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Home My WebLink About187-056MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 4-42 DUCK IS UNIT SDI 4-42 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 4-42 50-029-21731-00-00 187-056-0 W SPT 9645 1870560 2411 2054 2108 2119 2109 0 0 0 0 4YRTST P Sully Sullivan 6/10/2023 PT to 2709 for 500 dp 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT SDI 4-42 Inspection Date: Tubing OA Packer Depth 430 2709 2690 2686IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230612101508 BBL Pumped:3.8 BBL Returned:3.6 Thursday, July 27, 2023 Page 1 of 1           STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS �CENE JUN 18 2019 1. Operations Abandon Ll Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Ld install ab��,(n Li Performed: Suspend E]Perforate ElOther Stimulate ❑ Alter Casing 1:1X13 ❑� Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Complete 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Exploratory ❑ Stratigraphic❑ Service Q 187-056 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-21731-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0047502 DUCK IS UNIT SDI 4-42 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NIA ENDICOTT / ENDICOTT OIL 11. Present Well Condition Summary: Total Depth measured 11,839 feet Plugs measured N/A feel true vertical 10,584 feet Junk measured N/A feet Effective Depth measured 11,740 feet Packer measured 4,783 & 10,755 feet true vertical 10,496 feet true vertical 4,783 & 9,657 feet Casing Length Size MD TVD Burst Collapse Conductor 145' 30" 145' 145' WA NIA Surface 2,481' 13-318" 2,481' 2,481' 5,020psi 2,260psi Production 9,204' 9-518" 9,204' 8,449' 6,870psi 4,760psi Production 1,853' 9-5/8" 11,057' 9,906' 8,150psi 5,090psi Liner 1,031' 7" 11,839' 10,584' 8,160psi 7,020psi Scab Liner 5,912' 5-1/2" 10,695' 9,609' 10,640psi 7,480psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-112" 12.6#/ L-801 DSS 10,767' 9,667' Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2#/ L-801 TDS 10,870' 9,751' WFD LTP 1,611' MD Packers and SSSV (type, measured and true vertical depth) SAB -3 3-1/2" XN w1MCX See Above 1,611' TVD 12. Stimulation or cement squeeze summary: N/A 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: 0 0 0 2,000 0 Subsequent to operation: 1 0 0 9,673 650 2,186 14. Attachments (required per 20 AAc 25070, 25.071, & 25.283) 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 LJ Gas WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑✓ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-153 & 318-203 v+t=2 Authorized Name: Chad Helgeson Contact Name: Wyatt Rivard Authorized Title: Operations Manager Contact Email: WrlyardCWhllcorp.com , Authorized Signature: Dah 6/17/2019 Contact Phone: 777-8547 Form 10-404 Revised 4/2017 t' e! /I '/ o 3BDMS�JUN 1 91019 Wff Submit Original Only KB Elev.: 55.18 / BF Elev.:16,8 TD=11,839' (ND) / TD=10,5"OVD) PBTD =11,740' (MD) / PBTD=10,496'(T/D) Duck Island Unit Well: END 4-42 SCHEMATIC Last Completed: 5/15/2019 PTD: 187-056 SAFETY NOTES TREE & WELLHEAD Well Requires a SSSV Tree CIW 4-1/16" Wellhead I MCEVOY 13-5/8" OPEN HOLE / CEMENT DETAIL 13-3/8" 4,348 cu/ft Permafrost in 17.5" Hole 9-5/8" 575 cu/ft Class 'G',.75%CFR -2=0,12%HR-7 in 12-1/4" Hole 7" 1 375 cu/ft Class "G", .5% Halad 344, .16% LWL, 2% CFR -2 in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn Drift I Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 145' N/A 13-3/8" Surface 68/ L-80/ Btrs 12.415 Surface 2,481' 0.150 9-5/8" Production 47/NT80s/NSCC 8.681 Surface 9,204' 0.0732 9-5/8" Production 47/ NT95HS/ NSCC 8.681 9,204' 11,057' 0.0732 7" Liner 29/ L-80/ TKC Btrs 6. 184 10,808' 11,839' 0.0372 5-1/2" Scab Liner 17 / P-110 / GeoConn 4.892 4,783' 10,695 0.0232 TUBING DETAIL 3-1/2" Tubing 9.2#/L-80/EUE 2.992 1 Surface 10,716' 0.0087 4-1/2" Tubing 12.6/ L-80/ D55 1 3.958 1 10,716' 10,767' 0.0152 3-1/2" Tubing 1 9.2#/ L-80/ TDS 1 2.992 1 10,767' 10,870' 1 0.0087 WELL INCLINATION DETAIL KMP H "1 M.. A7911 = 43 deg. @ 7,255' Angle at Top Perf = 31 Deg. @ 11,306' JEWELRY DETAIL No Depth Item 1 1,634' 3.5" X Nipple - ID= 2.813" w/ MCX Valve 2 4,783 9-5/8"x7" WFD Liner Top Packer 3 4,789 9-5/8"0" WFD Liner Hanger 4 4,795' 7"x5-1/2" XO 5 10,663' 3-1/2" X Nipple (ID=2.813") 6 10,668' 5-1/2" Stage Tool 7 10,670' 5-1/2" WFD Annular Casing Packer 8 10,695' 5-1/2"x4" XO 9 10,696' 4" Sealbore Assembly, ID=4.0" 10 10,698' 4" Seal Assembly, ID=2.992" 11 10,707 4-1/2" Overshot Assembly 12 10,716' 4-1/2- Tubing Stub 13 10,741' Baker EB -1 Extra Long Tubing Seal Receptacle - ID= 3.735" 14 10,754.6' KBH-22 Anchor Seal Assembly, 3.948" 35 10,755' Baker SAB -3, 9-5/8" x 4-1/2" Hydroset Packer, ID=4.750" 16 10,760' 194-60 Mill -out Extension, 0=6.00" 1710,767' 11,377' 7" Srd Box X 3-1/2" TOS Pin XO, ID=2.972" 18 10,803' 3-1/2" Otis X Nipple, ID=2.75" 19 10,835' 3-1/2" Otis XN Nipple, ID=2.635" 20 10,870' Wireline Entry Guide, 2.992" PERFORATION DETAIL END Sands Toplit-m- (MD) (MD) Top (TVD) Btm (TVD) FT Date Status Size SPF 11,176' 11,278' 10,007' 10,094' 102 8/31/1987 Open 5" 5 11,306' 11,346' 10,118' 10,152' 40 5/16/2011 Open 2" 6 11,366' 11,396' 10,170' 10,195' 30 6/3/2003 Open 2-1/4" 6 11,366' 11,430' 10,170' 10,225' 64 8/31/1987 Open S. 5 END Sands 11,376' 11,377' 10,178' 10,179' 1 4/27/2003 Open 2-1/2" 5 11,396' 11,410' 10,195' 10,207' 14 4/27/2003 Open 11,416' 11,430' 10,213' 10,225' 14 4/27/2003 Open 2-1/2" 5 11,480' 11,500' 10,268' 10,284 20 10/14/2016 Open 2-3/8" 5 Reference Pert Log: DLL/ GR on 6/18/1987 GENERAL WELL INFO API: 50-029-21731-00-00 Initial Com letion -10/2/1987 Complete w/ ASR -5/15/2019 See Perf Table for Dates Revised By: TDF 6/17/19 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date END 4-42 ASR 50-029-23081-00-00 202-077 4/16/2019 5/18/2019 Daily Operations. 4/10/2019- Wednesday No activity to report. 4/11/2019 -Thursday No activity to report. 4/12/2019 - Friday No activity to report. 4/13/2019 -Saturday No activity to report. 4/14/2019 -Sunday No activity to report. 4/15/2019 - Monday No activity to report. 4/16/2019 -Tuesday Remove production tree and begin process of N/U BOPE on well 4-42. Pressure buildup seen on the IA. Bleed down to 0 psi. Crews meet at Endicott camp in prep for Sundry meeting and discussions w/ Endicott field staff. Conduct Introduction MTG to Endicott and Sundry to END 4-42. Crews Spot in Mud Boat, Pits, Rig, and other Equipment while making up the speed head and 2' spacer spool to the doyon hydril double gate ROPE. Stab Double gate on well head and begin to torque up to well head. RU hydraulic lines to Shaffer single gate BOP and install 2-7/8" x 5-1/2" VBR rams. Pick floor and well but off of Jacobs truck and release truck. Cont. to RU location, Pick and set well hut. RU stairs From well but to the Pits. Cont. to NU BOPE, NU single gate to 2" spool, pick annular when setting annular not enough room in-between well but and floor support beam to install BOP annular never had annular stack this high before. stop and come up with a game plan to raise floor and lower stack to fit bope under support beam. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-42 ASR 50-029-23081-00-00 202-077 4/16/2019 5/18/2019 Daily Operations. 4/17/2019- Wednesday Decision made to crib up well house with rig mats in order to get annular element under well house structural beam. Rig mats located on Endeavor Island in snowbank. Dig out mats and relocate to SDI. Fly mats into position w/ crane. Bleed down IA in prep for removing gate valve and replacing with VR plug. R/D BOPE w/ crane and remove 24" spacer spool. Set mud cross directly on TBG spool. Wellhead rep Mike Gilroy on location to set VR plug in McAvoy wellhead. VR plug unable to thread in. Remove gate valve and inspect. Thread type different than 3" plug provided. Utilize blind flange w/ ported 1502 to blind port. N/U annular and TO all studs. Fly in well house utilizing crane and spot in position over wellhead and BOPE. L/D accumulator hoses utilizing crane. Utilize crane to remove TBG tong stand from mast and move up on mounts in order to fit properly on raised rig floor. Prep fluid lines on pits for R/U. Spot rig stairs in position utilizing crane. Stairs slightly off with new rig floor height. Call scaffolding crew to add handrails and bridge gap between catwalk on pits and stairs. Raise mast and begin process of marrying mast to rig floor. N/U accumulator hoses in prep for testing BOPE. Spot auxiliary equipment around rig w/ forklift. Continue to R/U prepping fluid lines and glycol trailer for winterization. Call crews in for meeting to discuss new labor contract. conduct safety MTG with both crews and go over the labor contract. Cont. to R/u to BOP test, HCR lines, Winterize Equipment, RU to shore Power, Move well but over well, Put in rack pins and ru workfloor, adjust the tong rack, crown inspection, C/O to 5.5 elevator, max height of elevators 46' from the floor, pick up jnt of 5.5" geocon liner(average length 44') grease all valves, make up test subs. Stab in to BPV, pressure under BPV try to bleed of the pressure but could not bleed off tbg start to flow. Cont. to RU Spotting equipment. and rigging up. Off load 200 bbls of 9.2LBS brine and 40 bbls of lake water. call and order kill fluid 870 bbls 9.2lbs brine 4/18/2019 - Thursday Crew swap and fluid checks on equipment. While standing by for brine delivery - swapped out bails from 8' to 6" inspected and troubleshot noise from power swivel on hydraulic motor side. Dug out and moved in 5.5" Geo -Conn casing for scab liner, Change out the service loop wrap. 9.2 Brine on location, Tubingpsi =12psi IApsi = 12psi - Line up and pump 36 bbls 9.2 ppg brine down tubing @ 2.5 bpm @ 415psi, S/D and Line Up to Backside - Startpsi @ 200psi and falling - Start pumping @ 3.3 bpm. At 100 bbl awaypsi = 1500, @ 200 bbl away pmping 3.3bpmpsi = 1525, @ 300 bbl away pmpng 3.3bpmpsi = 1300, @ 400 bbl away pmpng 3.Sbpmpsi = 1350, @ 500 bbl away pmpng 3.5 bpmpsi = 1350. Continue pumping kill - with 600 bbls away @ 3.5 bpm pressure = 1350, pump total of 870 bbls with final pressure at 1350psi @ 3.5bpm. S/D pumping and pressure falling - ISIP@ 800psi and falling, 1 min S/I @ 144psi and falling, 2 min S/I @ ZEROpsi and falling. Blow Down all lines, and prep to shell test BOP. Swap out BPV to a TWC. Crew change, Inspect and service rig. Put fluid in the stack driller noticed that the TWC was Bubbling watched with well head hand bubbling stopped, continue to try and shell test. Work air out of system shut Blind rams and try to get shell test. when turn on test pump noticed fluid coming out of pump. stop to trouble shoot. found broken piston liner in triplex pump end. Repair and put test pump back together. Start shell test immediately start to leak on low. bring up to a high check for leaks could not find any surface leaks. swap out TWC. when pulling TWC Wellhead rep. said that it was sticky when pulling TWC like there was something in it. Start Shell test again Test good, continue to conduct BOPE t st as per sundry 2 7/8" and 5 1/2" TI 250psi/lo ^nnnpcj/bigh S min rh rr. A' fel' Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number I Start Date End Date END 4-42 ASR 50-029-23081-00-00 202-077 4/16/2019 5/18/2019 Daily Operations. 4/19/2019 - Friday Crew swap and fluid checks, prep to pull hanger. BOLDS and pull hanger and lay down. Witness Weatherford Liner Tech install pins on inflatable packer for 1,800psi to open inflation port and 1000psi to close and lock inflation port. POOH w/ 3.5" E kill string laying down, pulled 115 joints 3.5" EUE . Pick up 1 joint 5.5" 17# Geoconn casing and to make sure ASR and tong height is correct for PU the GeoConn casing. Lay down joint 5.5" geoconn. Install fill line for running 5.5" geoconn to rig floor, drift all X -overs and TIW Valve,witness and confirm measurements with Weatherford Tool Hand. P/U Muleshoe assembly w/ PBR and RIH, P/U Inflatable Packer assembly and RIH . All equipment visually good when RIH- Muleshoe CD - 7.500 ID - 4.90 w/ 10K shear screws for downward location., PBR ID - 4.000 OD - 5.11, Inflatable Packer OD -7.000 ID - 4.89 ID pinned to 1,800psi open and 1,000psi close for inflation. P/U 5.5" 17# P-110 GeoConn connection Casing and RIH. Conduct safety meeting and team meeting with Hilcorp rep. Crew change out. service and inspect rig. P/U RIH with 5.5"17# P-110 GEOCONN Connection Casing. Fill hole 1 bbls perjnt going in. Total of 134 jnts 5,917.37'. Liner top (top) @ 4,792.78'. C/O To 3.5" handle equipment, P/U Liner hanger/PKR assembly (5.5" 17# Geo Conn Pup,7" Vam Top HT X 5.5" GeoConn Pin,WFT WPHR Liner Hanger,Vam Top HT Coupling,WFT WTSP Liner top Packer,WFT PBR Tieback Sleeve) Witness Weather Liner Tech hanger packer with appropriate 3 screws and packer with 8 screws on first row (slips) and then 16 on second row (packer). RIH. 4/20/2019 -Saturday Continue P/U RIH w/ Liner Hanger Running Tool, and X -over to from 3-1/2" IF to 2-7/8" PH -6 Drifted X -over with 2.223 drift for good. RIH and start P/U and RIH w/ 2-7/8"" 7.9# P-110 PH -6 tubing. Continue RIH w/ 2-7/8" 7.9# P-110 PH -6 tubing. RIH to 10,689' and UP weight @ 128K, Down Weight 80K - RIH to 10,709' and set down 5K. P/U 15' and break weight over to 128 K. P/U 5' and Run back down to 10,709' and set down 1SK with no indication of shears. Repeat and set down 20K twice with no indication of shears. Repeat with 30K down and no shear. S/D and discuss options, decision made to set down and pull to neutral weight - set down 5K and cement well. RU Halliburton. Went to PT could not get over 800psi, Swapped TIW with Halliburton 1/4 turn valve. PT pump lines to 4,000psi,. Load Dart 1.63" OD, Pump 5 Bbls cement, chase with 3 bbls of 9.2#brine, Pump 168 bbls of brine to bump calculated volume was 162Bb1s. Set liner hanger at 1,000psi set down 25K on Hanger. Inflatable PKR opened @ 2,100psi and settled @ 1,740psi- Good. DV tool opened at 2,600psi. Pumped 50 Bbls 3Bbls/min @ 430psi. 30 Bbls of fresh water, 261 Bbls of Class G cement,. dropped dart 1.89" OD, 3 bbls min@ 350psi, latch @ 1,450psi, chase with 10 bbls fresh then 170 bbls of 9.2# never saw a bump should have saw bump @ 163 bbls away. tried to pump 30 more @ 3 bbis a min at 2,500psi never bumped. 4/21/2019 -Sunday POH/w 2-7/8" ph6 7.9# P-110 TBG 134 jnts lay down. pumping displacement on the way out every 15 jnts out. C/O to 3.5" TBG equipment. Break out and lay down the WFT running tool. Found Dart still inside wiper plug for 5.5" liner cement job. load and tally first 65 jnts of 3.5" 10.37# G-105 DP work string, M/U 4-3/4" Tricone bit. RIH/w 3.5" 10.37# G-105 DP work string, M/U 4-3/4" Tri- cone bit. 117 jnts displacing on the way in the hole. 5�� Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date END 4-42 ASR 50-029-23081-00-00 202-077 4/16/2019 1 5/18/2019 Daily Operations. 4/22/2019 - Monday Continue RIH w/ 3.5" 10.37# Work -string and 4.750" tricone bit - Tag liner top at 4,769' adjusted DPM (20' KB), rotate easy and fall in, continue RIH to 10,644' to 20' above DV tool and circulate 30 bbls at 3.5bpm - pump pressure 520psi steady pressure with full returns. POOH w/3.5" 10.37# Work -string and 4.750" tricone bit 10,644' 266 jnts pumping displacement on the way out conduct Low 02 well control Drill. B/O and lay down Bit and BS, unload 115 jnts of 4" 14# HT 38 DP, 43 jnts of 4" 28.38# HT 38 HWDP, 3.5" IF Pin X HT 38 Box, HT 38 Pin X 3.5" IF Box, HT 38 FOSV and IBOP, 2- HT 38 X 1502, 4" Manual elevators, HT 38 Pin X 3.5" IF Box ported sub, 4" HT 38 Subs (2-5', 1-10', 1-15'), HT 38 Lifting sub, Load and tally HWDP And part of DP, RD Rig Tong, Prep to RU Doyon CSG Tongs 4/23/2019 -Tuesday Continue rig up to RIH w/ drill pipe. Swap out 13-5/8" riser spools to accommodate manual slip bowl, swap out 6' bails for 8' bails, swap out lifting and handling gear to handle 4" DP, R/U Doyon casing tongs, move out work string and move in drill pipe and tally. Prep catwalk to handle HVY WT D/P,. P/U Weatherford Assembly with wiper plug, seal assembly, and packer actuator. Wiper plug pinned with 4 shear pins at 960psi shear pressure, Seal assembly inspected for good when RIH, Distance from packer actuator to bottom of seal assembly -5.82', Seal OD 7.52" Wiper plug ID 1.69", Drill Pipe Dart no-go OD 1.78". RIH w/ Weatherford Seal / wiper plug assembly. Start RIH w/ Weatherford Seal assembly and HVY WT DP. Joint # 36 in hole @ 18:00 hours. Continue to RIH w/ Weatherford Running Tool on 4" HT 38 Drill Pipe f/—900'md to LNR top @ 4,769'md. Utilize Doyon CSG w/ 9-5/8" double stack Eckle tongs for making up DP. Halliburton Cementers back unit into position and prep for R/U. Clear rig floor in prep for cementing. PJSM w/ HES Cement, Weatherford, and ASR Crew Hands, Jacobs Truck Drivers. Shut annular and roll rig pumps @ 21313M. Stab Weatherford running tool into PBR @ 4,769'md, watch for pressure increase as seals engage PBR (100psi seen). Set down until running tool no-go is seen on the LNR top. Set down 15klbs on LNR Top. HES cementers perform PT on circulation lines. Set pump trips at 3,000psi and verify kick out. Open up HES cementers to wellbore and pump 30bbls of fresh water spacer to warm up system. Line up and pump 134bbls of 12ppg lead cement, chase 12ppg cement w/ 98bbls of 14.5ppg tail cement. Hold 250psi back pressure on choke in order to slow cement from falling in TBG. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-42 ASR 50-029-23081-00-00 1 202-077 4/16/2019 5/18/2019 Daily Operations. 4/24/2019- Wednesday Continue pumping displacement to land wiper plug w/ ZERO returns. Bump plug @ 3.5bpm at 3160psi. Good indication of plug bump and slowly increase pressure to 4,065psi w/ hook load @ 3K and held for 5 mins. No real indication of DV tool shift. Finalpsi after hold was 4,113psi w/ hook load @ 64K. Bleed back 1.5 bbls fluid andpsi dropped to ZERO with no build. Call town. Decision made to set packer - set down w/ string weight of 75K on liner top for 2mins, pull back up to neutral (75K) and set back down full string weight 75K for 3 mins. Pick back up to neutral and with seals in seal bore on drill pipe and test backside good test to 1500psi for 10 mins with no leak off - test charted. Bleed off and pull up and out of seals. Circulate 50bbls long way to pits with full returns. POOH laying down 4 joints 4" HT -38 drill pipe. Kelly up and test 9-5/8" casing and 5- 1/2" liner to 1,500psi for 30 minutes. Test charted and test good. Bleed off pressure. Line to reverse out and pump 2 bottoms up 100bbls and all returns clean brine. Blow Down lines. Pick up X -over 4" Ht -38 pin X 3-1/2" IF box -1.39', X -over 3 1/2" IF pin X 2-7/8" IF box -1.67', X -over 2-7/8" IF pin x 3-1/2" EUE box - 1.70', 1 joint 3-1/2" EUE 8 rnd 9.3# L-80 tubing 29.46', X -over 3-1/2" EUE pin X 4.5" EUE box 1.30' Hanger pup 5.72', and Hanger. Land Hanger, RILDS. Pump 40 bbls diesel down backside taking returns up tubing. Lock diesel in backside, Blow down lines, Install BPV. Lay down derrick, rig down floor, pull BOP stack, and tree up. tested void on tree to 5K for good test - PULLED BPV and pad operator installed u -tube hose to freeze protect. start u -tubing diesel from casing to tubing to freeze protect. 4/25/2019 - Thursday Complete stack out to leave rig. Well is currently equalizing with diesel u -tubing from backside to tubing. Wireline due to arrive for temp survey to find TOC. 4/26/2019 - Friday No activity to report. 4/27/2019 -Saturday No activity to report. 4/28/2019 -Sunday No activity to report. 4/29/2019 - Monday No activity to report. 4/30/2019 -Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-42 E -Line/ ASR 50-029-21731-00-00 187-056 4/16/19 5/18/19 Daily Operations. 5/8/2019 - Wednesday No activity to report. 5/9/2019 - Thursday MODE crews and held Sundry MTG, check pressure on the well on a vac., ND wellhead, NU 13-5/8" BOPE with annular, RU ASR and all supporting equip., RU Pump lines, Shell test BOPE test as per sundry 250psi low 3,000psi high Good. 5/10/2019 - Friday Service Rig. Test BOPE as per Hilcorp & AOGCC requirements, AOGCC witness was waived by Adam Earl, tested with 3-1/2" & 4-1/2" TJ, 250 low & 3,000 high, tested Gas alarms & pvt system Good. R/D test eq. & blow down lines. R/U handling eq. M/U landing jt. Pulled hanger 78k, I/d same. Install spacer spools, r/u & circulate out freeze protect. Swap over to 3.5" handling equipment, lay down 1 jnt 3.5" EUE Tbg, swap over to 4" handling equipment. Inspect and service rig and equipment. Lay Down 86 jnts of 4.00" D/P HT -38 15.65 #. Note: Fighting 3rd party CSG Tong equipment. Having power problems not able to get full breakout torque with power pack. ended up having to call for new pack. Start R/U Return line for Drilling operations, Prep and tally Drilling BHA while wait on new power unit for casing tongs. cont. POOH t/822' Lay down 4.00" HWDP , working through some tight connections. 5/11/2019 - Saturday Cont. POOH f/822' I/d 4" kill string. C/O handling eq. install wear bushing, install flow nipple. P/U BHA ( 4-3/4" Tri -cone bit 2- 7/8" reg ID 1-1/4", 2-7/8" reg x 2-3/8"IF Bit sub, 7- 3-1/2" DC 2-3/8" IF BxP ID 1.75", 3-1/2" Jar 2-3/8"IF BxP ID 11/2", XO- 2- 3/8" IF x 2-7/8" reg 1D 1-1/4", XO -2 7/8 Reg x 2-7/8" IF). RIH/ 3.5" 10.37# 2-7/8"IF Work String. 6,002.46'. P/U, M/U Dual 7" Boot Basket with 2-7/8" IF connection, 10.05'3-1/2" handling sub on top. Cont. RIH/W 3.5" 10.37# 2-7/8"IF Work String tag cement stringer @ 10,455', 110K up wt. 73K dwn. 0 fluid loss for tower. Kick while tripping well control drill. 5/12/2019 -Sunday Wash down f/10,455', t/ 10,660'Wash & ream stringers as needed, drilled cmt f/10,660't/10,665'tagging dart/plug, circulate 3 bpm, 970 psi, up wt 106k, do wt 68k, rot wt 85k tq 2,600. Cont. drill on plug f/ 10,665 t/ 10,668' changing parameters hunting tq.broke through , drill cmt t/10,683' circulate 3 bpm, 970 psi, up wt 106k, do wt 68k, rot wt 85k tq 2,600. Tagged Dart/plug @10,683', drilled on dart circulate 3 bpm, 970 psi, up wt 106k, do wt 68k, rot wt 85k tq 2,600 changing parameters hunting tq as needed. Finally fell through @ 10,686' dragging for about 1' then no WOB cont. down 4' established a positive tag on collar @ 10,691'. Begin bottoms up 4bbl/min @ 1,500psi. @ 370 bbls started to see some gas cut and hydrocarbons on returns cont. to circ. another 60 bbls until clean . total fluid loss during circ. 19bbls. Pooh with 3.5" 10.37# 2-7/8"IF work string 117 jnts pumping displacement on the way out. Break out and lay dwn Boot basket, recovered rubber & cmt cuttings. Cont. to Pooh/w 3.5" 10.37# 2-7/8"IF work string lay down total of 9,400'. 5/13/2019 - Monday Cont. POOH 1/d 3-1/2" wk string, f/840', L/D BHA, bit was dull on outer & most inner cutters gone. R/U w/I , RIH w/ 4" brush assembly, tagged up @ 10,691' WLM (10,6711' with KB adjustment) worked area several times brushing seal bore, POOH c/o tools t/ 1-3/4" bailer w/2.33 cent. RIH tagged at 10,691' WLM (10,6711' with KB adjustment) set down worked several times & fell through cont. on down t/ 11,447' WLM w/KB adjustment. R/U pull wear bushing, c/o handling eq. Load pipe rack with completion- 3-1/2" 9.2# L-80 EUE tubing, tally same. PU RIH 3-1/2" 9.2# L-80 EUE completion tubing w/ 4" seal assembly 2.7' seals on 10.68' assembly, t/7,230', saw the liner hanger @ 4,764.99', up wt 62k, Down wt 47k. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number I Start Date End Date END 4-42 E-Line/ ASR 50-029-21731-00-00 187-056 4J16/19 5/18/19 Daily Operations. 5/14/2019-Tuesday Cont. RIH w/ 3-1/2" completion t/ 8,590'. Developed leak on tongs, troubleshoot & repair same. Cont. rih p/u 3-1/2" completion tubing (9.2#, L-80, EUE ) t/ 10,671' up wt 86k, do wt 65k. R/U to pump down annulus to verify seal interaction for space out. Pump down annulus balance out system, stage In hole watching for pressure increase, pump 2 BPM 750 psi t/ 10,701.50' seeing pressure increase t/ 1,591psi. Calculate space out placing seals in seal bore 7', I/d 3 jts, strip off the 13- 5/8"X11" Spool , p/u space out pup, p/u joint, m/u hanger pups & landing jt. RU to spot inhibitor in the annulus and pump freeze protect. Circulate & spot corrosion inhibitor (baracore) in annulus & 140 bbls of diesel freeze protect. Land Tbg hanger Dwn wt @ 64K watched wt while sting into the PBR saw a bit of drag good indication stung in before landing hanger, RILDS, PEessured up for 2,500 psi MIT, chart 30 min test good. EOT @ 10,707.83'. Pulled Iandingjt, set BPV. (At Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-42 E-Line/ ASR 50-029-21731-00-00 187-056 4/15/18 5/18/19 Daily Operations. 5/15/2019- Wednesday RDMO ASR rig and Equipment. ND 13-5/8" BOPE stack. NU new completion well head and test tree and void 250psi/low 5,000psi/high. test good. Start rig Move from Endicott to MPU K-44 5/16/2019-Thursday No activity to report. 5/17/2019 - Friday No activity to report. 5/18/2019 -Saturday WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/2,500H. SET 3-1/2" MCX (SER# MP3-07, 1.0875" BEAN, DAL= 31", NO ED DEVICE), S/D IN X-NIPPLE @ 1,596' SLM / 1,634' MD, UNABLE TO PERFORM CLOSURE TEST DUE TO LOW PRESSURE ON WELL. JOB COMPLETE, WELL LEFT SHUT IN UPON DEPARTUE - NOTIFY PAD-OP SSSV INSTALLED. 5/19/2019-Sunday No activity to report. 5/20/2019 - Monday No activity to report. 5/21/2019-Tuesday No activity to report. MEMORANDUM To: Jim Regg 7Ih 119 P. Supervisor FROM: Austin McLeod Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 27, 2019 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska LLC 4-42 DUCK IS UNIT SDI 4-42 Src: Inspector Reviewed By: P.I. Suprv,3R2— NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 442 API Well Number 50-029-21731-00-00 Inspector Name: Austin McLeod Permit Number: 187-056-0 Inspection Date: 6/12/2019 ' Insp Num: mi[SAM190612121934 Rel Insp Num: Thursday, June 27, 2019 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Type Boas s Tubing 2170 �2163 - 2142 _ prp s7asvo Type s Test psi 241 - IA 513 2809 2762 - 2750 -- — BBL Pumped: - - _ 3.5 ' — - IBBL Returned: 3.7 OA - zo zo ,L zoo j Interval li INITAL P/F -10 P Notes: MIT -IA post conversion to injector. i Thursday, June 27, 2019 Page I of I Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, April 23, 2019 8:21 AM To: Wyatt Rivard Cc: Rixse, Melvin G (DOA) Subject: RE: END 4-42 (PTD#187056) Scab Liner Cement Job 2nd Attempt Wyatt, You have approval to modify sundry as proposed. Once kill string is landed also perform a MIT of the casing to 1500 psi (30 min) to verify your LTP is set and you are hydraulically isolated from any open perforations or the casing leak. You can leave sundry 318-203 open but will require notification of re-entering the well as you mention below. At that point you would be at approx. step 33 of the program... Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@olaska.aov). From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, April 22, 2019 6:41 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: RE: END 4-42 (PTD#187056) Scab Liner Cement Job 2nd Attempt Hello Guy, As discussed this morning. When we pulled out of hole with our workstring following the unsuccessful liner cement job on END 4-42 (PTD#187056), we found our wiper plug still in the running tool. The running tool had malfunctioned during the cement job, causing an emergency release burst disk to pop after the dart was dropped but before wiper plug was released to close the stage tool. With that, we still stand a good chance of success at a 2"d attempt on a cement job. There will be a few minor changes to our previous plan for cementing the liner. The main change is a slight reduction (10%) in cement volume, this will help us avoid over displacing cement onto the backside of the workstring while bumping the plug. In the event that we run into issues again, we will have the option of holding pressure on the liner until cement is set. We would also look to combine a lighter weight cement system (13 ppg) with our planned 14.5 ppg system due to cement availability and to provide less back pressure/lifting force at our PBR during the cement job. Once the liner is set, we will be running out of ASR crew availability on this hitch and we would plan to temporarily suspend the workover for 2 weeks and then come back next hitch. Once the liner cementing is complete, we would pick up a couple of joints and utilize the workstring as a killstring. Additional steps added to the sundry procedure would include (also attached): 27. Begin mixing cement and once at weight pump ±250bbls of 14.5ppg Class G cement down the workstring. Launch wiper plug and chase with seawater. Once wiper plug lands in the Stage Tool, pressure up to 2,000psi to confirm set. ***1" attempt at cement job on 4/21/19 unsuccessful following malfunction of running tool/wiper plug. Cement circulated out and work string disconnected from LTP*** 28. Perform 2 n attempt at cementing 5-1/2" Liner 1) RIH with packer setting tool and stab into LTP PBR. 2) Begin mixing cement and, once at weight, pump +/- 225 bbls (-100 bbls 14.5 ppg and 125 bbls 13 ppg) cement down the workstring. a. +/- 225 bbls equates to 900 of 5-1/2" by 9-5/8" annular volume leaving some margin to prevent overdispalcement while bumping plug. 3) Launch wiper plug and chase with 9.2 ppg fluid. Once wiper plug lands in the stage tool, pressure up to 1,500 psi over cement hydrostatic to confirm set and stage tool closed. a. If plug not bumped, do not over displace cement to backside of work string. b. Instead, hold pressure on the liner until cement is set. 29. Set liner top packer. If needed, utilize heavier weight workstring to set down at least +/- 67klbs. 30. Pick up at least two joints and circulated out any excess cement. Land the workstring as a killstring to temporarily suspend workover. a. Set BPV. Test tubing hanger to 250/5000 psi through test port. b. RD BOPE and ASR Rig c. Set TWC, NU 4-1/16" 5,000# tree and adapter flange and test to 500 psi low/5,000 psi high. 31. Obtain AOGCC approval for additional rigup and BOPE testing steps prior to reentering on rig's return to well. This would leave the well in a secure state, circulated with 9.2 ppg fluid and isolated from the reservoir with the cemented wiper plug. Provided 5-1/2" liner cementing is successful, we would also be isolated from the casing leak. We would then add and communicate additional steps to the procedure upon return for rigging back up to the well and BOP testing before milling out the wiper plug and running the injection completion as per the sundry procedure. Please let me know if these changes are acceptable or if you have any questions. Thank You, Wyatt Rivard J Well Integrity Engineer IHiIcorp Alaska, LLC U: (907) 777-8547 I C: (509)670-8001 1 wrivardc@hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wyatt Rivard Sent: Sunday, April 21, 2019 9:27 PM To: 'Schwartz, Guy L (DOA)' <guy.schwartz@alaska.Pov> Cc:'Rixse, Melvin G (DOA)' <melvin.rixse@alaska.gov> Subject: RE: END 4-42 (PTD#187056) Scab Liner Uncemented Hello Guy, The ASR ran the 5-1/2" scab liner on END 4-42 (PTD#187056) across the 9-5/8" casing leak from "'4800 to -10700 as per under Sundry 318-203. The upper liner hanger was successfully set and the lower inflatable casing packer inflated with cement. They then proceeded to cement the scab liner through the stage tool and up through the liner hanger. Unfortunately, once the cement job was pumped, a dart was dropped to shear the stage tool closed but was unable to pressure up and close the tool. In the process of attempting to close the tool, they wound up with cement on the backside of the workstring and had to circulate the cement up the backside and out of the hole. Going forward, we are not planning further attempts to cement the liner as we have low confidence in both maintaining the flow path and closing the stage tool concurrently. Instead we plan to manually close the stage tool then confirm the liner's integrity as a stand-alone casing patch. The sundry procedure would be modified at Step 27 following the cement job: 27A) Following unsuccessful cementing, confirm liner integrity as standalone straddle patch. a. POOH with workstring b. RIH with bit and shift the stage tool closed. c. If 5-1/2" test packer is available and can be run with bit run, set 5-1/2" test packer below LTP at 4800' and test through packer to obtain internal test of 5-1/2" liner to 2000 psi. d. Otherwise, POOH. Run back in and sting into the LTP at -4800' and perform an internal test of the 5- 1/2" to #2000 psi. e. If internal test good, continue to set LTP as per step 28 of sundry procedure. Please let me know if you have any questions. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard@hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wyatt Rivard Sent: Thursday, April 18, 2019 2:52 PM To:'Schwartz, Guy L (DOA)' <guy.schwa rtz(a@aIaska.gov> Cc:'Rixse, Melvin G (DOA)' <melvin.rixse@alaska.gov> Subject: RE: END 4-42 (PTD#187056) Mud Weight Increase Hello Guy, The ASR has moved onto END 4-42 (PTD#187056) to begin work under sundry 318-203 (attached). Since the sundry procedure was created, the well's BHP has increased due to offset injection. A SBHPS performed on 2/1/19 showed a BHP of -4296 psi or 8.3 ppg EMW. The well was circulated ahead of the ASR with 8.5 ppg seawater on 4/16/19 which left 100 psi on the tubing. Due to our relatively shallow kill string depth at 3535' MD, it's assumed that we did not have a full seawater gradient to perfs. The 100psi was back calculated to an equivalent kill weight fluid and the new KWF was pumped to the bottom of the kill string. The well went on a vacuum, a BPV was set in the TBG hanger, and the crews rigged up the ASR over the well. However, prior to pulling the BPV, pressure was seen below the BPV so it was decided to pump a surface to perforation volume of 9.2 ppg KWF so that fluid density is consistent throughout wellbore even though BHP is well below a 9.2 ppg equivalent. Going forward, 9.2 ppg wellbore volume will be pumped prior to setting the TWC. To accommodate this change, Step 14 of the procedure would be modified to: 14. Check for pressure and if Opsi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, circulate'+.2ppg fluid and confirm dead prior to pulling BPV. Set TWC. Please let me know if you have any questions. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 1 Q (509)670-80011 wrivard0hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Schwartz, Guy L (DOA) [mailto:guv.schwartz@alaska.gov] Sent: Sunday, April 14, 2019 9:21 AM To: Wyatt Rivard <wrivard@hilcorp.com> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: END 4-42 (PTD#187056) ASR Workstring and BOPE Configuration Change Wyatt, The change in work sting size is approved as proposed. Test VBRs as outlined and fill out MOC form. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCCI, State of Alaska and is for the sole use of the intended recipient(s). If may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartz@alaska.aovl. From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Saturday, April 13, 201910:58 AM To: Schwartz, Guy L (DOA) <guy.schwa rtz@alaska.gov> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: END 4-42 (PTD#187056) ASR Workstring and BOPE Configuration Change Hello Guy, The ASR will be moving over to Endicott soon to start a scab liner & tubing swap RWO on END 4-42 (PTD#187056) under Sundry 318-203 (attached). Currently the sundry procedure calls for using a 3-1/2" workstring to set and cement the liner. Instead of 3-1/2" work string, we would like to change to a 2-7/8" workstring which has a smooth internal bore unlike our 3-1/2" string which has internal upsets at the connections. These upsets may cause issues with properly displacing all of the cement from the string and dropping balls/plugs while cementing the scab liner. In order for the BOPS to accommodate the full range of our 2-7/8" workstring, 3-1/2" killstring and 5-1/2" scab liner, this change will necessitate the installation and testing of an additional set of VBR pipe rams. The sundry procedure would be modified as follows: Step 15: Test BOPE to 250psi Low/ 3,000psi High, annular to 250psi Low/ 2,500psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 3-1/2" & 5-1/2" test joints. e. Test VBR rams on 2-7/8" test joint. f. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Step 21: MU 5-1/2" scab liner and TIH on , 7 ;7„ workstring. An updated BOPE schematic is attached showing the third set of rams installed. Please let me know if you have any questions. Thank You, Wyatt Rivard I Wei I Integrity Engineer I Hilcorp Alaska, LLC 0: (90 7) 777-8547 1 C: (509)670-80011 wrivard(a)hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 PROF 7' • THE AE Alaska Oil and Gas o e LA c 11 1Conservation Commission _ fl 1VJ�\ 5}� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 0F ALAS�P Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC scow) MAY 2 3 2-01Ei 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU SDI 4-42 Permit to Drill Number: 187-056 Sundry Number: 318-203 Dear Mr. York: Enclosed is the approved application for the 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, Hollis S. French Chair DATED this -22-day of May, 2018. RBDMS AY 21201U • „,,,,, t i«' .r—to'i p.:40.4 • STATE OF ALASKA MAY 18 201a ALASKA OIL AND GAS CONSERVATION COMMISSION OTS 5 f 2.2.I/ V APPLICATION FOR SUNDRY APPROVALS A G CC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Install Scab Liner CI Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q . MIT-IA El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Complete 0 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 187-056 • 3.Address: 3800 Centerpoint Dr,Suite 14006.API Number: Stratigraphic ❑ Service 0Anchorage Alaska 99503 50-029-21731-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462.007 Will planned perforations require a spacing except' n? Yes ❑ No D DUCK IS UNIT SDI 4-42 • 9.Property Designation(Lease Number): S,,13,4t-_, 10.Field/Pool(s): ADL0047502,,1 L.et)I7.52 3 ENDICOTT/ENDICOTT OIL • I 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,839' 10,584' 11,740' 10,496' 2,000 N/AN/A Casing Length Size MD TVD Burst Collapse Conductor 145' 30” 145' 145' N/A N/A Surface 2,481' 13-3/8" 2,481' 2,481' 5,020psi 2,260p5i Production 9,204' 9-5/8" 9,204' 8,449' 6,870psi 4,760psi Production 1,853' 9-5/8" 11,057' 9,906' 8,150psi 5,090psi Liner 1,031' 7" 11,839' 10,584' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4-1/2" 12.6#/L-80/DSS 10,767 See Schematic See Schematic 3-1/2" 9.2#/L-80/TDS 3,535 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SAB-3 Packer 10,755(MD)/9,657(TVD and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development❑ Service Q • 14.Estimated Date for -? 15.Well Status after proposed work: 4/21/2018 - Commencing Operations: OIL ❑ WINJ 0. WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 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. Authorized Name: Bo York Contact Name: Taylor Wellman 7✓ Authorized Title: Operations Manager Contact Email: twelimant hiIcorp.com �� Contact Phone: 777-8449 Authorized Signature: Date: 5/17/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1 20 3 Plug Integrity ❑ BOP Test Ii Mechanical Integrity Test [r Location Clearance ❑ a Other: 4 J o lo5 4 ,.`5 t do ,T /0.---,- k"- Pi 4 - t Post Initial Injection MIT Req'd? Yes ❑ No ❑ /// Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /O -I16 l / ., 31 y _l)3 a)C2c-n\" APPROVED BY + Approved by: COMMISSIONER THE COMMISSION Date: 5 (I2'lte) r z is � ,AL, BD11LS MAY 2 2 2018mt Form and Form 10-403 Revised 41201 Approved applicati 1 f 2 e date o approva. ttachments in Duplicate • RWO—Scab Liner&Tbg Swap • Well: END 4-42 PTD: 187-056 Hilcorp Alaska,LL API: 50-029-21731-00 Well Name: END 4-42 API Number: 50-029-21731-00 Current Status: S/I—Casing Leak Rig: ASR#1 Estimated Start Date: June 05, 2018 Estimated Duration: 8 Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 187-056 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8847 (0) (509) 670-8001 (M) AFE: WeIIEZ Entry Required: Yes Current Bottom Hole Pressure: 3,091psi @ 10,000' TVD (Based on SBHPS taken on 10/29/15) Maximum Expected BHP: 3,091 psi @ 10,000' TVD (Based on SBHPS taken on 10/29/15) Equivalent MW: 6.0ppg Max. Anticipated Surface Pressure: 2,000psi (Highest recorded tbg pressure—GL system pressure) Brief Well Summary: Endicott Well 4-42 was drilled and completed in September 1987. The well was completed as an USZ producer in the FIII, FIV, and FV sands. The well has had multiple cement squeezes performed for water shut off. By the end of 2012 the well's production and declined to<20bopd. Additional perforations were added in the FII in 2016 which provided a short term buzz before watering out. In early 2017 the well was converted to a water injector. During the conversion,the well failed an MIT-IA. Further diagnostics indicated a packer leak with an LDL run on 05/22/17. All topside facilities have been converted but the well has not passed an MIT-IA and has not injected any water to date. v A RWO was begun on 4/22/18. During the RWO, a casing leak was identified between 5,20000' md. The ASR#1 was rigged down to develop a full repair plan. A slickline caliper shows damaged casing from ±5,250' and down to near the packer. RWO Objective: 1. Pull the kill string, run and cement a 5-1/2" scab liner to restore casing integrity. 2. Run a new completion to regain a competent IA. 3. Place well on injection and obtain MIT-IA once stabilized on injection. ***VARIANCE REQUEST***: Requesting a variance to 20AAC25.412(b). Uppermost 9-5/8" packer will be set greater than 200ft measured depth from open perfs. Proposed distance=471ft. Procedure Operations& Pumping 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump.Setup reverse out skid and 500 bbl returns tank and additional upright tanks as needed. 4. Pressure test lines to 3,000 psi. 5. Attempt to circulate out any gas from the well by pumping down the tubing and taking returns from the IA. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. • RWO—Scab Liner&Tbg Swap • Well: END 4-42 PTD: 187-056 Hilcon)Alaska,Lb API: 50-029-21731-00 7. RD Little Red Services Pump and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 13-5/8" BOPE. RD crane. 9. NU BOPE house.Spot mud boat. Workover Procedure: 10. Move ASR#1 over well. 11. Verify 0 psi on the annulus and tubing pressure. 12. Set BPV, ND tree, NU 13-5/8" BOP's. a. Make scribe mark on tree for orientation for re-installation. b. Function test all prior to arrival of AOGCC inspectors. 13. Spot and rig up ASR#1 and all supporting equipment. 14. Check for pressure and if Opsi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, circulate 8.5ppg seawater and confirm dead prior to pulling BPV. Set TWC. 15. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and V) .+5 test for 5-min). Record accumulator pre-charge pressures and chart tests. ,r�✓ a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 3-1/2" &5-1/2"test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 16. Contingency: (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.) Note the BPV profile was found to be damaged during the last inspection. Use of a SL plug in the tubing was used in order to conduct the BOP G test. Since this time the hanger was replaced and tested good when the tree was re-installed. Contingency should not be required. a. 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 test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 17. Bleed any pressure off casing to 500bbI returns tank. Pull TWC. 18. MU 4-1/2" landing joint and BOLDS. 19. Pull over string weight on tubing and confirm free (original drilling reports did not record PU/SO weights). Once hanger becomes free check for flow to insure well is dead. LD Tubing hanger. • RWO—Scab Liner&Tbg Swap Well: END 4-42 PTD: 187-056 Hilcorp Alaska,LG API: 50-029-21731-00 a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in. tubing head. Test BOPE per standard procedure. 20. Pull the 3-1/2" killstring from 3,500' md. 21. MU 5-1/2" scab liner and TIH on 3-1/2" workstring. C a. Confirm configuration with proposed running order sheet. 'A P t b. Confirm shear values with Tool Supervisor prior to running in hole. The values listed are D43 h� approximate values and may vary slightly to actual values run. 22. Land 5-1/2" scab liner with overshot onto 4-1/2"tubing stub. 55 c — a. Note shear pins and travel to ensure over the tubing stub. �(`'�I' ��' S 23. Launch ball and pressure up on workstring to ±1,800psi to set the liner hanger. Continue to pressure up to pt` ±2,800psi to release the running tool. PU off the scab liner to confirm free. Pressure up to±3,500psi to .- 1.4 rupture the shear disk. 24. Launch ball and land in baffle of the landing collar. Pressure up to open and set the ACP. a. Inflate ACP as per Tool Supervisor's instructions. ACP is set to shear closed after inflation. 25. Pump down the IA and pressure to 500psi to confirm ACP set. 26. Pressure up on the workstring to±3,500psi to shear open the Stage Tool. Confirm circulation down workstring and up the IA. 27. Begin mixing cement and once at weight pump±250bbls of 14.5ppg Class G cement down the workstring. Launch wiper plug and chase with seawater. Once wiper plug lands in the Stage Tool, pressure up to 2,000psi to confirm set. 28. TIH and set down±50,000Ibs onto the workstring to set the liner top packer. `.c, 29. Circulate out any excess cement and TOOH. r, si - Z ,�. 30. MU 5-1/2" milling BHA. TIH to top of wiper plug and obtain milling parameters. 0.5, r 31. Mill out wiper plug and down through the baffle plug. Attempt to circ well clean and TOOH. F.,- 32. MU and run the 3-1/2" injection string completion. a. Confirm configuration with proposed running order sheet. 33. Record PU and SO weights prior to spacing out in the sealbore. 34. PU and space out and then land the tubing string. a. Sealbore setting depth is±10,705' md. b. Pump down the IA while stinging into the sealbore. Once pressure begins to build, shut down pumps and complete space out. 35. PU and reverse circulate 510bbls of seawater with corrosion inhibitor followed by 140bbls of diesel. 36. Land the tubing hanger and RILDS. Lay down landing joint. Test tubing hanger packoff to 5,000 psi. IA37. Perform an MIT-IA to 2500psi for 30 min (charted). M t�r a. Notification to the AOGCC for witnessed test needs to be submitted 24 hrs prior to conducting test. 38. Set BPV.Test tubing hanger to 250/5,000psi thru test port. 39. RD Hilcorp ASR#1 WO Rig,ancillary equipment and lines to 500 bbl returns tank. Post Workover Procedure: 40. RD mud boat. RD BOPE house. 41. RU crane. ND BOPE. Pull BPV.Set TWC. • RWO—Scab Liner&Tbg Swap Well: END 4-42 PTD: 187-056 Hiloorp Alaska,LL, API: 50-029-21731-00 42. NU 4-1/16" 5,000#tree and adapter flange and test to 500 psi low/5,000 psi high. 43. Test tubing hanger void to 500psi low/5,000psi high. 44. Pull TWC. RD crane. 45. Move 500bbl returns tank and rig mats. 46. Spot Slickline unit and RU. 47. Pressure test lubricator to 300psi low and 4,000psi high. 48. Set 3-1/2" MCX SSSV at±1,600' md. 49. RD Slickline. 50. Turn well over to production. 51. Once well online and stable contact AOGCC for witnessed MIT-IA(aressure to be determined by actual packer set depth: 0.25 x packer tvd). — Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic • • DuckIsland ni SCHEMATIC11 U� U t Well: END 4-42 Last Completed: 10/2/1987 Mean)Alaska,LLC PTD: 187 056 SAFETY NOTES TREE&WELLHEAD KB Elev.:55.18/BF Elev.:16.8 H2S Readings Average 230-260 PPM on A/L&Gas Injectors Tree CIW 4-1/16" Well Requires a SSSV Wellhead MCEVOY 13-5/8" 3CT IV! OPEN HOLE/CEMENT DETAIL t* 13-3/8" 4,348 cu/ft Permafrost in 17.5"Hole 'mal 9-5/8" 575 cu/ft Class'G',.75%CFR-2=0.12%HR-7 in 12-1/4"Hole ;% CA7" 375 cu/ft Class"G",.5%Halad 344,.16%LWL,2%CFR-2 in 8-1/2"Hole 133/8 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 145' N/A 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,481' 0.150 9-5/8" Production 47/NT8Os/NSCC 8.681 Surface 9,204' 0.0732 9-5/8" Production 47/NT95HS/NSCC 8.681 9,204' 11,057' 0.0732 7" Liner 29/L-80/TKC Btrs 6.184 10,808' 11,839' 0.0372 9-5/8"Casing TUBING DETAIL W Leak between: 3-1/2" Kill String 9.2#/L-80/EUE 2.992 Surface 3,535' 0.0087 5,200'-5,300'and 4-1/2" Tubing 12.6/L-80/DSS 3.958 10,716' 10,767' 0.0152 3-1/2" Tubing 9.2#/L-80/TDS 2.992 10,767' 10,870' 0.0087 WELL INCLINATION DETAIL KOP @ 5,000' ID Max Hole Angle=43 deg. @ 7,255' kt Angle at Top Perf=31 Deg.@ 11,306' ot F. q JEWELRY DETAIL 51 No Depth Item t '601 Mg Cut @ F` 10,716' i�' I C IIo 9,10&11 12 i TSC ,^c± Mill 13 9 10,741' BakerEB-1 Extra Long Tubing Seal Receptical-ID=3.735" 10 10,754.6' KBH-22 Anchor Seal Assembly,3.948" 4,', 11 10,755' Baker SAB-3, 9-5/8"x 4-1/2"H droset Packer,ID=4.750" t k.4Y 12 10,760' 194-60 Mill-out Extension,ID=6.00" {{ 13 10,767' 7"8rd Box X 3-1/2"TDS Pin XO,ID=2.972" i 14 'J 14 10,803' 3-1/2"Otis X Nipple,ID=2.75" li 15 10,835' 3-1/2"Otis XN Nipple,ID=2.635" i MnID=2.635" 1 .. i` +; 16 10,870' Wireline Entry Guide,2.992" @10,835' ° i 15 `+ ° PERFORATION DETAIL END Top Btm Top Btm '' 16 Sands (MD) (MD) (TVD) (TVD) FT Date Status Size SPF 9-5/8 e x 11,176' 11,278' 10,007' 10,094' 102 8/31/1987 Open 5" 5 11,306' 11,346' 10,118' 10,152' 40 5/16/2011 Open 2" 6 7 Marker Joint a 11,366' 11,396' 10,170' 10,195' 30 6/3/2003 Open 2-1/4" 6 @11,301' r 11,366' 11,430' 10,170' 10,225' 64 8/31/1987 Open 5" 5 END Sands I. 11,376' 11,377' 10,178' 10,179' 1 4/27/2003 Open 2-1/2" 5 11,396' 11,410' 10,195' 10,207' 14 4/27/2003 Open 2-1/2" 5 T0C11,740' 11,416' 11,430' 10,213' 10,225' 14 4/27/2003 Open 2-1/2" 5 Tagged 6/21/87 ry 11,480' 11,500' 10,268' 10,284 20 10/14/2016 Open 2-3/8" 5 Reference Perf Log:DLL/GR on 6/18/1987 e 4', GENERAL WELL INFO API:50-029-21731-00-00 TD=11,839'(MD)/TD=10,584'(TVD) Initial Completion -10/2/1987 PBTD=11,740'(MD)/PBTD=10,496'(TVD) See Perf Table for Dates Revised By:TTW 5/4/2017 • PFOPOSED SCHEMATIC Duck Island Unit Well: END 4-42 Rev1 - 5-1/2" Scab Liner Last Completed: 10/2/1987 ililcoru Alaska,IIA PTD: 187 056 SAFETY NOTES TREE&WELLHEAD KB Elev.:55.18/BF Elev.:16.8 H2S Readings Average 230-260 PPM on A/L&Gas Injectors Tree CIW 4-1/16" Well Requires a SSSV Wellhead MCEVOY 13-5/8" 30^t-, OPEN HOLE/CEMENT DETAIL a 13-3/8" 4,348 cu/ft Permafrost in 17.5"Hole 1 `-+ 9-5/8" 575 cu/ft Class'G',.75%CFR-2=0.12%HR-7 in 12-1/4"Hole 7" 375 cu/ft Class"G",.5%Halad 344,.16%LWL,2%CFR-2 in 8-1/2"Hole 13-3/8",` CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 145' N/A 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,481' 0.150 9-5/8" Production 47/NT8Os/NSCC 8.681 Surface 9,204' 0.0732 9-5/8" Production 47/NT95HS/NSCC 8.681 9,204' 11,057' 0.0732 7" Liner 29/L-80/TKC Btrs 6.184 10,808' 11,839' 0.0372 5-1/2" Scab Liner 17/P-110/GeoConn 4.892 ±4,800' ±10,680' 0.0232 _ ►7.-4 2&3 \o TUBING DETAIL LkSj'D 4 .. SLw 1-44" Lift ria 3-1/2" Tubing 9.2#/L-80/EU E 2.992 Surface ±10,720' 0.0152 � ,, J �� 4-1/2" Tubing 12.6/L-80/DSS 3.958 ±10,720' 10,767' 0.0152 5.�+"w / 3-1/2" Tubing 9.2#/L-80/TDS 2.992 10,767' 10,870' 0.0087 WELL INCLINATION DETAIL GENERAL WELL INFO KOP @ 5,000' API:50-029-21731-00-00 Max Hole Angle=43 deg. @ 7,255' Initial Completion -10/2/1987 Angle at Top Perf=31 Deg.@ 11,306' See Perf Table for Dates JEWELRY DETAIL `. - 5 No Depth Item 3W 687 1 ±1,600' 3.5"X Nipple-ID=2.813" g Cl 514.. 2 ±4,800' 9-5/8"x7"WFD Liner Top Packer 10 9Y 3 ±4,810' 9-5/8"x7"WFD Liner Hanger j SC-IV4 ±4,820' 7"x5-1/2"xo 11±12 L414y612.. 5 ±10,675' 3-1/2"X Nipple(ID=2.813") 6 ±10,680' 5-1/2"Stage Tool 13-16 7 ±10,690' 5-1/2"WFD Annular Casing Packer rl z; 17 8 ±10,695' 5-1/2"x4"xo 9 ±10,705' 4"Sealbore Assembly,ID=4.0" 10 ±10,705' 4"Seal Assembly,ID=2.992" 11 ±10,715' 4"x5-1/2"xo 12 ±10,716' 4-1/2"Overshot '1 18 ti,1 i 13 10,741' BakerEB-1 Extra Long Tubing Seal Receptical-ID=3.735" 14 10,754.6' KBH-22 Anchor Seal Assembly,3.948" Min ID=2.635 15 10,755' Baker SAB-3, 9-5/8"x 4-1/2"Hydroset Packer,ID=4.750" @10,835' ----w t9 ,> 16 10,760' 194-60 Mill-out Extension,ID=6.00" 17 10,767' 7"8rd Box X 3-1/2"TDS Pin XO,ID=2.972" 20 - 18 10,803' 3-1/2"Otis X Nipple,ID=2.75" 35/8":, 19 10,835' 3-1/2"Otis XN Nipple,ID=2.635" 14 10,870' Wireline Entry Guide,2.992" 7"Marker Joint 11,17L @11,301'�� PERFORATION DETAIL END Top Btm Top Btm s Sands (MD) (MD) (TVD) (ND) FT Date Status Size SPF s 11,176' 11,278' 10,007' 10,094' 102 8/31/1987 Open 5" 5 TOC 11,740' 11,306' 11,346' 10,118' 10,152' 40 5/16/2011 Open 2" 6 Tagged 6/21/87 11,366' 11,396' 10,170' 10,195' 30 6/3/2003 Open 2-1/4" 6 END Sands 11,366' 11,430' 10,170' 10,225' 64 8/31/1987 Open 5" 5 11,376' 11,377' 10,178' 10,179' 1 4/27/2003 Open 2-1/2" 5 11,396' 11,410' 10,195' 10,207' 14 4/27/2003 Open 2-1/2" 5 7 'a' ,6 11,416' 11,430' 10,213' 10,225' 14 4/27/2003 Open 2-1/2" 5 TD=11,839'(MD)/TD=10,584'(lVD) 11,480' 11,500' 10,268' 10,284 20 10/14/2016 Open 2-3/8" 5 PBTD=11,740'(MD)/PBTD=10,496'(TVD) Reference Perf Log:DLL/GR on 6/18/1987 Revised By:TTW 5/3/2018 • • Endicott ASR 13-5/8"BOP 03/27/2018 ,- renal Hydril or Shaffer 13 5/8"5M til it! Ill Ill tI$ WI 1in 1 1 tot — — Spacer Spool 13 5/8"5M x 13 5/8"SM 111.1111.11111111.111 r CIW or Shaffer )1= 3 1/2"x 5 1/2"VBR Rams C121( 13 5/8"5M Blinds 2 1/16"5M Kill Valves ' 2 1/16"5M Choke Valves Manual and Manual • Manual and HCR • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday,April 27, 2018 4:46 PM To: Taylor Wellman Subject: Re: DIU Endicott 4-42 RWO Sundry#318-153 Change Request(PTD#187-056) Taylor, Approval granted to run kill string as proposed and moved off well with ASR 1. Hilcorp to evaluate casing leak and gather needed equipment in to repair at later date. Regards, Guy Schwartz AOGCC Sent from my iPhone On Apr 27,2018,at 2:57 PM,Taylor Wellman<twellman@hilcorp.com>wrote: Mr. Schwartz, During the RWO of DIU Endicott well 4-42 (PTD#187-056)we have determined that there is a casing leak in the 9-5/8"casing between 5,200'—5,300' md. This was found during the test packer run on Step 32 of the approved Sundry(#318-153). At this time we are not set up to be able to repair the casing leak. We would like to move the ASR#1 off the well in order to gather the equipment needed for the repair of the 9-5/8" casing leak and then complete the well. Enclosed are a current schematic of the well and a proposed schematic for the way we would like to leave the well until we come back to complete the RWO. We would like leave a kill string to 3,500' and for the following reasons: - Running a caliper to assess the condition of the 9-5/8"casing to see if a scab liner would need to be run higher than 5,200' and (location of passing pressure test). - Minimal risk for high pressure on the well. BHP=3,091psi a 10,000'tvd(6.0ppg)was taken on 10/29/15. During the initial well kill,we attempted to circulate the well clean. Circulation path was down the tubing,through the tubing cut and up the IA. 200bbls were pumped with only 30bbls returned. Throughout the RWO,attempts to load and circulate have been unsuccessful to catch any pressure at 3bpm. The fluid level has been remaining at—1,600' md. Thank you and let me know if you would like any further details, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer:Alaska North Slope Team Office: (907)777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com <END 4-42 SCHEMATIC 4-27-2017.pdf> 1 • <END 4-42 PROPOSEDOEMATIC-Kill String 4-27-2017.pdf> 2 SOF T� S • \ I 77,�sv THE STATE Alaska Oil and Gas 1,,11 'VA _fALAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 9 07 279.1433 of ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCOW Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU SDI 4-42 Permit to Drill Number: 187-056 Sundry Number: 318-153 Dear Mr. York: 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, Hollis S. French Chair -I DATED this 1 l day of April, 2018. RBDM APR 111018 0 0 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 6 2018 APPLICATION FOR SUNDRY APPROVALS OtS 4//i� �8' 20 AAC 25.280 ACS G , 1.Type of Request: Abandon El Plug Perforations El Fracture Stimulate El Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing D . MIT-IAD Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well El Alter Casing El Other: Complete El- 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory 0 Development ❑ 187-056 - 3.Address: 3800 Centerpoint Dr,Suite 14006.API Number: Stratigraphic EI ❑✓ Anchorage Alaska 99503 50-029-21731-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.462.007 Will planned perforations require a spacing exception? Yes ❑ No D DUCK IS UNIT SDI 4-42 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047502 • ENDICOTT/ENDICOTT OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,839' • 10,584' . 11,740' 10,496' 2,000 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 145' 30" 145' 145' N/A N/A Surface 2,481' 13-3/8" 2,481' 2,481' 5,020psi 2,260psi Production 9,204' 9-5/8" 9,204' 8,449' 6,870psi 4,760psi Production 1,853' 9-5/8" 11,057' 9,906' 8,150psi 5,090psi Liner 1,031' 7" 11,839' 10,584' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4-1/2" 12.6#/L-80/DSS 10,767 See Schematic See Schematic 3-1/2" 9.2#/L-80/TDS 10,870 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SAB-3 Packer and 4-1/2"OTIS HXO 10,755(MD)/9,657(TVD and 1,611(MD)/1,611(TVD) 12.Attachments: Proposal Summary D Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch D Exploratory ❑ Stratigraphic 0 Development❑ Service D ' 14.Estimated Date for 15.Well Status after proposed work: 4/21/2018 Commencing Operations: OIL ❑ WINJ El " WDSPL El Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ El 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. Authorized Name: Bo York Contact Name: Taylor Wellman --7--21,1 Authorized Title: Operations Manager Contact Email: twellman(CT7hiIcorp.com Contact Phone: 777-8449 Authorized Signature: Date: 4/4/2018 COMMISSION USE ONLY Conditions of approval. otify Commission so that a representative may witness Sundry Number: 313_ 153 Plug Integrity ❑ BOP Test Nj/ Mechanical Integrity Test 1 Location Clearance I=1Other: .' 3000 /0S L , o f'/ 7 T t— LJ 41.1-...0,-K J. 4-4A4-1- to/4_4_¢.i-'"1'.'vf- G�/0c i'i.v-di) 4'w". •---- ' 4� Z��Z . l�� Post Initial Injection MIT Req'd? Yes ❑ No Elc �� ' Spacing Exception Required? Yes ❑ No 121/ Subsequent Form Required: 10 L(() 1�/ RBDM�7 APPROVED BY Approved by: .. COMMISSIONER THE COMMISSION Date: Li 1%' 1,-.. -,,,.4--- 44-f:,,b, CPC \^` 1 -j D�I A t SentsinFormane al'�`A� Form 10-403 Revised 4/2017 Approved apple 'IF IkJV� 1�1HO�s rom the to of 4-1`)-18approval. Attachments in Duplicate RWO—Tbg Swap • • Well: END 4-42 PTD: 187-056 Hileorp Alaska,LL) API: 50-029-21731-00 Well Name: END 4-42 API Number: 50-029-21731-00 Current Status: S/I—TxIA Comm Rig: ASR#1 Estimated Start Date: April 21, 2018 Estimated Duration: 8 Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 187-056 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907)947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8847 (0) (509) 670-8001 (M) AFE: WeIIEZ Entry Required: Yes Current Bottom Hole Pressure: 3,091 psi @ 10,000' TVD (Based on SBHPS taken on 10/29/15) Maximum Expected BHP: 3,091psi @ 10,000' TVD (Based on SBHPS taken on 10/29/15) Equivalent MW: 6.0ppg Max.Anticipated Surface Pressure: 2,000psi (Highest recorded tbg pressure—GL system pressure) Brief Well Summary: Endicott Well 4-42 was drilled and completed in September 1987. The well was completed as an USZ producer in the FIII, FIV, and FV sands. The well has had multiple cement squeezes performed for water shut off. By the end of 2012 the well's production and declined to<20bopd. Additional perforations were added in the FII in 2016 which provided a short term buzz before watering out. In early 2017 the well was converted to a water injector. During the conversion,the well failed an MIT-IA. Further diagnostics indicated a packer leak with an LDL run on 05/22/17. All topside facilities have been converted but the well has not passed an MIT-IA and has not injected any water to date. RWO Objective: 1. Pull the tubing and run a new completion with a stacker packer to regain a competent IA. - 2. Place well on injection and obtain MIT-IA once stabilized on injection. ***VARIANCE REQUEST***: Requesting a variance to 20AAC25.412(b). Uppermost 9-5/8" packer will be set greater than 200ft measured depth from open perfs. Proposed distance=551ft. Pre-Workover Prep Procedure (non-sundried steps): 1. Spot Slickline unit and RU unit. 2. Pressure test lubricator to 300psi low/2,000psi high. a. Use GL system pressure. 3. Pull prong and 3-1/2" PXN plug body from 10,835' md. 4. Drift for 4-1/2" chem cutter to 10,750' md. 5. RD SL unit. Sundried Operations—Approved sundry required before proceeding 6. RU E-Line unit and pressure test to 300psi low/2,000psi high. a. Use GL system pressure. 7. RIH and chem cut tubing at±10,716' and (mid 15t full joint above packer). RWO—Tbg Swap . • Well: END 4-42 PTD: 187-056 Hilcorp Alaska,LU API: 50-029-21731-00 a. No tubing punches required. There is a suspected packer leak and the IA has been liquid packed. b. Increase tubing pressure slightly(50-100psi) above IA prior to cut to confirm communication post cut. c. Reference Log: END 4-42 Tubing Tally dated 09/31/87 8. RD E-Line unit. Operations& Pumping 9. Clear and level pad area in front of well. Spot rig mats and containment. 10. RD well house and flowlines. Clear and level area around well. 11. RU Little Red Services Pump.Setup reverse out skid and 500 bbl returns tank and additional upright tanks as needed. 12. Pressure test lines to 3,000 psi. 13. Attempt to circulate out any gas from the well by pumping down the tubing and taking returns from the IA. a. IA fluid level was at 1600' and on 5/22/17 so no freeze protect was pumped on the IA. ?��p 14. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 15. RD Little Red Services Pump and reverse out skid. 16. RU crane. Set BPV. ND Tree. NU 13-5/8" BOPE. RD crane. 17. NU BOPE house.Spot mud boat. LA--/12 Workover Workover Procedure: 18. Move ASR#1 over from END 4-26. 19. Verify 0 psi on the annulus and tubing pressure. 20. Set BPV, ND tree, NU 13-5/8" BOP's. a. Make scribe mark on tree for orientation for re-installation. b. Function test all prior to arrival of AOGCC inspectors. 21. Spot and rig up ASR#1 and all supporting equipment. 22. Check for pressure and if Opsi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, circulate 8.5ppg seawater and confirm dead prior to pulling BPV. Set TWC. 23. Test BOPE to 250psi Low/3,000 si High, annular to 250psi Low/2_1_5Npsi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. e a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. pee. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 3-1/2" &4-1/2"test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 24. Conti (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.) a. 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 test. b. With stack out of the test path,test choke manifold per standard procedure RWO—Tbg Swap • • Well: END 4-42 PTD: 187-056 Hilcary Alaska,Lb API: 50-029-21731-00 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. 25. Bleed any pressure off casing to 500bbl returns tank. Pull TWC. 26. MU 4-1/2" landing joint and BOLDS. 27. Pull over string weight on tubing and confirm free (original drilling reports did not record PU/SO weights). Once hanger becomes free check for flow to insure well is dead. LD Tubing hanger. a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. b. Contingency: (If the tubing hanger will not pull and it is determined to be a pulling capacity ( limitation vs. a partial tubing cut) i. RU Casing jack Hydraulics to the ASR#1 control Panel. Set pressure relief high point as 2,038 psi (equates to—230.4k#or 80%of yield strength). ii. Yield strength of 4-1/2", 12.6#, L-80= 288k#, and the Mannesmann TDS connections= C.`'evifi'l 288k#. iii. Cycle jacks up and down to ensure proper function (dry run without being connected to ,, hanger). / iv. Set Casing Jack pressure to 1,415 psi (160,000 lbs). Slowly pressure up on jacks. Hold for 5 min. v. If hanger does not unseat, increase pressure in 10k#("88psi) increments holding for 5 min between pressure increases. Note: do not exceed 2,038 psi (230,400#). If unmoved contact Ops Engineer for further discussion. 28. RU Spoolers and continue to pull 4-1/2"tubing from cut at±10,716', and lay down the same in singles. a. From 0—1,611'there are two%" control lines(balance and control line)to the OTIS HXO nipple. 29. PU 3-1/2" workstring and MU used 4-1/2" polish mill and 9-5/8" casing scraper assembly. TIH and reciprocate around ±10,490'—10,690' md. Dress off tubing stub. 30. Circulate if possible until returns are clean and TOOH. 31. MU 9-5/8"test packer,TIH and set at±10,600' md. 32. Pressure test the 9-5/8" casing to 2500psi. /C./ 33. Unseat the test packer and TOOH while laying down the workstring. 34. MU and run the 3-1/2" injection string completion. a. Confirm configuration with proposed running order sheet. 35. Record PU and SO weights prior to spacing out on top of the tubing stub. 36. Slip over the tubing stub and confirm over with the shear pins in the 4-1/2" non-sealing overshot. 37. PU and space out and then land the tubing string. RWO—Tbg Swap • • Well: END 4-42 PTD: 187-056 Hilcorp Alaska,Lia API: 50-029-21731-00 a. Packer setting depth is±10,590' md. 38. PU and reverse circulate 510bbls of seawater with corrosion inhibitor followed by 140bbIs of diesel. 39. Land the tubing hanger and RILDS. Lay down landing joint. Test tubing hanger packoff to 5,000 psi. 40. Drop the ball & rod and set the packer. Increase the pressure and test the tubing to 3,000 psi. 41. Perform an MIT-IA to 2500psi for 30 min (charted). o a. Notification to the AOGCC for witnessed test needs to be submitted 24 hrs prior to conducting test. 42. Set BPV.Test tubing hanger to 250/5,000psi thru test port. 43. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. Post Workover Procedure: 44. RD mud boat. RD BOPE house. 45. RU crane. ND BOPE. Pull BPV.Set TWC. 46. NU 4-1/16" 5,000#tree and adapter flange and test to 500 psi low/5,000 psi high. 47. Test tubing hanger void to 500psi low/5,000psi high. 48. Pull TWC. RD crane. 49. Move 500bbI returns tank and rig mats. 50. Spot Slickline unit and RU. 51. Pressure test lubricator to 300psi low and 4,000psi high. 52. Pull ball and rod from 3-1/2"XN nipple at±10,680' md. 53. RD Slickline. ,),If 54. Turn well over to production. 55. Once well online and stable contact AOGCC for witnessed MIT-IA(pressure to be determined by actual ON' `L` packer set depth:0.25 x packer tvd). 4w Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Duck Island Unit H . Well: END 4-42 PRO SED SCHEMATIC Last Completed: 10/2/1987 Hamra Alaska,LLC PTD: 187-056 SAFETY NOTES TREE&WELLHEAD KB Elev.:55.18/BF Elev.:16.8 H2S Readings Average 230-260 PPM on A/L&Gas Injectors Tree CIW 4-1/16" ii...) 30 4li Well Requires a SSSV Wellhead MCEVOY 13-5/8" OPEN HOLE/CEMENT DETAIL 13-3/8" 4,348 cu/ft Permafrost in 17.5"Hole - 1 9-5/8" 575 cu/ft Class'G',.75%CFR-2=0.12%HR-7 in 12-1/4"Hole 7" 375 cu/ft Class"G",.5%Halad 344,.16%LWL,2%CFR-2 in 8-1/2"Hole 13-3/g'A CASING DETAIL - Size Type Wt/Grade/Conn Drift ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 145' N/A 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,481' 0.150 9-5/8" Production 47/NT80s/NSCC 8.681 Surface 9,204' 0.0732 9-5/8" Production 47/NT95HS/NSCC 8.681 9,204' 11,057' 0.0732 7" Liner 29/L-80/TKC Btrs 6.184 10,808' 11,839' 0.0372 TUBING DETAIL 3-1/2" Tubing 9.2#/L-80/EUE 2.992 Surface ±10,720' 0.0152 ' 4-1/2" Tubing 12.6/L-80/DSS 3.958 ±10,720' 10,767' 0.0152 X61. J`� 3-1/2" Tubing 9.2#/L-80/TDS 2.992 10,767' 10,870' 0.0087 ( N�� ki'y I‘ WELL INCLINATION DETAIL h/ KOWELL @ 5,000' t Max Hole Angle=43 deg. @ 7,255' _ 2 I°�L,j' `�z( Angle at Top Perf=31 Deg.@11,306' rkr*3 N AJEWELRY DETAIL i 4 tt No Depth Item " g1 ±1,600' 3.5"X Nipple-ID=2.813" ,?, j 5 N 2 ±10,565' 3-1/2"X Nipple(ID=2.813") iz ' 41 3 ±10,625' 9-5/8"x3-1/2"Packer IP47 4 ±10,665' 3-1/2"X Nipple(10=2.813") )' 6 1 5 ±10,705' 3-1/2"XN Nipple(ID=2,75") 6 ±10,715' 5-1/2"Overshot 7-10 w 7V i 7 10,741' BakerEB-1 Extra Long Tubing Seal Receptical-ID=3.735" 11� 8 10,754.6' KBH-22 Anchor Seal Assembly,3.948" 9 10,755' Baker SAB-3, 9-5/8"x 4-1/2"Hydroset Packer,10=4.750" `is 10 10,760' 194-60 Mill-out Extension,10=6.00" t' c 11 10,767' 7"8rd Box X 3-1/2"TDS Pin XO,ID=2.972" ?1 Pik'" 12 10,803' 3-1/2"Otis X Nipple,I0=2.75" 12 . 5.1Y 13 10,835' 3-1/2"Otis XN Nipple,ID=2.635" 14 10,870' Wireline Entry Guide,2.992" Kin 1 2.635" .._� r i @10835' 111 13 IA P PERFORATION DETAIL i ti. 14 END Top Btm Top Btm FT Date Status Size SPF 9-5/8 ' Sands (MD) (MD) (TVD) (TVD) j 11,176' 11,278' 10,007' 10,094' 102 8/31/1987 Open 5" 5 V ; 11,306' 11,346' 10,118' 10,152' 40 5/16/2011 Open 2" 6 7"MarkerJointtl 40 IOU'. 11,366' 11,396' 10,170' 10,195' 30 6/3/2003 Open 2-1/4" 6 @11,301' ► END Sands 11,366' 11,430' 10,170' 10,225' 64 8/31/1987 Open 5" 5 11,376' 11,377' 10,178' 10,179' 1 4/27/2003 Open 2-1/2" 5 ,,, 11,396' 11,410' 10,195' 10,207' 14 4/27/2003 Open 2-1/2" 5 TOC 11,740' 11,416' 11,430' 10,213' 10,225' 14 4/27/2003 Open 2-1/2" 5 Tagged 6/21/87 11,480' 11,500' 10,268' 10,284 20 10/14/2016 Open 2-3/8" 5 Reference Perf Log:DLL/GR on 6/18/1987 GENERAL WELL INFO 7"i,,,, ` .. :., API:50-029-21731-00-00 TD=11,839'(MD)/TD=10,584'(WD) Initial Completion -10/2/1987 PBTD=11,740'(MD)/PBTD=10,496'(TVD) See Perf Table for Dates Revised By:TTW 4/3/2018 0 Duck Island Unit Well: END 4-42 H • SCHEMATIC Last Completed:10/2/1987 Hilcuru Alaska,LLc PTD: 187-056 SAFETY NOTES TREE&WELLHEAD KB Elev.:55.18/BF Elev.:16.8 H2S Readings Average 230-260 PPM on A/L&Gas Injectors Tree CIW 4-1/16" J Well Requires a SSSV Wellhead MCEVOY 13-5/8" I" 'sY OPEN HOLE/CEMENT DETAIL 13-3/8" 4,348 cu/ft Permafrost in 17.5"Hole 1 9-5/8" 575 cu/ft Class'G',.75%CFR-2=0.12%HR-7 in 12-1/4"Hole 7" 375 cu/ft Class"G",.5%Halad 344,.16%LWL,2%CFR-2 in 8-1/2"Hole 13-3/8" CASING DETAIL a Size Type Wt/Grade/Conn Drift ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 145' N/A 1‘, 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,481' 0.150 2 9-5/8" Production 47/NT80s/NSCC 8.681 Surface 9,204' 0.0732 9-5/8" Production 47/NT95HS/NSCC 8.681 9,204' 11,057' 0.0732 7" Liner 29/L-80/TKC Btrs 6.184 10,808' 11,839' 0.0372 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/DSS 3.958 Surface 10,767' 0.0152 F 3; .. 3-1/2" Tubing 9.2#/L-80/TDS 2.992 10,767' 10,870' 0.0087 WELL INCLINATION DETAIL KOP @ 5,000' Max Hole Angle=43 deg. @ 7,255' Angle at Top Perf=31 Deg.@ 11,306' 5 JEWELRY DETAIL No Depth Item 6 1 1,611' 4.5"OTIS HXO Nipple-ID=3.813" . •( k`l GLM DETAIL Camco 4.5"x 1.5"Valve w/RK Latch 1 ' �� 2 4,198' STA 6:Dev=0,VLV=DMY,Port=?,TVD=4,198',Date=5/4/17 3 6,476' STA S:Dev=37,VLV=DMY,Port=0,TVD=6,379',Date=3/25/17 4 8,402' STA 4:Dev=39,VLV=DMY,Port=0,TVD=7,833',Date=3/24/17 4¢ 8 5 9,593' STA 3:Dev=38,VLV=DMY,Port=0,TVD=8,756',Date=3/18/03 6 10,434' STA 2:Dev=39,VLV=DMY,Port=0,TVD=9,404',Date=9/31/87 t.lt7 10,579' STA 1:Dev=38,VLV=DMY,Port=0,TVD=9,517',Date=3/18/03 iON l. 9.1O&11 ` 8 10,684' 4-1/2"OTIS XA Sliding Sleeve,ID=3.813" S 12 �� 9 10,741' BakerEB-1 Extra Long Tubing Seal Receptical-ID=3.735" VIIIF 13 (C 10 10,754.6' KBH-22 Anchor Seal Assembly,3.948" ` 11 10,755' Baker SAB-3, 9-5/8"x 4-1/2"Hydroset Packer,ID=4.750" e.. 1' 12 10,760' 194-60 Mill-out Extension,ID=6.00" i, 13 10,767' 7"8rd Box X 3-1/2"TDS Pin XO,ID=2.972" t4 14 10,803' 3-1/2"Otis X Nipple,ID=2.75" 15 10,835' 3-1/2"Otis XN Nipple,I0=2.635" ***PXN plug set 4/19/17*** . .-4 I..... 16 10,870 --...: a c. 2.992 Mn 10=2 635" @10,836 .��__,_,_._.._..__... PERFORATION DETAIL Ito,ii15 END Top Btm Top Btm '_ 16 l Sands (MD) (MD) (TVD) (TVD) FT Date Status Size SPF 9-5/g f' 11,176' 11,278' 10,007' 10,094' 102 8/31/1987 Open 5" 5 11,306' 11,346' 10,118' 10,152' 40 5/16/2011 Open 2" 6 7'Marker Joint =kr 11,366' 11,396' 10,170' 10,195' 30 6/3/2003 Open 2-1/4" 6 @11,301' 11,366' 11,430' 10,170' 10,225' 64 8/31/1987 Open 5" 5 END Sands 11,376' 11,377' 10,178' 10,179' 1 4/27/2003 Open 2-1/2" 5 " 11,396' 11,410' 10,195' 10,207' 14 4/27/2003 Open 2-1/2" 5 TOC 11,740' ti; • 11,416' 11,430' 10,213' 10,225' 14 4/27/2003 Open 2-1/2" 5 Tagged 6/21/87'' 11,480' 11,500' 10,268' 10,284 20 10/14/2016 Open 2-3/8" 5 Reference Perf Log:DLL/GR on 6/18/1987 GENERAL WELL INFO 7". ‘1,:-",1, API:50-029-21731-00-00 TD=11,839'(MD)/TD=10,584'(TVD) Initial Completion -10/2/1987 PBTD=11,740'(MD)/PBTD=10,496'(1VD) See Perf Table for Dates Revised By:.ICM 4/20/2017 • . Endicott ASR 13-5/8"BOP flt#roiA s,i.U. 03/Z7/2018 I ! III 111 Iih Iili lill lull Iii Hydril or Shaffer i/ . 13 S/8" 5M III1II'11Y11111i '(Ii E i •I 111 11 1;1 1 1; I )'I; III Spacer Spool 13 5/8"5M x 13 5/8"5M 1 I t 1, 1 1 1; 1 1 1;11 11 11 1 r _ /, .. ' C.iY/of lil,l i r .i — _a--i 3 1/2"x S 1/2"VBR Rams t 5'8"'5M rf,, . L:3 Blinds 2 1/16" 5M Kill Valves MT 2 1/16" 5M Choke Valves Manual and Manual Manual and HCR illiII 'IVi iiia III i i..-- "Jill �� i ,i _ 1 „LAI} . ii,",,,,, , 1 • i �. f 1 ., _ ...i ...l , ,. a te' . _ .., • • Davies, Stephen F (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Friday, April 6, 2018 1:34 PM To: Davies, Stephen F (DOA) Subject: RE: DIU SDI 4-42 (PTD 187-056; Sundry 318-153) - Conversion to Injector Attachments: END 4-42 AOGCC 10-404 SUBMITTAL 4-6-2018.pdf Steve, You are correct on the documentation side for this well. The 10-404 to close out the conversion was actually submitted today along with the new 10-403 application. The perfs that we shot in the well extended the life of the well for a time and then we encountered mechanical issues (failed MIT-IA) with the well during the conversion. A leak detect log ran indicated a packer leak and the new 10-403 is aimed at repairing this leak and then completing the required steps (Witnessed MIT-IA's) prior to and after stabilized injection. Enclosed is an electronic copy of the operations. If there is other information you'd like to see let me know and I will provide. Thank you, Taylor Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Alaska North Slope Team Office: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Friday, April 06, 2018 12:26 PM To: Taylor Wellman Subject: DIU SDI 4-42 (PTD 187-056; Sundry 318-153) - Conversion to Injector Taylor, I'm reviewing Hilcorp's Application for Sundry Approvals for the re-completion and MIT-A of DIU SDI 4-42. Hilcorp's application lists this well as an injector, but I noticed that it is still listed in AOGCC's database as a development well. So I checked AOGCC's files. In Sept 2016, AOGCC approved Sundry Application 316-454 to perforate the well and convert it to an injector. On that application, Hilcorp listed the estimated date for commencing operations as 10/1/2016. One condition of AOGCC's approval for that application was that Hilcorp submit a subsequent Sundry Report (Form 10-404) documenting the perforation and conversion operations. Hilcorp's current Sundry Application, 318-153, states that the well was converted to an injector in early 2017. I don't see the Sundry Report for conversion to an injector in the AOGCC's files, or in the document logs that our receptionist maintains. Did Hilcorp submit that required Sundry Report? If so, could you please provide a duplicate copy? If not, could you please submit a Sundry Report to document the work that was done? Thank you, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use 1 or disclosure of such information may violate•or federal law.If you are an unintended recipient of thissil,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies( alaska.gov. 2 STATE OF ALASKA E, cD ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 0 6 2018 1.Operations Abandon Li Plug Perforations U Fracture Stimulate U Pull Tubing U •�!-- � s. own U Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter CasingiIj ❑i ❑ Conveonve"to ector Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:MIT ❑✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 187-056 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-21731-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047502 DUCK IS UNIT SDI 4-42 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A ENDICOTT/ENDICOTT OIL 11.Present Well Condition Summary: Total Depth measured 11,839 feet Plugs measured N/A feet true vertical 10,584 feet Junk measured N/A feet Effective Depth measured 11,740 feet Packer measured 10,755 feet true vertical 10,496 feet true vertical 9,657 feet Casing Length Size MD TVD Burst Collapse Conductor 145' 30" 145' 145' N/A N/A Surface 2,481' 13-3/8" 2,481' 2,481' 5,020psi 2,260psi Production 9,204' 9-5/8" 9,204' 8,449' 6,870psi 4,760psi Production 1,853' 9-5/8" 11,057' 9,906' 8,150psi 5,090psi Liner 1,031' 7" 11,839' 10,584' 8,160psi 7,020psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6#/L-80/DSS 10,767' 9,667' Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80/TDS 10,870' 9,751' 1,611'MD Packers and SSSV(type,measured and true vertical depth) SAB-3 4-1/2"OTIS HXO See Above 1,611'TVD 12.Stimulation or cement squeeze summary: N/A 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 I Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 2,000 0 Subsequent to operation: 0 0 0 400 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory Development❑ Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ 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: 316-454 Authorized Name: Bo York Taylor Wellman Contact Name: Y Authorized Title: Operations Manager Contact Email: twellman hilcorp.corn Authorized Signature: Dati 4/4/2018 Contact Phone: 777-8449 Form 10-404 Revised 4/2017 )1/ RBDMS)() Ai* 0 b 2018 Submit Original Only • 111 Duck Island Unit Well: END 4-42 SCHEMATIC Last Completed: 10/2/1987 am LLC PTD: 187-056 H SAFETY NOTES TREE&WELLHEAD KB Elev.:55.18/BF Elev.:16.8 H2S Readings Average 230-260 PPM on A/L&Gas Injectors Tree CIW 4-1/16" . v,L j : Well Requires a SSSV Wellhead MCEVOY 13-5/8" 30 OPEN HOLE/CEMENT DETAIL 13-3/8" 4,348 cu/ft Permafrost in 17.5"Hole 1" 1 r 9-5/8" 575 cu/ft Class`G',.75%CFR-2=0.12%HR-7 in 12-1/4"Hole 7" 375 cu/ft Class"G",.5%Halad 344,.16%LWL,2%CFR-2 in 8-1/2"Hole 133/g CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 145' N/A 13-7513:./288,r,," Surface 68/L-80/Btrs 12.415 Surface 2,481' 0.150 2 9 5/8" Production 47/NT80s/NSCC 8.681 Surface 9,204' 0.0732 9- Production 47/NT95HS/NSCC 8.681 9,204' 11,057' 0.0732 Liner 29/L-80/TKC Btrs 6.184 10,808' 11,839' 0.0372 TUBING DETAIL 4- Tubing 12.6/L-80/DSS 3.958 Surface 10,767' 0.0152 3 3-1/2" Tubing 9.2#/L-80/TDS 2.992 10,767' 10,870' 0.0087 WELL INCLINATION DETAIL KO @ 5,000' Max Hole Angle=43 deg. @ 7,255' 4 Angle at Top Perf=31 Deg.@ 11,306' 5 JEWELRY DETAIL 111 No Depth Item 6 1 1,611' 4.5"OTIS HXO Nipple-ID=3.813" GLM DETAIL:Camco 4.5"x 1.5"Valve w/RK Latch 72 4,198' STA 6:Dev=0,VLV=DMY,Port=?,TVD=4,198',Date=5/4/17 3 6,476' STA 5:Dev=37,VLV=DMY,Port=0,TVD=6,379',Date=3/25/17 4 8,402' STA 4:Dev=39,VLV=DMY,Port=0,TVD=7,833',Date=3/24/17 8 fl 9,593' STA 3:Dev=38,VLV=DMY,Port=0,TVD=8,756',Date=3/18/03 j: 6 10,434' STA 2:Dev=39,VLV=DMY,Port=0,TVD=9,404',Date=9/31/87 7 10,579' STA 1:Dev=38,VLV=DMY,Port=0,TVD=9,517,Date=3/18/03 t ins 1' 9,10&11 8 10,684' 4-1/2"OTIS XA Sliding Sleeve,ID=3.813" KK, '�4.44 13 6'12 /7. 9 10,741' BakerEB-1 Extra Long Tubing Seal Receptical-ID=3.735" r4.C 10 10,754. KBH-22 Anchor Seal Assembly,3.948" J 11 10,755' Baker SAB-3, 9-5/8"x 4-1/2"Hydroset Packer,ID=4.750" / Cr' 12 10,760' 194-60 Mill-out Extension,ID=6.00" `"�� 13 10,767' 7"8rd Box X 3-1/2"TDS Pin X0,10=2.972" 14 1 14 10,803' 3-1/2"Otis X Nipple,I0=2.75" F� 4 15 10,835' 3-1/2"Otis XN Nipple, I0=2.635" ***PXN plug set 4/19/17*** Iv1n ID=2.635" • 16 10,870' Wireline Entry Guide,2.992" @10,835' ' #' 15 PERFORATION DETAIL /" END Top Btm Top Btm FT Date Status Size SPF 95/8 16 ' Sands (MD) (MD) (TVD) (TVD) 11,176' 11,278' 10,007' 10,094' 102 8/31/1987 Open 5" 5 11,306' 11,346' 10,118' 10,152' 40 5/16/2011 Open 2" 6 7"Marker Joint 11,366' _ 11,396' 10,170' 10,195' 30 6/3/2003 Open 2-1/4" 6 @ 11,301' � 11,366' 11,430' 10,170' 10,225' 64 8/31/1987 Open 5" 5 END Sands 11,376' 11,377' 10,178' 10,179' 1 4/27/2003 Open 2-1/2" 5 11,396' 11,410' 10,195' 10,207' 14 4/27/2003 Open 2-1/2" 5 TOC 11,740' 11,416' 11,430' 10,213' 10,225' 14 4/27/2003 Open 2-1/2" 5 Tagged 6/21/87 11,480_' 11,500' 10,268' 10,284 20 10/14/2016 Open 2-3/8" 5 " Reference Perf Log:DLL/GR on 6/18/1987 1 4, tie' : . � '' GENERAL WELL INFO 7' *.Ftt,' API:50-029-21731-00-00 TD=11,839'(MD)/ID=10,584'(TVD) Initial Completion -10/2/1987 PBTD=11,740'(MD)/PBTD=10,496'(TVD) See Perf Table for Dates Revised By:TDF 4/2/2018 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-42 Slick line 50-029-21731-00-00 187-056 10/13/16 5/22/17 Daily Operations; 10/12/2016-Wednesday No activity to report. 10/13/2016-Thursday Well s/i on arrival, (P/T TO 300 LOW, 2050 HIGH) (drift for eling adperfs). WIND SPEEDS TOO HIGH FOR CRANE 10/14/2016- Friday well s/i on arrival, (P/T TO 300 LOW, 2050. HIGH) (drift for eline adperfs). CORRECTION TO MD=40' FROM WSR 10/29/15. RAN 20'x 2.60" BARBELL DRIFT(simulated 20' x 2.50"spent gun),TAGGED SOLID T/D @ 11,459' SLM, 11,499' MD. POLLARD ELINE TO ROLL IN BEHIND US TO SHOOT 20' OF PERFS. WELL LEFT SHUT IN - NOTIFIED PAD. OP OF DEPARTURE. Pollard: E- Line arrives on location. PJSM. Spot equipment and begin rigging up on well. PT to 250psi low/2,100psi high. RIH w/20' of perfs.Tag PBTD @ 11,506' and run gamma ray tie-in pass. Co-ordinate with engineer on tie-in log and make 2' adjustment down. Tag again and pull into position @ 11,472 (CCL Depth) and shoot 11,480'to 11,500'. Guns fired. POOH, RD and leave location. 10/15/2016-Saturday No activity to report. 10/16/2016-Sunday No activity to report. 10/17/2016- Monday Well s/i on arrival, (P/T TO 300 LOW, 2050 HIGH), set sssv. CLEARED RESTRICTION IN TUBING HANGER W/GAUGE RINGS SIZED 3.71" THROUGH 3.85". SET 3.813" X-LOCK, W/ BBE SSSV(ser# HBB4-100) 3 sets all std w/o-rings. CONTROL AND BALANCE WERE PURGED 2 GALLONS EACH, PASSING DRAW DOWN TEST TO 500 PSI DIFFERNTIAL. WELL TURNED OVER TO POP- NOTIFIED PAD OP OF DEPATURE. 10/18/2016-Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-42 Slickline 50-029-021731-00-00 187-056 10/13/16 5/22/17 Daily Operations: 3/1/2017-Wednesday No activity to report. 3/2/2017 -Thursday No activity to report. 3/3/2017- Friday No activity to report. 3/4/2017-Saturday No activity to report. 3/5/2017-Sunday PT PCE 250#-LOW/2,500#-HIGH. DRIFT TBG W/3.85" GAUGE RING TO 4-1/2" BBE AT 1,578' SLM (1,611' MD). PULLED 4- 1/2" BBE SSSV (ser#HBB4-100) FROM HXO NIP AT 1,578' SLM (1,611' MD) 3/6/2017- Monday PT PCE 250#-LOW/2,500#-HIGH. Pull GLV's from sta's#4,5&6. Set DGLV's in sta's#5 & 6. Set Circ valve in Sta #4. 3/7/2017-Tuesday PT PCE 250#-LOW/2,500#-HIGH. BRUSH TBG W/4-1/2" BRAIDED BRUSH &3.80" G. RING TO 10,680' SLM. SET 4-1/2" PX PLUG BODY IN XA SLIDING SLEEVE AT 10,654' SLM (10,684' MD) Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-42 Slickline 50-029-021731-00-00 187-056 10/13/16 5/22/17 Daily Operations: pro 3/8/2017-Wednesday PT PCE 250#-LOW/2,500#-HIGH. SET P-PRONG IN 4-1/2" PX PLUG BODY AT 10,648' SLM. BLEED TBG & IA DOWN TO ADJACENT FLOWLINE From 2,000PSI to 1,750 PSI. 3/9/2017-Thursday No activity to report. 3/10/2017- Friday No activity to report. 3/11/2017 -Saturday No activity to report. 3/12/2017-Sunday No activity to report. 3/13/2017- Monday No activity to report. 3/14/2017-Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-42 Slickline 50-029-21731-00-00187-056 10/13/16 5/22/17 Daily pperat 3/22/2017-Wednesday ***WELL SHUT IN UPON DEPARTURE*** (troubleshoot circ valve). SPOT IN UNIT ON END 4-42, CHANGE OUT DAY. REDRESS AND PRESSURE WIRELINE VALVES. 3/23/2017-Thursday WELL S/I ON ARRIVAL. .ATTEMPTED TO TEST WIRELINE VALVES BUT PRESSURE APPEARS TO BE LEAKING BY THE WING. HAVE GREASE CREW SERVICE THE TREE. ATTEMPT TO TEST WIRELINE VALVES AGAIN BUT HAVE SAME ISSUE AS PREVIOUS TEST. HAVE ERA SLING LOAD WIRELINE VALVES TO DEADHORSE. 3/24/2017- Friday WELL S/I ON ARRIVAL, PT 250/2,000 PSI, (GAS LIFT/TROUBLESHOOT). SET SLIP STOP CATCHER @ 8,493' SLM. PULLED 1-1/2" CIRC GLV FROM ST#4 @ 8,384'SLM (8,402' MD) (Confirmed vlv was in fact a circ vlv and also confirmed vlv not plugged) (IA not communicating with tbg still). SET 1-1/2" DGLV IN ST#4 @ 8,384' SLM (8,402' MD). 3/25/2017-Saturday WELL S/I ON ARRIVAL, PT 250/2,000 PSI, (PULL& SET GLV'S/TROUBLESHOOT). PULLED 1-1/2" DGLV IN ST#5 @ 6,454' SLM. (not able to verify tbg/ia communication). SET 1-1/2" DGLV IN ST#5 @ 6,454' SLM. PULLED 1-1/2" DGLV FROM ST#6 @ 4,174' SLM. SAW THE TUBING PRESSURE DROP AND IA PRESSURE increased (verify good commmunication). SET 1-1/2" CIRC VALVE RK LATCH IN ST#6 @ 4,174' SLM. PULLED SLIP STOP CATCHER @ 8,493' SLM. RDMO. 3/26/2017-Sunday No activity to report. 3/27/2017- Monday No activity to report. 3/28/2017-Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-42 Slickline 50-029-21731-00-00 187-056 10/13/16 5/22/17 Daily Operations: 4/12/2017-Wednesday No activity to report. 4/13/2017-Thursday **WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/2500H**. PULL P-PRONG (1.75" f/n, oal=96", 12 x 1/4" ports) FROM PX PLUG @ 10,647' SLM.ATTEMPT TO PULL 4-1/2" PX PLUG BODY FROM XA SSD @ 10,654' SLM/ 10,684' MD,JAR FOR 1hr, UNSUCCESSFUL(shear tool). 4/14/2017- Friday No activity to report. 4/15/2017-Saturday No activity to report. 4/16/2017-Sunday WILL CONT AT LATER DATE CONT TO PULL 4-1/2" PLUG BODY AND SET 3-1/2" PLUG. *****PRONG OUT OF THE HOLE- 4- 1/2" PX PLUG BODY STILL IN THE HOLE******. 4/17/2017- Monday No activity to report. 4/18/2017-Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number _ Well Permit Number Start Date End Date END 4-42 Slickline 50-029-21731-00-00 187-056 10/13/16 5/22/17 Daily Operations: 4/19/2017-Wednesday ***WELL SHUT-IN ON ARRIVAL*** (pull-set plug). PT PCE 250-LOW/2,200-HIGH. PULLED 4-1/2" PX PLUG BODY FROM XA SLIDING SLV AT 10,684' MD. SET 3-1/2" PXN PLUG BODY IN XN-NIP AT 10,812' SLM (10,835' MD). SET P-PRONG IN PXN PLUG BODY AT 10,804' SLM. ***WELL LEFT SHUT-IN ON DEPARTURE, DSO NOTIFIED***. 4/20/2017-Thursday No activity to report. 4/21/2017 - Friday No activity to report. 4/22/2017-Saturday No activity to report. 4/23/2017-Sunday No activity to report. 4/24/2017- Monday No activity to report. 4/25/2017-Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-42 Slickline 50-029-21731-00-00 187-056 10/13/16 5/22/17 Daily Operations ` 5/3/2017-Wednesday WELL S/I ON ARRIVAL, (GASLIFT), PT PCE 250/2,000 PSI. SET 4.5" SLIP STOP CATCHER @ 4,310' SLM, (OAL=40"). RAN 4.5" OM-1, 7" EXT, 1-5/8"JDC AND PULLED 1-1/2" CIRC VALVE FROM ST#6 @ 4,174'SLM (4,198' MD). 5/4/2017 -Thursday WELL S/I ON ARRIVAL, (GAS LIFT), PT PCE 250/2,200 PSI+A48. RAN 4.5" OM-1 AND SET 1-1/2" DGLV IN ST#6 @ 4,174' SLM (4,198' MD). RAN 4.5" GS AND PULLED SLIP STOP CATCHER @ 4,310' SLM. 5/5/2017- Friday No activity to report. 5/6/2017 -Saturday No activity to report. 5/7/2017 -Sunday No activity to report. 5/8/2017- Monday No activity to report. 5/9/2017-Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 4-42 Slickline 50-029-21731-00-00 187-056 10/13/16 5/22/17 Daily Operations: 5/17/2017-Wednesday No activity to report. 5/18/2017-Thursday No activity to report. 5/19/2017- Friday No activity to report. 5/20/2017-Saturday No activity to report. 5/21/2017-Sunday PT PCE 250-LOW/1000-HIGH. UNABLE TO COMPLETE JOB DUE TO BBL COUNTER BEING USED ON OTHER JOB. 5/22/2017- Monday PT PCE 250-LOW/1,000-HIGH. RAN DUAL SPARTEK SBHPS GUAGES FOR LDL AS PER PROGRAM (SAMPLE RATE SET @ 1 SEC INTERV.ALONG WITH DEPTH TIME BOX). PUMPED A TOTAL OF 604 BBLS OF PRODUCED WATER DOWN IA WHILE LOGGING. IA FLUID LEVEL AT END OF JOB IS @ 1,600' SO NO NEED TO FRZ PRT. 5/23/2017-Tuesday No activity to report. • OF • • 141'\I / , THE STATE Alaska Oil and Gas ALASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 p 1. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager F .. i Hilcorp Alaska, LLC scONEa 42017, 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Endicott Field,Endicott Oil Pool,DIU SDI 4-42 Permit to Drill Number: 187-056 Sundry Number: 316-454 Dear Mr. Dunn: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this Z2 day of September,2016. RBDMS I,V SEP 2 106 . RECEIVED • STATE OF ALASKA • SEP 0 6 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 075 9'2,7 l k, APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ ,,,, ,(Fracture 1�Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate [I Other Stimulate ❑ Pull Tubing ❑ Convert to Injector❑✓ . Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. MIT Q- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development D. 187-056 - 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Dr,Suite 1400 50-029-21731-00-00 - 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 Will planned perforations require a spacing exception? Yes 0 No ❑ DUCK IS UNIT SDI 4-42 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047502 ' ENDICOTT/ENDICOTT OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,839' - 10,584' - 11,740' 10,496' 2,050 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 145' 30" 145' 145' N/A N/A Surface 2,481' 13-3/8" 2,481' 2,481' 5,020psi 2,260psi Production 9,204' 9-5/8" 9,204' 8,449' 6,870psi 4,760psi Production 1,853' 9-5/8" 11,057' 9,906' 8,150psi 5,090psi Liner 1,031' 7" 11,839' 10,584' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): 4-1/2" 12.6#/L-80/DSS 10,767 See Attached Schematic See Attached Schematic 3-1/2" 9.2#/L-80/TDS 10,870 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Hydroset Packer and SSSV 10,755(MD)/9,657(TVD and 1,611(MD)'1,611(ND) 12.Attachments: Proposal Summary Q Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service Q • 14.Estimated Date for 15.Well Status after proposed work: 10/1/2016 Commencing Operations: OIL ❑ WINJ Q • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 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 Taylor Wellman Tit„/ Email twellmanehilcorD.com Printed Name ike Dunn Title Operations Manager / / Signature Phone 777-8382 Date 9/1/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3\LR-- `-1511 Plug Integrity ❑ / BOP Test ❑ / Mechanical Integrity Test IBJ Location Clearance ❑ Other: 1 Z r"i'1 pr.....E[ -.f �ltt�.e,r,�:*✓t"/� z j,!"r ty=r _t Zt�✓/4�Tc.," A s.`t/e.t.6) /... ;a+,. i 4,G._e c,tr_a v.r...e, / AZO / c� �:t � lea.. Post Initial Injection MIT Req'd? Yes ❑ No ❑ 4455- 1 ILa(IL Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /O�' `' f 7 /fir/ APPROVED BY RBDMS Lev SEP 2 9 ""� Approved by:(I COMMISSIONER THE COMMISSION Date:_-��l� Submit Form and Form 10-403 it/-67 11/2015 1 a valid for 12 months from the date of approval. Attachments in Duplicate • • Perf&Convert to PWI • Well: E4-42 PTD: 18ND7-056 Macon)Alaska.Lb API: 50-029-21731-00-00 Well Name: END 4-42 API Number: 50-029-21731-00-00 Current Status: Flowing w/Gas Lift Rig: SL+ EL Estimated Start Date: October 1, 2016 Estimated Duration: 4 Reg.Approval Req'std? No Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 187-056 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8847 (0) (509) 670-8001 (M) AFE: WeIIEZ Entry Required: Yes Current Bottom Hole Pressure: 3,092psi @ 10,000' TVD (Based on SBHPS on 10/29/15) Maximum Expected BHP: 3,092psi @ 10,000' TVD (Based on SBHPS on 10/29/15) Max. Proposed Surface Pressure: 2050psi (Gas Lift System Pressure) Brief Well Summary: The scope of the project is to convert the 4-42 well, a long term shut in production well,to a water injection - well to support the 4-14A,4-28 &4-46 wells.The well was last flowed in June 2013 at a +99%water cut.This project would alter the existing waterflood sweep pattern in the FII/FIII/FIV/FV sands.This project will add pressure support to this area, especially the 4-14A well that has just been reactivated.The UPSZ Fll perforations will be added to improve support of the 4-46 &4-28 wells that have open FII perforations. Objective: 1. Add perforations to the UPSZ Fll and flow test 2. Convert the well service to produced water injection Gun Run# UPSZ Perf Top Perf Bottom Perf Length kj 1 4 ±11,479' ±11,499' 20 Total 20 Table 1:END 4-42 Proposed Gun Runs*Verify final gun runs correspond to signed END 4-42 Final Approved Perf Sheet y Variance Requested: 20AAC25.412(b) Packer will be set greater than 200ft measured depth from 'T open perfs Li C4 ' P,r.✓p iG�✓'C c>(c Area of Review—Endicott DIU 4-42 (187-056) !�'�' `�' �''t"'"-Zrz, Prior to the conversion of well 4-42 from producer to water injector, an Area of Review (AOR) must be conducted. This AOR found one other well (4-34) within 1/4 mile of 4-42's entry point into the UPSZ FV Formation. Table 2:Wells within AOR Well Name PTD Distance, Ft. Annulus Integrity 4-42 187-056 0' MIT-IA on 9/2/87 passed to 2500 psi MIT-IA on 10/11/97 passed to 2500 psi Concur. Tie /41r 7-1' e r4 L.-. '(( prod €CO©, a fPyv4,/ Asf fro., 9A1 TO bo PP w, '$t% tv/c. / gve - co n✓err�y Tfi�s �� 'ec��r f� Tit 1 wet! 1`0 �r r'/1,J(cfoi sit �w hep ry ; y ? /o • • • Perf&Convert to PWI • 14Well: END 4-42 PTD: 187-056 Hikorp Alaska,LL, API: 50-029-21731-00-00 Table 3: Completion Detail APIA Well No Permit AWeill tiltUrretit Status _ Zit-nal isolation e , S/I Producer- Cement Bond Log run on 6/23/1987 50-029-21731-00-00 187-056 4-42 Endicott Oil Pool indicates TOC at 10,832'MD (top of 7" liner) —340' above UPSZ FV sand. Segmented Bond Log run on 11/1/1996 50-029-22705-00-00 196-155 4-34 S/I Producer- indicates TOC at 10,360'MD —28' above . Endicott Oil Pool UPSZ FV sand Procedure: Slickline 1. RU SL unit and pressure test to 250psi low/2,000psi high. 2. Pull 4-1/2" BBE SSSV from 1611' md. 3. RD SL. Eline 4. RU EL unit and pressure test to 250psi low/2,000psi high. 5. MU perforating tool string with 2" - 2-1/2" guns, 60 deg phasing. 6. Correlate 1st gun run to reference log. Contact OE Taylor Wellman at 1(907) 947-9533 prior to perforating for final approval of tie in. Q{ ► F 7. Perforate 15t gun run as per Table 1: END 4-42 Proposed Gun Runs. POOH. 1147`i- Il 11' 6 a. Note any tubing pressure change in WSR. 8. RD Eline. Slickline 9. RU SL unit and pressure test to 250psi low/2,000psi high. 10. Set 4-1/2" BBE SSSV at 1611' md. 11. RD SL. Operations 12. Flow well and obtain well tests. Slickline 13. MIRU SL unit and pressure test to 250psi low/2000psi high. 14. Pull 4-1/2" BBE SSSV from 1611' md. 15. Set catcher sub below Station #4 (8402' md). a. Drift of tubing is up to WSM discretion. 16. Pull GLV's from: b. Station #4 (8402' md) c. Station #5 (6476' md) d. Station #6 (4198' md) 17. Set Dummy GLV's in: Perf&Convert to PWI • • • Well: END 4-42 PTD: 187-056 xaear„Alaska,LL API: 50-029-21731-00-00 e. Station #5 (6476' md) f. Station #6 (4198' md) 44-41"'‘ 18. Set circ valve in Station #4 (8402' md). ' r 19. Set 3-1/2" PXN plug at 10,885' md. g. Use fill extension prong to ensure ease of recovery later. h. Bleed down tubing pressure to ensure good plug set. Operations 20. Circulate the well down the IA and take returns down the flowline w/ 550bbls of seawater and freeze protected IA w/55bbls of diesel. Slickline 21. Pull circ valve from Station #3 (8402' md). 22. Set Dummy GLV in Station #4 (8042' md). a. Note: Depending on the time of the year (freezing ambient temps) an alternative method for using a pump truck to load the IA with seawater and freeze protect with diesel and setting a dummy GLV in Station #4 (8402' md) will be done. This would replace steps 18-21. / 23. Conduct MIT-IA to 2500psi.l C-11-4717't 24. Pull PXN plug from 10,885' md. 25. MU 4-1/2" MCX SSSV and set in nipple @1,611' md. 26. RD SL. Attachments: As-built/ Proposed Well Schematic/Tree &Wellhead Diagram/AOR Map 1Ke,55-S 4417r ( { • II • . Duckell:IslandEND4-42 Unit SCHEMATIC Well:: Last Completed: 10/2/1987 Hileorp Alaska,LLC PTD: 187-056 SAFETY NOTES TREE&WELLHEAD KB Elev.:55.18/BF Elev.:16.8 H2S Readings Average 230-260 PPM on A/L&Gas Injectors Tree CIW 4-1/16" I F Well Requires a SSSV Wellhead MCEVOY 13-5/8" 3Cr I, I OPEN HOLE/CEMENT DETAIL ,', 13-3/8" 4,348 cu/ft Permafrost in 17.5"Hole F 1 9-5/8" 500 cu/ft Class'G',.75%CFR-2=0.12%H R-7 in 12-1/4"Hole 7" 375 cu/ft Class"G",.5%Halad 344,.16%LWL,2%CFR-2 in 8 1/2"Hole 13-3/8", CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 145' N/A 4 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,481' 0.150 2 9-5/8" Production 47/NT80s/NSCC 8.681 Surface 9,204' 0.0732 I 9-5/8" Production 47/NT95HS/NSCC 8.681 9,204' 11,057' 0.0732 7" Liner 29/L-80/TKC Btrs 6.184 10,808' 11,839' 0.0372 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/DSS 3.958 Surface 10,767' 0.0152 3 3-1/2" Tubing 9.2#/L-80/TDS 2.992 10,767' 10,870' 0.0087 WELL INCLINATION DETAIL �� KOP @ 5,000' 1 Max Hole Angle=43 deg. @ 7,255' 4 elf Z5 Angle at Top Perf=31 Deg.@ 11,306' 5 JEWELRY DETAIL 11 No Depth Item 6 `'§ 1 1,611' 4.5"OTIS HXO Nipple-ID=3.813" GLM DETAIL:Camco 4.5"x 1.5"Valve w/RK Latch 7� 2 4,198' STA 6:Dev=0,VLV=Dome,Port=16,TVD=4,198',Date=2/28/03 ) 3 6,476' STA 5:Dev=37,VLV=Dome,Port=16,TVD=6,379',Date=2/28/03 4 8,402' STA 4:Dev=39,VLV=SO,Port=22,TVD=7,833',Date=3/18/03 1 1 .$ 5 9,593' STA 3:Dev=38,VLV=DMY,Port=0,TVD=8,756',Date=3/18/03 l 8 'i 6 10,434' STA 2:Dev=39,VLV=DMY,Port=0,TVD=9,404',Date=9/31/87 4° 7 10,579' STA 1:Dev=38,VLV=DMY,Port=0,TVD=9,517',Date=3/18/03 '•' 9,10&11 i 8 10,684' 4-1/2"OTIS XA Sliding Sleeve,ID=3.813" 13 s 12 i y /tv b 9 10,741' _ BakerEB-1 Extra Long Tubing Seal Receptical-ID=3.735" 10 10,754.6' KBH-22 Anchor Seal Assembly,3.948" 11 10,755' Baker SAB-3, 9-5/8"x 4-1/2"Hydroset Packer,ID=4.750" „. 12 10,760' 194-60 Mill-out Extension,ID=6.00" 1 ,, ' 13 10,767' 7"8rd Box X 3-1/2"TDS Pin XO,ID=2.972" *. 14 �' 14 10,803' 3-1/2"Otis X Nipple,ID=2.70" it 4, 15 10,835' 3-1/2"Otis XN Nipple,ID=2.635" Min ID=2.635" : 16 10,870' Wireline Entry Guide,2.992" @10,835' - ,, ,,15 PERFORATION DETAIL END Top Btm Top Btm FT Date Status Size SPF 16 Sands _ (MD) (MD) (TVD) (TVD) 9 5/S 11,176' 11,278' 10,007' 10,094' 102 8/31/1987 Open 5" 5 11,306' 11,346' 10,118' 10,152' 40 5/16/2011 Open 2" 6 7"Markerioint 11,366' 11,396' 10,170' 10,195' 30 6/3/2003 Open 2-1/4" 6 @11,301' END Sands 11,366' 11,430' 10,170' 10,225' 64 8/31/1987 Open 5" 5 11,376' 11,377' 10,178' 10,179' 1 4/27/2003 Open 2-1/2" 5 11,396' 11,410' 10,195' 10,207' 14 4/27/2003 Open 2-1/2" 5 TOC 11,740' 11,416' 11,430' 10,213' 10,225' 14 4/27/2003 Open 2-1/2" 5 Tagged 6/21/87 ' Reference Perf Log:DLL/GR on 6/18/1987 GENERAL WELL INFO API:50-029-21731-00-00 y', Initial Completion -10/2/1987 See Perf Table for Dates TD=11,839'(MD)/TD=10,584'(TVD) PBTD=11,740'(MD)/PBTD=10,496'(TVD) Revised By:TDF 3/22/2016 . • • Duck Well:IslandEND4-42 Unit 14 PROPOSED Last Completed: 10/2/1987 ffilcorp Alaska,f LLC PTD: 187-056 SAFETY NOTES TREE&WELLHEAD KB Elev.:55.18/BF Elev.:16.8 H2S Readings Average 230-260 PPM on A/L&Gas Injectors Tree CIW 4-1/16" e' Well Requires a SSSV Wellhead MCEVOY 13-5/8" 30'a:.: x I OPEN HOLE/CEMENT DETAIL r. 13-3/8" 4,348 cu/ft Permafrost in 17.5"Hole 1 9-5/8" 500 cu/ft Class'G',.75%CFR-2=0.12%HR-7 in 12-1/4"Hole �r (F 7" 375 cu/ft Class"G",.5%Halad 344,.16%LWL,2%CFR-2 in 8-1/2"Hole 13-3/8" '� R' 2" CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 145' N/A 13-3/8" Surface 68/L-80/Btrs 12.415 Surface 2,481' 0.150 2 9-5/8" Production 47/NT8Os/NSCC 8.681 Surface 9,204' 0.0732 9-5/8" Production 47/NT95HS/NSCC 8.681 9,204' 11,057' 0.0732 7" Liner 29/L-80/TKC Btrs 6.184 10,808' 11,839' 0.0372 TUBING DETAIL t' - 4-1/2" Tubing 12.6/L-80/DSS 3.958 Surface 10,767' 0.0152 3 %s r�� 3-1/2" Tubing 9.2#/L-80/TDS 2.992 10,767' 10,870' 0.0087 2 WELL INCLINATION DETAIL KOP @ 5,000' Max Hole Angle=43 deg. @ 7,255' 4 Angle at Top Perf=31 Deg.@ 11,306' 5 ,4 JEWELRY DETAIL No Depth Item 6 I 1 1,611' 4.5"OTIS HXO Nipple-ID=3.813" GLM DETAIL:Camco 4.5"x 1.5"Valve w/RK Latch(DMY valves) 14 7 2 4,198' STA 6:Dev=0,VLV=DMY,Port=0,TVD=4,198',Date=9/28/16 3 6,476' STA 5:Dev=37,VLV=DMY,Port=0,TVD=6,379',Date=9/28/16 1 4 8,402' STA 4:Dev=39,VLV=DMY,Port=0,TVD=7,833',Date=9/28/16 � 5 9,593' STA 3:Dev=38,VLV=DMY,Port=0,TVD=8,756',Date=3/18/03 ',-4 , 8 --, , 6 10,434' STA 2:Dev=39,VLV=DMY,Port=0,TVD=9,404',Date=9/31/87 0, 9,10&11 (010 i) 7 10,579' STA 1:Dev=38,VLV=DMY,Port=0,TVD=9,517,Date=3/18/03 8 10,684' 4-1/2"OTIS XA Sliding Sleeve,ID=3.813" 12 9 10,741' BakerEB-1 Extra Long Tubing Seal Receptical-ID=3.735" 1 13 s ';e 10 10,754.6' KBH-22 Anchor Seal Assembly,3.948" 11 10,755' Baker SAB-3, 9-5/8"x 4-1/2"Hydroset Packer,ID=4.750" yt 12 10,760' 194-60 Mill-out Extension,ID=6.00" 13 10,767' 7"8rd Box X 3-1/2"TDS Pin XO,ID=2.972" - 94 ? 14 10,803' 3-1/2"Otis X Nipple,ID=2.70" 15 10,835' 3-1/2"Otis XN Nipple,ID=2.635" Min ID=2.635" '`4e ' ak 16 10,870' Wireline Entry Guide,2.992" @10835' �, a 15 4 PERFORATION DETAIL vEND Top Btm Top Btm Statu if ' 16 Sands (MD) (MD) (TVD) (TVD) FT Date s Size SPF X5/8" Ai 11,176' 11,278' 10,007' 10,094' 10 8/31/1987 Open 5" 5 7"MarkerJoint v^ tco. 11,306' 11,346' 10,118' 10,152' 40 5/16/2011 Open 2" 6 @11,301' % 11,366' 11,396' 10,170' 10,195' 30 6/3/2003 Open 2-1/4" 6 't END 11,366' 11,430' 10,170' 10,225' 64 8/31/1987 Open 5" 5 s' Sands 11,376' 11,377' 10,178' 10,179' 1 4/27/2003 Open 2-1/2" 5 11,396' 11,410' 10,195' 10,207' 14 4/27/2003 Open 2-1/2" 5 TOC 11,740' Tagged 6/21/87 t n� 1} 11,416' 11,430' 10,213' 10,225' 14 4/27/2003 Open 2-1/2" 5 ±11,479' ±11,499' ±10,268' ±10,284' 20 Open 2" 6 `' Reference Perf Log:DLL/GR on 6/18/1987 41;,,toc. .z.., , GENERAL WELL INFO ' ""```' API:50-029-21731-00-00 __ TD=11,839'(MD)/TD=10,584'(TVD) Initial Completion -10/2/1987 PBTD=11,740'(MD)/PBTD=10,496'(TVD) See Perf Table for Dates Revised By:TDF 3/22/2016 . • • END 4-42 13 5/8 X4'A hanger W/4" BPV profile I iiiiSialung lbw RI. Uv ■ all-a. !'h1IIiiIIiu1 4 1/16 5M CIW Tree ,,IBI mil ma '''"iQ (© tom:: O, '-ei O�-G > 6 ache p11\ 17,-; Errti351a-I- mil II IIII 111 M.61L. 13 5/8 X 13 5/8 5M McEvoy 'a -, �_=i, �: tubing spool � I : i�a, 1. 0 7111111I1%4, li ilii-• 3 1/8 McEvoy HWO valve 13 3/8 3M McEvoy starting head �� - Cid #,.l1111 I� �„�il�l 11,„ ..I••- 2 1/16 McEvoy HWO valve 312/1987 4-.6 '� . 1988 7191 -88 � .'• nd2A 3- 1 :/1979 6122 4-28 - / ____-- 3-45 3-45 4- � � I n _.......„,,, l I "rr I I 441,0i .:• -4 .-46 15/ / 7/22/198 HILCORP ALASKA LLC "4,1-'4-iii?1:00114" • ALASKA NORTH SLOPE:ENDICOTT 9/20/1=96 ••• 4-42 AOR MAP-UPSZ FII i --- .— POSTED WELL DATA J' Well Number 6/. F�:Fi a �I • WELL-SPUD DATE -- '�� SDI 3-49A4/5/1997 • r! ,� , - I 4-42 1 WELL SYMBOLS �i I� � • Active Oil 5/30/1987i 'I , I ,�, D8A O WELL ------' I f' Shut In Oil I lII '_.__ .._. 1 PBA Oil pr I ' Abandoned Injector - I I , ` � '� � i Plug Back w1 I [•� INJ WeII(Water Flood) +}��-�A___1_--♦ f ' 1 C,,� Shut in Injector Water .14/ 008 ` I 7 I • Exploration Well 1 I `` ` 1� REMARKS Well symbol at top of UPSZ FII Sand I I Active/Open perfs in Black ..—._.._._.—_ I ` 7 ' I Proposed perfs in red __ RedInacDashed 1,0 in pink I I � —"-" � --"-'_--- Red Dashed Circle=1,000'radius J Blue Dashed Circle=1,320'(1/4 mile)radius il I I I! 0 X00 2,000 S FEET ----- May 17,2016 PETRA 5nn/2018 3'.1130 Pe • • Schwartz, Guy L (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Friday, September 23, 2016 4:54 PM To: Schwartz, Guy L(DOA) Cc: Davies, Stephen F (DOA) Subject: RE: SDI 4-42 convert to Inj. (PTD 187-056) Gu Sorry about that. Please see the enclosed section of the table that has the information for the 9-5/8" casing. If you'd like this input into the procedure to have it all in a single table please let me know. API Well No Permit Well Current Status Zonal isolation (method) Estimated TOC (calculated) at 9525' md. S/I Producer Bumped plug at calculated displacement, held 50-029-21731-00-00 187-056 4-42 Endicott Oil Pool 3000psi, bled to 700psi &floats held. No losses noted in daily drilling reports. 1650' above UPSZ FV sand. Thank you, 9 4 cs Taylor -tom" Taylor Wellman Hilcorp Alaska, LLC—Ops Engineer: Endicott& Northstar Office: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@ alaska.gov] Sent: Thursday, September 22, 2016 12:00 PM To: Taylor Wellman Cc: Davies, Stephen F(DOA) Subject: SDI 4-42 convert to Inj. (PTD 187-056) Taylor, I am reviewing sundry to convert SDI 4-42 to injection. The AOR is incomplete in that the 9 5/8" casing cement data is not included. Please provide data on quality and TOC for the 9 5/8"casing since the confining packer will be set within it. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended 1 • i RECEIVED Post Office Box 244027 3 0 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 2015 3800 Centerpoint Drive Suite 100 AOG cc Anchorage,AK 99503 Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 SCANNED AUG 2 3 2O1c Commissioner Cathy Foerster p �f © �fU Alaska Oil & Gas Conservation Commission U / ' r_ 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD# 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig • New API_WeliNo I PermitNumberl WeliName I WellNumber I WellNumber I 50029219460600 2032160 DUCK IS UNIT SDI 3-17F/K30 3-17F 50029224630000 1940490 DUCK IS UNIT SDI 3-19/R28 3-19 50029217140000 1870330 DUCK IS UNIT SDI 3-21/L34 3-21 50029217149500 1980190 DUCK IS UNIT SDI 3-21AK35XX 3-21AXX 50029216450000 1861550 DUCK IS UNIT SDI 3-23/N32 3-23 50029221250000 1901820 DUCK IS UNIT SDI 3-25/M27 3-25 50029221250100 2010200 DUCK IS UNIT SDI 3-25A/N24 3-25A 50029221250200 2030210 DUCK IS UNIT SDI 3-25B/L27 3-25B 50029215860000 1860830 DUCK IS UNIT SDI 3-27/M33 3-27 50029221060000 1901560 DUCK IS UNIT SDI 3-29/J32 3-29 50029228380000 1972270 DUCK IS UNIT SDI 3-31/K32 3-31 50029216680000 1861800 DUCK IS UNIT SDI 3-33/K37 3-33 50029216680100 2032150 DUCK IS UNIT SDI 3-33A/J35 3-33A 50029217010000 1870200 DUCK IS UNIT SDI 3-35/L36 3-35 50029225540000 1950510 DUCK IS UNIT SDI 3-37/L35 3-37 50029217640000 1871160 DUCK IS UNIT SDI 3-39/J39 3-39 50029217640100 1970910 DUCK IS UNIT SDI 3-39A/137 3-39A 50029218780000 1881260 DUCK IS UNIT SDI 3-41/K39 3-41 50029224160000 1931700 DUCK IS UNIT SDI 3-43/P36 3-43 50029218110000 1880510 DUCK IS UNIT SDI 3-45/M39 3-45 50029215690000 1860640 DUCK IS UNIT SDI 3-47/Q35 3-47 50029217350000 1870600 DUCK IS UNIT SDI 3-49/J40 3-49 50029217350200 1970570 DUCK IS UNIT SDI 3-49A/M40 3-49A 50029217359500 1950350 DUCK IS UNIT SDI 3-49AJ40XX 3-49AXX 50029217890000 1880220 DUCK IS UNIT SDI 4-02/Q28 4-02 50029219680000 1890860 DUCK IS UNIT SDI 4-04/T26 4-04 50029219680100 2090190 DUCK IS UNIT SDI 4-04A/T30 4-04A 50029217230000 1870430 DUCK IS UNIT SDI 4-06/032 4-06 50029217230100 1961660 DUCK IS UNIT SDI 4-06A/Q30 4-06A 50029216920000 1870080 DUCK IS UNIT SDI 4-08/P27 4-08 50029224640000 1940500 DUCK IS UNIT SDI 4-10/M28 4-10 50029224640100 2022380 DUCK IS UNIT SDI 4-10A/L28 4-10A 50029218630000 1881040 DUCK IS UNIT SDI 4-14/R34 4-14 50029218630100 2080120 DUCK IS UNIT SDI 4-14A/S-37 4-14A 50029218960000 1881490 DUCK IS UNIT SDI 4-18/S30 4-18 50029216400100 1861730 DUCK IS UNIT SDI 4-20/M35 4-20A 50029216400000 1861500 DUCK IS UNIT SDI 4-20/T34 4-20 50029218350000 1880720 DUCK IS UNIT SDI 4-26/034 4-26 50029218700000 1881110 DUCK IS UNIT SDI 4-28/N37 4-28 50029225590000 1950690 DUCK IS UNIT SDI 4-32/K38 4-32 50029227050000 1961550 DUCK IS UNIT SDI 4-34/038 4-34 50029224820000 1940740 DUCK IS UNIT SDI 4-38/K34 4-38 50029222650000 1920420 DUCK IS UNIT SDI 4-40/P43 4-40 50029217310000 1870560 DUCK IS UNIT SDI 4-42/P38 4-42 50029222540000 1920190 DUCK IS UNIT SDI 4-44/M44 4-44 50029222549500 1970470 DUCK IS UNIT SDI 4-44AM40XX 4-44AXX 50029219570000 1890690 DUCK IS UNIT SDI 4-46/N39 4-46 50029219720000 1890970 DUCK IS UNIT SDI 4-48/K43 4-48 50029219400000 1890440 DUCK IS UNIT SDI 4-50/K41 4-50 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. ! ~- L~5~:) Well History File Identifier Organization (done) X Two-Sided RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA Diskettes, No. [] Other, No/Type TOTAL PAGES: 2 ' 0 ..~ NOTES: ORGANIZED BY~ BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) D Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other fsi Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: ~)"~ (at ,he time of scanning) SCANNED BY; ~ BREN VINCENT SHERYL MARIA LOWELL Is~ ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCEN'[~/~rHERYL ~'IARIA LOWELL DATE: General Notes or Comments about this file: PAGES: Quality Checked (done) Rev 1NOTScanned.wod UNSCANNED, OVERSIZED MATERIALS AVAILABLE: / TILE # / &I Adit To request any /all of the above information, please contact: Alaska Oil & Gas Conservation Commission +333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279 -1433 Fax (907) 276 -7542 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 ° . fi r p a" . p.:3 � Mr. Jim Regg .E0 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 4 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 4 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, / I I P - 19 Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 4 Date: 10/07/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na pal END4 -02 / 0-28 1880220 50029217890000 0.3 NA 0.3 NA 1.70 9/29/2010 END4 -04 / T -30 2090190 50029219680100 4 2.0 0.8 9/2/2010 3.40 9/29/2010 END4 -06A / Q-30 1961660 50029217230100 4 3.0 0.1 9/6/2010 2.55 9/30/2010 END4 -08 / P -27 1870080 50029216920000 5 3.0 0.8 9/2/2010 6.00 9/30/2010 END4 -10A / L -28 2022380 50029224640100 15 12.5 0.5 9/6/2010 1.70 9/30/2010 END4 -14A / S-37 2080120 50029218630100 0.3 NA 0.3 NA 1.70 9/30/2010 END4-18 / S -30 1881490 50029218960000 7 2.0 0.8 9/2/2010 4.30 9/30/2010 END4-20 / M-35 1861730 50029216400100 1.5 0.5 0.4 9/6/2010 2.55 10/4/2010 END4 -26 / 0-34 1880720 50029218350000 1.2 NA 1.2 NA 1020 10/4/2010 END4-28 / N-37 1881110 50029218700000 2 1.0 0.5 9/6/2010 3.40 10/4/2010 END4 -32 / K -38 1950690 50029225590000 6 6.0 0.7 9/2/2010 6.80 10/4/2010 END4-34 / 0-38 1961550 50029227050000 4 1.0 0.3 9/6/2010 1.70 10/4/2010 END4 -38 / K -34 1940740 50029224820000 10 7.0 0.3 9/6/2010 1.70 10/4/2010 END4 -40 / P-43 1920420 50029222650000 1.5 0.3 0.4 9/6/2010 3.40 10/4/2010 �9 END4 -42 / P -38 1870580 50029217310000 0.5 NA 0.5 NA 3.40 10/4/2010 END4 -44 / M-44 1920190 50029222540000 1.5 0.3 0.5 9/6/2010 1.70 10/4/2010 END4 -46 / N -39 1890690 50029219570000 3 2.5 0.8 9/6/2010 5.10 10/4/2010 END4 -48 / K-43 1890970 50029219720000 4 2.0 0.8 9/6/2010 5.10 10/4/2010 END4-50 / K-41 1890440 50029219400000 1.3 0.1 0.3 9/6/2010 1.70 10/4/2010 STATE OF ALASKA ALASKA OAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development al Exploratory ❑ " 187 -0560 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 .4 50- 029 - 21731 -00 -00 8. Property Designation (Lease Number) : Si''►1 9. Well Name and Number: - ADL0= 'b47.5Q, ) ti 75 O,.� 5 .. 4- 42/P -38 10. Field /Pool(s): ENDICOTT FIELD / ENDICOTT OIL POOL 11. Present Well Condition Summary: Total Depth measured 11839 feet Plugs (measured) None feet true vertical 10583.58 feet Junk (measured) None feet Effective Depth measured 11715 feet Packer (measured) 10755 feet true vertical 10473.92 feet (true vertical) 9657 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 122' 30" 40 - 162 40 - 162 Surface 2442' 13 -3/8" 68# L -80 39 - 2481 39 - 2481 4930 2270 Production 11019' 9 -5/8" 47# NT8OS 38 - 11057 38 - 9506 6870 4760 Liner 1031' 7" 29# L -80 10808 - 11839 9700 - 10584 8160 7020 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - MA ` _ _ True Vertical depth: _ - - _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 37 - 10697 37 - 9610 3 -1/2" 9.2# L -80 10697 - 10871 9610 - 9751 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" TIW HBBP Packer 10755 9657 RECEIVED' q summary: MY" Y 4. ,U11 12. Stimulation or cements squeeze summa � . Intervals treated (measured): Alaska 011 3. ;a$ Gems. Ginerilasion Treatment descriptions including volumes used and final pressure: !' n L r q6 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 2 3 2856 308 Subsequent to operation: 2 2 2432 282 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development Q - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil r. 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE 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: NA Contact Joe Lastufka Printed N e e Last AL I Title Petrotechnical Data Technologist Signat re V&IIIik \ Phone 564 -4091 Date 5/24/2011 _'I Form 10-404 Revised 10/2010 RBDMS MAY 2 5 '101 4) s-- ubmit Original Only � 3 ,`� / ir, 4- 42/P -38 187 -056 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 4- 42/P -38 8/31/87 PER 11,176. 11,278. 10,006.94 10,093.97 4- 42/P -38 8/31/87 PER 11,306. 11,346. 10,117.96 10,152.3 4- 42/P -38 8/31/87 PER 11,366. 11,430. 10,169.5 10,224.68 4- 42/P -38 10/19/97 SQF 11,366. 11,430. 10,169.5 10,224.68 4- 42/P -38 10/19/97 SQZ 11,306. 11,346. 10,117.96 10,152.3 4- 42/P -38 10/19/97 SQF 11,176. 11,278. 10,006.94 10,093.97 4- 42/P -38 4/27/03 APF 11,416. 11,430. 10,212.59 10,224.68 4- 42/P -38 4/28/03 APF 11,376. 11,377. 10,178.1 10,178.96 4- 42/P -38 4/28/03 APF 11,396. 11,410. 10,195.33 10,207.41 4- 42/P -38 6/3/03 APF 11,366. 11,396. 10,169.5 10,195.33 4- 42/P -38 5/16/11 APF 4 / 11,326. 11,346. 10,135.13 10,152.3 4- 42/P -38 5/17/11 APF I 11,306. 11,326. 10,117.96 10,135.13 • AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • . . 4- 42/P -38 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 5/16/2011' WELL SHUT IN ON ARRIVAL * ** (E -LINE PERF JOB) INITIAL T /I /O = 1000/1350/0 PSI =SSV, SWAB, WV, KILL LINE = CLOSED. MASTER = OPEN ;RIH WITH A 2" POWER JET 2006 HMX AND PERFORATED A 20' INTERVAL 1(11326'- 11346'). RAN JEWELRY LOG FINAL T /I /O = 1100/1350/0 PSI SSV, SWAB, WV, KILL LINE = CLOSED. MASTER = OPEN ** *JOB IN PROGRESS TO BE CONTINUED 17- MAY -2011 * ** 5/17/2011 * ** JOB CONTINUED FROM 16- MAY - 2011 * ** (E -LINE PERF JOB) WELL SHUT IN ON ARRIVAL !INITIAL T /I /O = 1000/1350/0 PSI INITIAL VALVES CONFIGURATION = SSV, SWAB, KILL LINE = CLOSED. MASTER = OPEN RIH WITH 2" HSD 6 SPF POWERJET TO PERFORATE INTERVAL 11%)6'- 11326'. '.CCL TO TOP SHOT = 3.3', CCL STOP DEPTH 1 FINAL VALVES CONFIGURATION = SSV, SWAB, KILL LINE = CLOSED. MASTER OPEN FINAL T /I /O = 1575/1420/0 PSI ` * ** JOB COMPLETE * ** WELL SHUT IN ON DEPARTURE FLUIDS PUMPED BBLS 2 DIESEL 2 TOTAL TREE= CM/ WELLHEAD = SAFETY D D RAF• E N D4-42 SAFETY: WELL REQUIRES A SSSV I ACTUATOR = OTIS KB. ELEV = 55.3' ( ' BF. ELEV = 16.5' KOP _ I 1611' H4 -112" SSSV NIP, 1D = 3.813" I Max Angle = 43° @ 7255' Datum MD = 11233' Datum TV D = 10000 SS 113 -3/8" CSG, 68 #, L -80, ID = 12.415' H 2481' I I GAS LIFT MANDRELS ST MD TVD DEV TYPE VALVE LATCH PORT DATE 6 4198 4198 0 CAMCO DOME RK 16 02/28/03 5 6476 6379 37 CAMCO DOME RK 16 02/28/03 Minimum ID = 2.635" @ 10835' 4 8402 7833 39 CAMCO SO RK 22 03/18/03 3 9593 8756 38 CAMCO DMY RK 0 03/18/03 3 -1/2" OTIS XN NIPPLE 2 10434 9404 39 CAMCO DMY RK 0 09/31/87 1 10579 9517 38 CAMCO DMY RK 0 03/18/03 I ' 1 10684' 1-14-1/2" "XA" SLIDING SLV, ID = 3.813" ( 4 -1/2" TBG, 12.6 #, L -80 DSS, --I 10697' I 10741' — I9 -5/8" X 4 -1/2" BKR SEAL ASSY, ID = ? I .0152 bpf, ID = 3.958" 10755' I - 5/8" X ?" TNV HBBP PKR, ID = 4.750" I I 10803' H3 -1/2" OTIS X NIP, ID = 2.750" I TOP OF 7" LNR I—I 10808' 1 1 I 10835' H3 -1/2" OTIS XN NIP, ID = 2.635" I 3 -112" TBG. 9. L -80 TDS — 10871' I / 10871' J—I3 -1/2" WLEG, ID = 2,992" I 0087 bpf. ID = 2.992° 19 -5/8" CSG, 47 #, NT8OS NSCC, ID = 8.681" I--I 11057' 1 • PERFORATION SUMMARY REF LOG: DLL -GR on 06/18/87 ANGLE AT TOP PERF: 31° @ 11306' I 11301' H7" MARKER JOINT I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 5 5 11176 - 11278 S ? 1 5 5 11306 - 11346 S ? / 2" 6 11306 - 11346 0 05/17/11 J 2 -1/4 6 11366 - 11396 0 06/03/03 5 5 11366 - 11430 S ? ' 2 -1/4 5 11396 - 11410 0 04/28/03 2 -1/4 5 11416 - 11430 0 04/27/03 1 I PBTD I-1 11715' v!'A'A'A'A'A'A'i . • • • • • t�..1... 7" LNR, 29 #, TKC BUTT, —I 11839' 1.. 1.0.1.1.41.0.4 .0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 10/06/87 M DM ORIG COM PLETION 05/21/11 SRD/ PJC PERFS (05/17/11) WELL: 4 -42 / P -38 10/19/97 RAC WSO I & 11 05/21/11 PJC TUBING CORRECTION PERMIT No: 1870560 12/18/07 JLJ /PJC PERF /GLV CORRECTIONS AR No: 50- 029 - 21731 -00 -00 03/18/10 JLW /SV CSG CORRECTIONS SEC 8, T11 N, R17E, 2608' FSL & 629' FEL 11/09/10 ? /JMD FORMAT REVISION 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) . WELL LOG TRANSMITTAL . ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) EDE Disk 2) 3) 4) 5) 6) 7) 4 - 42/ P38SDI Production Profile 19-0ct-06 17f7- - D5cD '* 14<95"1 Print Name: ~-,j~ (I ~ II '" H l-t'¿ (VloJA tÆ 1L.0U\ Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PC:;5;:\;~jGHCR'2~i?;_=(5)f\J1E¡;kD~~'/LSG.t;O~ÌJ1 WEBSITE : 'Jìr\j"!}l.i\f<)JJE0,;¡O~r(LQG,C-O;\n 0:\00_ PDSANC- 2006\Z _ W ord\Distribution\Trnnsmittal_ SheetsITr1U\Smit_ Original.doc MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMISS ..... REPORT G, SUNDRY WELL OPEr ATIONS 1. Operations performed: Operation shutdown__ Stimulate × Plugging__ Pull tubing__ Alter casing __ Repair well__ Perforate.__ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exl)loration (Alaska) Inc. Development X KBE = 55.18 feet Exploratory ~ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchoracle, Alaska 99519-6612 Service_ Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 2673' SNL, 628' WEL, Sec. 8, T11N, R17E At top of productive interval 3275' SNL, 2452' WEL, Sec. 9, T11N, R17E At effective depth 3371' SNL, 2257' WEL, Sec. 9, T11N, R17E At total depth 3387' SNL, 2224' WEL, Sec. 9, T11N, R17E 4~42/P-38 SD/ 9. Permit number/approval number 87-56~Not Rec~uired 10. APl number 50- 029-21731 11. Field/Pool Endicott Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11839 feet 10583 BKB feet 11740 feet 10496 BKB feet Plugs (measured) Junk (measured) ORI61NAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 122' 30" Driven 161' 2442' 13 3/8" 4348 c.f. Permafrost 2481' 11018' 9 5/8" 500 c.f. Class G 11057' 1032' 7" 375 c.f. Class G 10807'- 11839' measured 11176'- 11278'; 11306'- 11346'; 11366'- 11430'(afl Squeezed) true vertical (Subsea) 9952'- 10039? 10063'- 10098'; 10115'- 10170' (all Squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 3 1/2" tailpipe to 10871' True vertical depth BKB 161' 2481' 9906' 9699'- 10583' RECEIVE NOV '19 199 . Packers and SSSV (type and measured depth) 9 5/8" Packer at 10755'; 4 1/2" SSSV at 1611' Alaska Oil & Gas Cons. C0~ Anchorage 13. Stimulation or cement squeeze summary 10/6 WSO #1~Cement Squeeze, 10/11 MIT, 10/19 WSO #2~Cement Squeeze Intervals treated (measured) 11176'- 11278', 11306'- 11346', 11366'- 11430' Treatment description including volumes used and final pressure see attached 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 106 549 5760 0 326 70 283 647 0 298 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X.. 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereb,.y~certify that~ foregoing is true and correct to the best of my knowledge. Siena Title ~;~ni~r t~hnic~l A_,;.qi~;t~nt IV Form 10-404 Rev 06/15/88 Date 11/14/97 SUBMIT IN DUPLICATE,~ To: McBride Location: Anchorage From: Luecker Re: END 4-42 NRWO WSO Date: 10-06-97 10-06-97 TIME OPERATIONS 08:30 MIRU Dowell unit #6, ctv- 33.3 bbls new reel. New brass packoff insert dimpling pipe, repair. SIWHP-00, IAP-2000, OAP-0. 10:00 Troubles continue, abort job for day. Pressure test bope's, pump ball through coil, repair live f/l cell line. 10-07-97 TIME OPERATIONS 07:00 Safety meeting, pressure test 4000. 07:30 Pressure test coil, bope's hardline to 4000. 07:40 Recover meth 08:06 SIWHP-2600, IAP-500, OAP-0, START BH kill. 10-8 10:30 CTP-80, WHP-60, bled both to 0 psi 14:30 WHP and CTP both 0 psi, mother of all safety meetings. 15:56 Start cUttting pipe. 16:38 Start pulling pipe. 17:38 OOH, cool down N2. 18:00 Start pumping N2. 21:00 RD and mol.. 10-07-97 TIME CTD WHP CTP RATE VOL RTN.VOL COMMENTS 08:24 0 2450 2550 4.8 91 08:42 0 1670 1800 4.8 180 08:50 0 1050 1080 2.0 220/0 Injectivity test, 2 bpm @ 1060, S/I fell to 720, start RIH. 09:00 200 870 1780 1.0 0 09:58 3900 1000 1920 1.0 31 10:57 11200 800 740 0 91 S/D for dry tag. 11:07 11726 700 630 0 91 Dry tag corrected +14' to 11740, PUH. 11:15 11525 1070 3550 2.0 0 Start acid 11:28 11525 1000 25/0 Switch to FSW. 11:33 11525 1105 3700 2.0 7 Acid at nozzle 11:43 11170 670 630 0 25 S/D grease valve, let acid soak. 11:56 11170 800 1860 1.3 26 RIH. 12:02 11477 860 3290 2.0 35 FSW at nozzle. Cement up to weight. 12:17 10993 920 3340 2.0 65 12:36 11525 750 1690 1.2 100 Circulating .5 bpm off b/s checking for gas. (150 psi discrepancy between coil and b/s pressures during s/d.) 13:38 11525 800 2100 2.0 167. Injectivity 2.0 bpm @ 680, safety meeting. 14:05 11525 710 1200 1.1 219 14:09 11525 705 1180 1.0 223/0 Switch to meoh 14:11 11525 650 640 1.7 1 Switch to fw. 14:17 11525 730 3290 2.4 11/0 Switch to cmt. H-27 NRWO GSO 10-04-97 00:55 6300 1700 0 1.3 0 Start FSW down b/s, recover meth from coil. 01:10 1170 0 1.5 20/0 20 Switch to 10.9 ppg brine down coil 01:19 1110 2860 2.2 0 0 Start brine 01:40 600 3900 2.0 0 02:04 200 3880 1.9 90 . 0 02:15 50 1570 1.2 110 10.8 ppg rtns at 113 pumped. Ship rtns to tankfarm. 02:24 40 2000 1.3 120/0 Switch to meth. 02:37 100 3600 1.6 23/0 Switch to meth dn b/s. 02:43 100 125 1.0 3/0 S/D, trap pressure. RD for night. Summary: BH kill well with 220 bbl. FSW. Injectivity 2 bpm @ 1060. RIH and tag at 11726, reset counter to 11740. Pumped 25 bbl 15/10% HCL/Xylene acid. Injectivity improved to 2.0 bpm @ 680. Cooled sump and laid in 22 bbls cement from 11525, held 750 WHP while laying in cement. Closed chokes once perfs covered and ramped to 2400. Continued building to final squeeze pressure of 3400. Reached 3400 12 minutes after perfs covered. Bled 190 psi in 15 minutes, bumped backup and bled 170 psi in 15 minutes. Held pressure for 62 minutes. Released pressure and LRO to 11150. Cleared coil and jetted with 30 bbl of biozan. Reversed out to 11525 and recovered a total of 14 bbl cement indicating 8 bbls behind pipe. This is close agreement to 8 bbls calculated by pressures. Backed in gas from 9500 placing f/1 at approximately 1850'. Based on a static whp of 600 this should give 1200psi drawdown for inflow test. Axle on reel broke while coming out of hole @ 6300'. Safed out well by pumping 10.9 ppg brine to give estimated 200 psi overbalance.. Cut coil and reeled pipe on yard spool, blow down both sections of pipe and RD to effectuate repairs. ACID FORMULA, 15 %/10 % HCL/XYLENE 6gpt A261 4 ppt A179 8 ppt A153 20 ppt LO58 15 gppt U074 18 ppt L-58 LATEX CEMENTSLURRY Additive Concentration D047 .100 ~al/sk D065 .350 % BWOC D800 1.00 % BWOC D134 1.12 gal/sk D135 .15 gal/sk D020 1.0% BWOC M117 .300 % BWOC RECEIVED Lab Field Thickening Time 6hr 9 min Fluid Loss 61.0 61 Filter Cake .77" .63" Density 15.6g 15.6 NOV 19 199 ' AJaska Oil & Gas Cons. Commission Anchorage H-27 NRWO GSO 10-04-97 BPX Endicott Production Engineering Department DATE: WELL N°: 10/11/97 4-42/P-38 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: Operations Report MIT Lovelace HB&R I .... TIME OPERATIONS SUMMARY SIP=1900 IA=900 OA=0 2200 RIG UP HB&R AND P-TEST LINES TO 3500 PSIG 2219 BEGIN PUMPING DIESEL AT 3 BPM-10 BLS ONLY 2225 SWITCH TO SEAWATER AT 5 BPM 2258 REDUCE RATE TO 3 BPM START TO PRESSURE UP-165 BLS AWAY 2322 - 233 BBLS AWAY. IA = 2400 SIP = 1900 OA = 0. MONITOR. FOR 15 MINUTES 2337 IA = 2400 SIP = 1900 OA = 0.' GOOD TEST. RIG DOWN HB&R ..... IA BLED DOWN TO 1300 PSI BY WELL TENDER SUMMARY: FILLED THE IA UP WITH 225 BLS OF SEA WATER AND 10 BLS OF DIESELD AND PRESSURE TESTED DUMMY VALVE TO 2400 PSI FOR COIL TUBING UNIT To: Anchorage Engineering From: Powers Operation: 4-42 WSO CEMENT SQUEEZE II Date: 10/19/97 RIH with 2.5" cementing nozzle. Circulated well dead. Checked injectivity and it was worse than 3000 psig at 1 BPM. Laid in 20 bbls of 15%HCL/10%Xylene across perforations and injectivity improved to 1000 psig at 1 BPM. Cooled sump with an additional 200 bbls of FSW. Laid in 17 bbls of cement with chokes open. Ramped pressure to 3500 psig after cement was laid in. Squeeze would look good initially than begin to leak off. We suspected leak was at surface but couldn't rule out squeeze. LRO cement to a depth of 11,520'. Jetted liner to WCTOC and back to flag. Reversed back same. The final PT was jug tight at 1945 psig. Reversed in lift gas for underbalance and POOH. MI recovered 8 bbls of cement, but I do not believe more than 2 bbls went behind pipe. (psi§) (psig) (psig) (psig) (deg F) (psig) 280 I 1000 I 0 I 280 I Broke I 2100 I Time ][ Operation 7:00 MIRU DS#6 13,800' of 1.75". CTV=31.5 bbls 8:47 PT and BOP test 9:29 Recover methanol 9:35 POP well (ft) (bpm) (psig) (psi§) (bbls) (bbls) 9:44 surf .5 600 280 RIH pumping min rate. 10:38 5000 600 330 9.8K 10:45 5700 2 2800 480 35 Start circulating gas out taking returns to flowline. 11:32 10000 1.7 3000 900 112 16.5K 11:49 11500 1.8 2900 850 142 Park. 19.6 off bottom 12:18 1 195 Close chokes and check injectivity 12:27 1 3600 3000 200 Bad injectivity. SD and tag TD 12:37 11620 0 875 Broke through a crust at about 11590' and decided not to go deeper. PU and flag pipe 13:15 11520 202 PT Dowell 13:18 2 3400 940 206/0 Stage acid - chokes open - PUH 13:32 11160 2 20 SW to water 13:39 1 12 Acid at nozzle. Close choke 13:43 11200 1 3000 2400 15 Getting a nice break 13:54 11450 1 1860 1160 25 ' PUH 14:00 11160 0 27 SD and let acid soak 14:19 Overdisplace acid 14:37 11520 0 762 778 55.2 Waiting on cmt -moving pipe 15:53 1 1700 1030 217 Check infectivity STATE OF ALASKA ALA5KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1343' FNL, 1760' FEL, Sec. 25, T13N, RSE, UM At top of productive interval 1444' FNL, 285' FEL, Sec. 25, T13N, RSE, UM At effective depth 1611' FNL, 460' FEL, Sec. 25, T13N, RSE, UM At total depth 1657' FNL, 511' FEL, Sec. 25, T13N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical 9730 6444 6. Datum elevation (DF or KB) RKB 64 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-22 9. Permit number/approval number 87-67 10. APl number 50-029-21740-00 11. Field/Pool Kuparuk River Field/Oil Pool feet feet Plugs (measured) None feet Effective depth: measured 9 63 9 true vertical 6385 feet feet Junk (measured) Two 1.5" GLV's in rathole Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 80' 1 6" 250 Sx CS II 115' 11 5' 4341' 9-5/8" 1400SXCS III & 4378' 321 6' 500 Sx Class G 9691' 7" 300 Sx Class G 9725' 6441 ' measured 9338'-9356',9386'-9404',9410'-9430',9445'-9486' true vertical 6190'-6202',6221'-6233',6237'-6250',6259'-6286' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 9275' Packers and SSSV (type and measured depth) Pkr: Camco HRP-I-SP @ 9245'; SSSV: Otis TRDP-1A-SSA @ 1808' RECEIVED 2 4 il v ¥ I~ 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 6/7/97. ORIGINAL Intervals treated (measured) AJal~ 011 & Ga~ Com~. Caallti~lbr~ 9386'-9404',941 0'-9430',9445'-9486' Altch~agll Treatment description including volumes used and final pressure Pumped 269 M lbs of 20/40 and 12/18 ceramic proppant into formation, fp was 6991 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 492 257 4 1000 178 Subsequent to operation 1232 895 29 1100 175 15. Attachments Copies of Logs and Sbrveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby/~ify that the foregoing is true and correct to the best of my knowledge. Signed ~z_..~.,~,.,~ Title Wells Superintendent Form lO-.,4~4'"-Rc~v ~6'~1~;/88~- ~- / Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT __ WELL SERVICE REPORT K1(3M-22(W4-6)) WELL JOB SCOPE JOB NUMBER 3M-22 FRAC, FRAC SUPPORT 0518971703.4 DATE DAILY WORK UNIT NUMBER 06/07/97 PUMP RE-FRAC DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 5 (~) Yes O NoI (~) Yes O No DS-GALLEGOS JOHNS ESTIMATE KD1016 230DS36ML $164,850 $200,612 Initial Tb.(:l Press Final Tbcl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann ~ Final~D'uter Ann 940 PSI 1340 PSI 640 PSI i 1000 PSII 400 PSII 800 PSI DALLY SUMMARY PUMPED 269,086# TO 13 PPA IN PERFS. TOTAL FLUIDS PUMPED 1736, COMPLETED FLUSH OF TUBING TIME 07:00 10:25 11:03 11:10 12:23 13:48 14:11 14:25 15:33 LOG ENTRY MIRU DOWELL FRAC EQUIP., LITTLE RED PUMP AND APC SUPPORT. HELD SAFETY MEETING PRESSURE TEST TREATING LINES TO 9400 PSI. PUMPED BREAKDOWN , SCOUR, AND FLUSH AT 21.5 BPM . 50# GEL SYSTEM. 8100 TO 6300 PSI. SHUT DOWN FOR ISIP. 1685 PSI. PUMPED TWO PULSE TEST AT 5 BPM. PUMPED168 BBLS DATA FRAC AND FLUSH , SHUTDOWN FOR CLOSURE CALCULATIONS. PUMPED 200 BBLS PAD. 5 TO 15 BPM. PUMPED 12348 # OF 20/40 PROP. TO 2 PPA AND 5770 PSI. PUMPED 252,476# OF 12/18 PROPPANT. TO 13 PPA AT PERFS. 14 TO 15 BPM PUMPED TUBING VOLUME NON-X-LINK WATER FLUSH. SHUTDOWN. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,145.00 APC $7,500.00 $13,500.00 ARCO $350.00' $350.00 BAKER OIL TOOLS $0.00 $5,415.00 DIESEL ,, $0.00 $567.00 DOWELL J$152,000.00 $158,853.00 HALLIBURTON $0.00 $10,723.00 LI'I-I'LE RED $5,000.00 $10,060.00 TOTAL FIELD ESTIMATE $164,850.00 $200,613.00 STATE OF ALASKA ALASK-"~:~.IL AND GAS CONSERVATION COMMISSIO-'~'~ REPORT O. SUNDRY WELL OPE .ATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging Perforate__ Pull tubing__ Alter casing Repair well Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development X KBE = 55.18 feet Exploratory 3. Address Stratigraphic __ 7. Unit or Property name P. 0. Box 196612, Anchoraoe, Alaska 99519-6612 Service __ Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 2673' SNL, 628' WEL, Sec. 8, T11N, R17E 4-42/P-38 SDI At top of productive interval 9. Permit number/approval number 3275' SNL, 2452' WEL, Sec. 9, T11N, R17E 87-56~Not Rec/uired At effective depth 10. APl number 3371'SNL, 2257' WEL, Sec. 9, T11N, R17E 50- 029-21731 At total depth 11. Field/Pool 3387' SNL, 2224' WEL, Sec. 9, T11N, R17E Endicott Oil Pool 12. Present well condition summary Total depth: measured 11839 feet Plugs (measured) true vertical 10583 BKB feet Effective depth: measured 11740 feet Junk(measured) ORIGINAL true vertical 10496 BKB feet Casing Length Size Cemented Measured depth True vertical depth Structural BKB BKB Conductor 122' 30" Driven 161' 161' Surface 2442' 13 3/8" 4348 c.f. Permafrost 2481' 2481' Intermediate 11018' 9 5/8" 500 c.f. Class G 11057' 9906' Production Liner 1032' 7" 375 c.f. Class G 10807'- 11839' 9699'- 10583' Perforation depth: measured 11176'- 11278'; 11306'- 11346'; 11366'- 11430' true vertical (Subsea) 9952'- 10039'; 10063'- 10098'; 10115'- 10170' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 3 1/2" tailpipe to 10871' Packers and SSSV (type and measured depth)95/8"Packorat10755';41/2"SSSVat1611'RECEIV~D 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation n/a Subsequent to operation 106 549 5760 0 184 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations v' Oil X Gas Suspended Service 17. I hereby, certify that tJ;~foregoing is true and correct to the best of my knowledge. Signed ~,.--4 ~,//J.J J ~ ~/_~1 TitleR~_niort~_nhni~lzt,.~i,t~ntlV Date 8/19/97 Form 10-4( 4/1~v"06~15/88 ' SUBMIT IN DUPLICATE / BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 8-15-97 WELL N°: 4-42/P-38 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: 9 5/8 ANNULUS MIT Lovelace APC ITIME I OPERATIONS SUMMARY I PRESSURES FP-350 IA-400 OA--0 1540 PUMP SEA WATER 4 BBLS PER MINUTE 1648 PUMP 248 BBLS PRESSURE 2000 LBS 1650 PUMP 5 BBLS METHONAL PRESSURE 2500 PSI 1715 HOLD PRESSURE 15 MINUTES, DID NOT LOOSE PRESSURE 1720 BLEED DOWN TO 1600 PSI 1725 RIG DOWN PUMP TRUCK STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Pull tubing __ Alter casing __ Repair well Perforate__ Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development X KBE = 55.18 feet Exploratory __ 3. Address Stratigraphic 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service __ Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 2673' SNL, 628' WEL, Sec. 8, T11N, R17E At top of productive interval 3275' SNL, 2452' WEL, Sec. 9, T11N, R17E At effective depth 3371'SNL, 2257' WEL, Sec. 9, T11N, R17E At total depth 3387' SNL, 2224' WEL, Sec. 9, T11N, R17E 4-42/P-38 SDI 9. Permit number/approval number 87-56/Not Required 10. APl number 50- 029-21731 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11839 feet 10583 BKB feet 11740 feet 10496 BKB feet Plugs (measured) Junk (measured) ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 122' 30" Driven 161' 2442' 13 3/8" 4348 c.f. Permafrost 2481' 11018' 9 5/8" 500 c.f. Class G 11057' 1032' 7" 375 c.f. Class G 10807'- 11839' measured 11176'- 11278'; 11306'- 11346'; 11366'- 11430' True v~al depth 161' 2481' 9906' 9~9'-10~3' true vertical (Subsea) 9952'- 10039'; 10063'- 10098'; 10115'- 10170' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 3 1/2" tailpipe to 10871' Packers and SSSV (type and measured depth) 9 5/8" Packer at 10755'; 4 1/2" SSSV at 1611' P, FrEIVED Alaska 0!~ ,:'. ',: .... ..... CammJ,'. 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment (4/17/96) Intervals treated (measured) 11176'- 11278', 11306'- 11346', 11366'- 11430' Treatment description including volumes used and final pressure 102 bbls Seawater (SW) w/BPCl SS-5206 Mutual Solvent, 197 bbls SW/BPCl Sl-4004 Scale Inhib. 665 bbls Overflush w/0.2% NE-18 non- ionic surfactant, 175 bbls SW Tubing Displacement. FSWHP= 300 psig. 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 907 387 4764 0 1019 553 5738 0 Tubing Pressure 4O2 388 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended 17. I hereby ~c(~.rtify that the for?g?ing is true and correct to the best of my knowledge. Signed ~-~:]'~-'~:'~.~-' ~,'~/ / g~'~-. C L-C~.-/ Title Senior technical Assistant IV Form 10-404 ~v 06/15~88 sion Service Date 8/21/96 SUBMIT IN DUPLICATE LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 20 February 1996 Transmittal of Data ECC #: 5945.02 Sent by: HAND CARRY Data: PDK Dear Sir/Madam, Reference: 4-42/P-38 (SDI) ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 to (907) 563-7803 Received by: Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. , Date: 17 February 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~4-42/P-38 (SDI) . . ::. DESCRIPTION 1 PLS FINAL BL+RF ECC No. 1 PDK FINAL BL+RF Run ~ 1 5723.10 Run $ 1 5945.02 1 PFC/PERF FINAL BL+RF Run # ' 1 I CN FINAL BL+RF Run # 1 6185.14 6397.12 Please sign .and return to: Attn. Rodney D. Paulson .......... Western Atlas Logging Services 5600 B Street Suite 201 ,~ Anchorage~ AK 99518 -' ~, F t/~07) 63-7803 Received by: /~,~ ~~~~ Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 July 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. i PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 PLS FINAL BL+RF Run # 1 2628.08 Run # 1 5649.04 Run # 1 Run # 1 5945.01 Please sign and return to: Attn. Rodney D. Paulson .~. ~.~ B Street · ~ Anchorage, AK 99518 Received b : ... .... 'urage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2673' SNL, 628' WEL, Sec. 8, T11N, R17E At top of productive interval 3275' SNL, 2452' WEL, Sec. 9, T11N, R17E At effective depth 3371'SNL, 2257' WEL, Sec. 9, T11N, R17E At total depth 3387' SNL, 2224' WEL, Sec. 9, T11N, R17E 12. Present well condition summary Total depth: measured true vertical. 11839 feet 10583 BKB feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 55.18 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 4-42/P-38 SDI 9. Permit number/approval number 87-56/Not Required 10. APl number 50- 029-21731 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical 11740 feet 10496 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True veBr~l depth BKB 122' 30" Driven 161' 161' 2442' 13 3/8" 4348 c.f. Permafrost 2481' 2481' 11018' 9 5/8" 500 c.f. Class G 11057' 9906' 1032' 7" 375 c.f. Class G 10807' - 11839' measured 11176'- 11278? 11306'- 11346? 11366'- 11430' 9699'-10583' true vertical (Subsea) 9952'- 10039? 10063'- 10098? 10115'- 10170' Tubing (size, grade, and measured depth) 4 1/2" 12.6~ L-80 TDS tubing with 3 1/2" tailpipe to 10871' Packers and SSSV (type and measured depth) 9 5/8" Packer at 10755? 4 1/2" SSS V at 1611' 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment (1/15/95) Intervals treated (measured) 11176'-11278', 11306'-11346', 11366'- 11430' Treatment description including volumes used and final pressure 62 Bbis diesel/mutual solvent mix, 15 bble methanol, and 813 Bbls seawater with scale inhibitor mix and 2% surfactant mix. FSlWHP = 600 psig 14. Prior to well operation Subsequent to operation Re.Dresentative Daily Average Production or Injection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1192 5555 3064 0 4 77 1057 305 3273 0 397 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended,. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-4~e~6/15/88 - SUBMIT IN DOPLI(~,~TE~ ~ :? STATE OF ALASKA ~ /,_ .,SKA OIL AND GAS CONSERVATION COMMI,_ .~')N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate × Plugging Perforate Pull tubing Alter casing Repair well 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory .... Stratigraphic Service Other ". 'i 6. Datum elevation (DF or KB) KBE = 55.18- ~ 'f~t I 7. Unit or Property name Duck Island Unit/Endicott 4. Location of well at surface 2673'SNL, 628'WEL, Sec. 8, T11N, R17E At top of productive interval 3275'SNL, 2452' WEL, Sec. 9, T11N, R17E At effective depth 3371' SNL, 2257' WEL, Sec. 9, T11N, R17E At total depth 3387'SNL, 2224' WEL, Sec. 9, T11N, R17E 12. Present well condition summary Total depth: measured true vertical RECEIVED AU G 2 5 1993 Alaska 0il & Gas Cons. L;or~missio~' Anchorage 11839 feet 10583 BKB feet Plugs (measured) 8. Well number 4-42/P-38 SDI 9. Permit number/approval number 87-56/Not Required 10. APl number 50- 029-21731 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical 11740 feet 10496 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 122' 30" Driven 161' 2442' 13 3/8" 4348 c.f. Permafrost 2481' 11018' 95/8" 500 c. f. Class G 11057' 1032' 7" 375 c.f. Class G 10807' - 11839' measured 11176'- 11278'; 11306'- 11346? 11366'- 11430' True v~.~lde~h 161' 2481' 9906' 9699'-10583' true vertical (Subsea) 9952'- 10039? 10063'- 10098? 10115'- 10170' Tubing (size, grade, and measured depth) 4 1/2" 12.6tt L-80 TDS tubing with 3 1/2" tailpipe to 10871' Packers and SSSV (type and measured depth) 9 5/8" Packer at 10755'; 4 1/2" SSS V at 1611' 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment Intervals treated (measured) 11176'-11278', 11306'-11346', 11366'-11430' Treatment description including volumes used and final pressure 1132 Bbls. seawater with Unichem West Scale 46, spacer, Unichem ESL Inhibitor Mix, and overflush; 15 bbls diesel/solvent mix FWHP=250 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1006 722 1788 0 378 1176 693 1693 0 416 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X. Gas Suspended Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~-~~_ C~/, ~ TitleSoniortechnicalAssistantll Form 10-.4~4 Rev 06/15/88 SUBMIT IN dUPLiCATE STATE OF ALASKA o,, 0 R 1 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ..... Stimulate X Plugging Perforate Pull tubing Alter casing Repair well. Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 2673' SNL, 628' WEL, Sec. 8, T11N, R17E At top of productive interval 3275'SNL, 2452' WEL, Sec. 9, T11N, R17E At effective depth 3371'SNL, 2257' WEL, Sec. 9, T11N, R17E At total depth 3387'SNL, 2224' WEL, Sec. 9, T11N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 11839feet 10583 BKBfeet 11740feet 10496 BKBfeet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) KBE -- 55.18 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 4-42/P-38 SDI 9. Permit number/approval number 87-56/92-047 10. APl number 5O- O29-21731 11. Field/Pool Endicott Oil Pool Length Size Cemented Measur..e,d...depth True ve~ depth 122' 30" Driven 161' 161' 2442' 13 3/8" 4348 c.f. Permafrost 2481' 2481' 11018' 95/8" 500 c. f. Class G 11057' 9906' 1032' 7" 375 c.f. Class G 10807'- 11839' measured 11176' - 11278'; 11306' - 11346'; 11366' - 11430' 9699'-10583' true vertical (Subsea) 9952'-10039';10063'-10098';10115'-10170' E E E J V E D Tubing (size, grade, and measured depth) 4 1/2" 12.6~ L-80 TDS tubing with 3 1/2" tailpipe to 10871' JUN 2 6 1992 Packers and SSSV (type and measured depth) 9 5/8" Packer at 10755'; 4 1/2" SSSVat 1611' AJaska OJ] & Gas Cons. Comraissio 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment Intervals treated (measured) 11176'-11278', 11306'-11346', 11366'-11430' Treatment description including volumes used and final pressure 11Bbls Mutual Solvent, 165 Bble ecale Inhibitor, 469 Bble seawater/2% surfactant mix, 157 Bble seawater, 20 Bbls diesel 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1834// 3295 945 0 1264 .~// 1797 1077 0 Tubing Pressure 77O 55O 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ . Signed~~/~.~ ~ /-~~ Titl~,/~W.,,-~) ~.~,,.,,-~," ~ Form 1 Rev 06/15/88 Date (', ~,..~-,~'~-- SUBMIT IN DUPLICATE 1. Type of Request: ALAo,,,A OIL AND GAS CONSERVATION APPLIOATION FOR SUNDRY APPROVALS Abandon __ 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 BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2673' SNL, 628' WEL, Sec. 8, T11N, R17E At top of productive interval 3275' SNL, 2452' WEL, Sec. 9, T11N, R17E At effective depth 3371°SNL, 2257' WEL, Sec. 9, T11N, R17E At total depth 3387' SNL, 2224' WEL, Sec. 9, T11N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service RECEIVED MAR 11 3992 Alaska Oil & Gas Cons. C0mmiss[0'n Anchorage Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 11839 feet 10583 BKB feet 11740 feet 10496 BKB feet Plugs (measured) Junk (measured) Length Size Cemented Measured d e~t, 122' 30" Driven 161' 2442' 13 3/8" 4348 c.f. Permafrost 2481' 11018' 9 5/8" 500 c.f. Class G 11057' 1032' 7" 375 c.f. Class G measured 11176'- 11278'; 11306'- 11346'; 11366'- 11430' 10807' - 11839' true vertical (Subsea) 9952'- 10039'; 10063'- 10098'; 10115'- 10170' Tubing (size, grade, and measured depth) 4 1/2" 12.6tt L-80 TDS tubing with 3 1/2" tailpipe to 10871' Packers and SSSV (type and measured depth) 9 5/8" Packer at 10755'; 4 1/2"SSSVat 1611' 13. Attachments Description summary of proposal__ 6. Datum elevation (DF or KB) KBE = 55.18 Detailed operations program × 14. Estimated date for commencing operation March/April 1992 16. If I~roposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 4-42/P-38 SDI 9. Permit number 87-56 10. APl number 50-029-21731 11. Field/Pool Endicott 0il Pool feet Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,'~--~-~,~,,"Z-(~, F~, ~~.~.~ Title Senior Technical Assistantll FOR COMMISSION USE ONLY Conditio~ of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE O. SMITH Tru eBv/~ical depth 161' 2481' 9906' 9699'- 10583' BOP sketch Suspended~ Form 10-403 Rev 06/15/88 SUBMIT IN T~IPLICATE Welchem Scale Inhibitor Squeeze Procedure Well 4-42/P-38 PRE-TREATMENT OPERATIONS 1. Please contact Greg Berezny in Anchorage at 261-8220 to allow for Welchem personnel to come to Endicott for the treatment and flowback analysis. 2. Obtain well test at normal recommended rate prior to treatment. Ensure WC sample is taken. SCALE INHIBITOR TRI~ATMI~NT 1. Mix or obtain fluids as detailed on attached treatment fluids sheet. . MIRU for bullhead treatment. Pressure test lines to 3000 psi. Pump the following without exceeding frac gradient. Avoid shutting down during the treatment. Evidence indicates that even brief shut- downs of 5-10 min have an adverse affect on the treatment. a. 11 bbl Super A-Sol mutual solvent b. 165 bbl WA-8851 inhibitor as 9% mixture in CaCI2 and seawater c. 454 bbl seawater overflush d. 147 bbl seawater to displace tubing e. 30 bbl arctic diesel to freeze protect (tubing displaced to top pedoration) Note: Filter all fluids that are to enter the peals to 3 !~, preferably on the fly while pumping the job. 3. RDMO. Leave the well shut in for 24 hours. . POP well to test separator for 24 hrs. and arrange with Welchem to monitor returns. Pull single brine samples, for inhibitor flowback evaluation, per the following schedule. Also obtain a watercut sample with each inhibitor fiowback sample pulled. · Every hour for the first 24 hours · Daily for the following seven days · Weekly for the following four weeks · Monthly thereafter The brine samples will be used by Welchem for inhibitor analysis. Watercut samples should be analyzed at the Endicott production lab. Mark each sample with date and time pulled. Please note on telex when the well is actually POP'd. . After the last 24 hr sample has been obtained (~8th day), set a DH corrosion coupon in the tubing tailpipe or sliding sleeve to monitor scale inhibitor effectiveness. Ensure that a watercut sample is pulled during the test. 6. Sample for inhibitor returns weekly thereafter. Pull the downhole coupon monthly, as operations permit, and inspect for scale deposition. DVT/2406 RECEIVED 1 I 199 /-~aska Oil & Gas Cons. corm~[ss~on Anchorage WELCHEM SCALE INHIBITION PROGRAM TREATMENT FLUID SUMMARY Well 4-42/P-38 WELCHEM SUPER A-SOL MUTUAL SOLVENT Volume: 11 bbls WELCHEM INHIBITOR. WA-8851 Volume' 165 bbls Dilute 605 gal of Welchem's inhibitor with 151 bbls of seawater and in a clean stainless steel vac truck equipped with mixing paddles. Mix thoroughly. SEAWATI~R: OVERFLUSH / DISPLACE Pump 454 bbls as ovedlush Pump 147 bbls to displace tubing. Volume- 601 bbls Add non-ionic sudactant to seawater (not required on 147 bbl tubing displacement volume). Ser vice Company Product Name Concentration BJ NE-18 O.2% Halliburton Losurf 300 0.2% Dowell/Schlumberger F-75N 0.2% ARC, TIC,, DIESEL FREEZE PROTECTION For tubing displacement only; mutual solvent not required. Volume: 30 bbls RECEIVED .Alaska Oil & Gas Cons. Commission Anchorage DVT/2406 Oil and Gas Conservation Commission January 15, 1992 Page Four WELL 4-06/Q-32 /~' 10300'- 10600' ~/' LEAK DETECTION SURVEY CAMCO 12/13/91 RUN ONE WE L L4-14/R-34 /11/30/91 10100'-10600' /'RUN ONE INJECTION PROFILE TEMP WARMBACK CAMCO WELL 4-42/P-38 ~ 1/3/92 11100'- 11500' ~/' RUN ONE PRODUCTION LOGGING SERVICES ATLAS WIRELINE SERVICES Sincerely, J. ~. Haas JLH/clt Enclosures xc' File 6.10 J. L. Haas RECEIVED JAN 2 ~ 1992 Alaska 0il & Gas Cans. Commission Anchorage 2370/JLH/clt BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 6, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Re.oorts Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells Well Name D_At.e. 1-21/K-25 8-14-90 1-67/T-20 8/12/90 2-26/N- 14 8-12-90 2-36/O-14 7/14-15/90 2-46/Q-15 8-13-90 2-52/S- 14 8-13-90 3-41/K-39 8-11-90 4-18/S-30 8-13-90 4-26/0-34 8/11/90 4-42/P-38 8/10/90 4-46/N-39 8/12/90 5-01/Sag Delta #7 8/10/90 5-02/Sag Delta #10 8/15/90 If there are any questions regarding this data, please 564-5225. Sincerely, ~anne L. Haas contact Jeanne Haas at RE,'¢EIVED S EP I 1 1990 ~asi~l.0ii & Gas Cons. uommission ~chorago WELL 4-42/P-31~ 8110~90 ,,,/TEMPERATURE SURVEY 11038'-11500' RUN ONE HALLIBURTON RESERVOIR SERVICES WELL 4-46/N-39 STATIC TEMPERATURE SURVEY 11400'-1201 0' CAMCO 8/12/90 RUN ONE WELL 5-01/SAG DELTA 7 STATIC TEMPERATURE SURVEY 11699'-12300' CAMCO 8/10/90 RUN ONE WELL 5-02/SAG DELTA 10 8/15/90 TEMPERATURE SURVEY 12402'-12740' RUN ONE HALLIBURTON RESERVOIR SERVICES WELL 5-03/SAG DELTA 9 ,/DUAL STATIC SURVEY/GR 11942'-12228' SCHLUMBERGER 8/9/90 RUN ONE Sincerely, JLH/Ims cc: File 06.10 WELL 4-06/Q-32 *TEMPERATURE SURVEY 10800' - 11607' Run No. 1 Camco WELL 4-14/R-34 *TEMPERATURE LOG 10000' - 10640' Camco Run No. 2 WELL 4-42/P. -38, *TEMPERATURE SURVEY 10950' - 11750' Run No. 1 Camco *PRODUCTION PROFILE 11000' - 11500' CamCo Run No. 1 WELL 4-46/N-39 *TEMPERATURE SURVEY 11550' - 12282' Run No. 1 Camco Sincerely, JLH/ims cc: File 06.10 WELL 2-70/U-15 *TEMPERATURE SURVEY 10590'- 12171' Run No. 1 HRS WELL 3-05/O-29 *TEMPERATURE LOG 11600' - 12563' HRS Run No. 1 WELL ~-17/J-30 *TEMPERATURE SURVEY 13500' - 14019' Run No. 1 CAMCO WELL 3-33/K-37 *THERMAL MULTIGATE DECAY LOG (TMD) 12740' - 13220' Run No. 1 HALLIBURTON WELL 4-04/T-26 *THERMAL MULTIGATE DECAY LOG (TMD) 13650' - 14024' Run No. 1 HALLIBURTON WELL 4-42/P-38 *TEMPERATURE LOG 10850' - 11760' CAMCO Run No. 1 WELL 5-O2/SAG - 10 *INJECTION PROFILE SURVEY 11850' - 12735' Run No. 1 CAMCO .WELL 5-03/SAG DELTA 9 *STATIC TEMPERATURE SURVEY 12000' - 12236' Run No. 1 CAMCO Sincerely, nne L. Haas JLH/Ims cc: File 06.10 BP EXPLORATION March 14, 1990 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 En.di¢ott Field - Bottom-Hole Pressure Reports Dear Sirs' Enclosed are Bottom Hole Pressure Reports for the following wells Well.Name _[:)ate 1-09J-18 2-12-90 1-41/O-23 2-18-90 1-49/P-21 3-1-90 1-67/T-20 2-3-90 2-26/N-14 2-7-90 2-28/P-19 2-24-90 2-52/S- 14 1-2-90 3-17/J-30 2-27-90 4-04/T-26 12-30-89 4-42/P-38 2-13-90 4-46/N-39 12-29-89 5-03/SG09 2-20-90 If there are any questions regarding this data, please contact Jeanne Haas at 564-5225. Sincerely, nne L. Haas JLH Enclosures RECEIVED ~chor~ge SAG Delta #9 *PACKER/TAILPIPE 112OO - 12200 Run 1 *CEMENT EVALUATION LOG 11267 - 12562 Run1 *CEMENT BOND LOG 11267 - 12562 Run I WE,L. L 4-061Q-32 *PRODUCTION PROFILE 1 O8OO - 112OO Run 1 WELL 1-27/P-20 *COMPENSATED NEUTRON LOG 9950 - 10709 Run I WELL 4-42/P-38 *DIFFERENTIAL TEMPERTURE LOG 10850 - 11735 Run I WELL 2-70/U-15 *PERFORATING RECORD 10485 - 11730 Run 1 Logged By Schlumberger WELL 3-33/K-37 *DIFFERENTIAL TEMPERATURE LOG 12450 - 12950 Run 2 WELL 3-33/K-37 *DIFFERENTIAL TERMPERATURE LOG 12700 - 13282 Run 1 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 5, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells in the Endicott Reservoir: Well Name Date 1-35/O-25 3-28-89 3-33/K-37 3-28-89 4-42/P-38 3-27-89 If there are any questions regarding this data, please contact Dave MacDonald at 564-4697. Sincerely, JeoChn~ L. Haas JLH/Ims RECEIVID APR - 7 1989 '" ~. ", Oil & ~ns Con=,., t;olnn, s~lult Nlcl~olage Standard Alaska ~'"~' Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 25, 1988 STANDARD ALASKA PRODUCTION John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle The following log information for Endicott wells is enclosed: 1 Sepia and blueline print for: 4-42/P-38 Run 1 6-23-88 * Production Profile Log (11000' - 11700~Camco Sincerely, ~ J. T.. Haas Received By: Date: 2176A JLH:slb A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5t I 1 JUN 20, 1988 STANDARD ALASKA PRODUCTION 3ohn Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: The following log information for Endicott wells is enclosed: 1 sepia and blueline print for; 4-42/P-38 Run 2 June 2-3, 1988 * Production Profile Log Sincerely, Floyd Hernandez Received by Date Jl~ 2 2 I988 -- ask~ Oil & Gas Cons. Commission Anchorage A unit of the original Standard Oii Company Founded in Cleveland, Ohio, in 1870, Standard Alaskfl' Production ComJ. .; 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 9~519-6612 (907~ 561-5111 SEP 25, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 The following log information for Endicott wells is enclosed: 1 sepia print and 1 blueline print for: P-38 Run 1 August 30, 1987 * TCP GR Positioning Log .. , Sincerely, .'~ Bruce St. Pierre Received by/ - - ~ ~Al~sk~ Oil & Gas_Cons. Commismo. ......... Anchorage A un,t o{ the or,g,,,Oi Standard Chi Company Founded ,n Cle, elond Oh,o ,n 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE I"1 2. Name of Operator 7. Permit Number Standard Alaska Production Company 87-56 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 s0- 029-21731 4. Location of well at surface 9. Unit or Lease Name 2673' SNL, 628' WEL, Sec. 8, T11N, R17E Duck Island Unit/Endicott At Top Producing Interval 10. Well Number 4-42/P-38 SDI 3275' SNL, 2452' WEL, Sec. 9, T11N, R17E 11. Field and Pool At Total Depth Endicott Field 3387' SNL, 2224' WEL, Sec. 9, T11N, R17E Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE -- 55.18' I ADL 47503 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offsho re 116. No. of Completions 5~30-87 6-18-87 9-2-87I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey J20. Depth where SSSV set J21. Thickness of Permafrost 11839'MD 10583' TVD 11740'MD 10495' TVD YeS [] NO []I 1611 feet MD I 1466' 22. Type Electric or Other Logs Run BCS/GR, DLL/MSFL, SLD/CNS 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe 161' 13-3/8" 68# L-80 Surface 2481' 17-1/2" 4348 cu. ft. Permafrost 9-5/8" 47# NT80S Surface 9204' 12-1/4" 500 cu. ft. Class G~ . 75% CFR -2 + O. 12% HR-7 9-5/8" 47# NT95HS 9204' 11056' 12-1/4" 7" 29# SM110 10808' 11839' 8-1/2" 375cu ft Class G, .5% Halad 344, .16% LWL, 2% CFR-2 24. Perforations open to Production (MD+TVD of TOP and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET IMD) PACKER SET IMD) MD TVDss 4-1/2" L-80 12.6# 10741' 10755' 11176'- 11278' 9952'- 10039' 3-1/2"L-80 9.6~ 10870' 11306' - 11346' 10063' - 10098' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11366' - 11430' 10115' - 10170' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13-3/8"X 9-5/8" Down squeeze 13-3/8" x 9-5/8'" annulus with 345 sx Permafrost C followed by 115 bbls of crude oil 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OlL-BBL GAS-MCF ~VATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED ~)IL-BBL GAS-MCF ~VATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Bdet description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVEI) OCT 0 ~ i~:~/ Alaska 0il & Gas Cons. Commission Anchorage WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. '~ t ;30. ,, , GEOLOGIC IVlARKERS ' FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top HRZ 10784' 9626' LCU 11158' 9918' Top Kekiktuk 11178' 9954' 31. LIST OF A'I-rACHMENTS 32. I hereby ced/fy that the foregoing is true and correct to the best of my knowledge Si~h'~' ' - Title D/vision Dr/fling Engineer Date /' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in anY attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STANDARD ALASKA PRODUCTION Rig: PAA #7 Well: 4-42/P-38 (SDI) Daily Drilling Report -- ENDICOTT August 31, 1987 at 0600 hrs 0600 Depth: 11,740' Day: 25 48-Hour Ftg: -' Current Operation: Testing flow lines. Accept rig at 1500 hfs on 8/29/87. Nipple down well head. Nipple up BOP. Pull tubing hanger. Test BOP. Pick up stack and change ring. RIH with mule shoe. Circulate diesel out. RIH. Circulate and filter brine. POH. Pick up perforating guns. Space out guns and set packer. Rig and test lines to flow well. Mud Type: Brine WT: 9.6 VIS: PV: YP: FL: Solids: Temp: OF SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS RECEIVEI) 0(;"[' 06 Alaska 0il & Gas Cons. Commission Anchorage Rig: PAA #7 Well: 4-42/P-38 (SDI) Daily Drilling Report-- ENDICOTT September 1, 1987 at 0600 hrs STANDARD ALASKA PRODUCTION Current Operation: Mud Type: Brine SURVEY MD 0600 Depth: 11,740' Day: 26 24-Hour Ftg: -' Running completion string. Hold safety meeting. Fire perforating guns. Flow well to surface. Reverse out fluids to tiger tank. Observe well and reverse circulate. POH and L/D perforating guns. Rig up for and run 4-1/2" completion string. WT: 9.6 VIS: PV: YP: FL: Solids: Temp: OF ANGLE DIRECTION TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Rig: PAA #7 Well: 4-42/P-38 (SDI) Daily Drilling Report -- ENDICOTT September 2, 1987 at 0600 hrs 3600 Depth: 11,740' Day: 27 24-Hour Ftg: -' Current Operation: Moving rig. Run and land 4-1/2" completion string. Nipple down BOP. Nipple up and test tree. RIH and set plug in tailpipe. POH. Set packer. Test tubing annulus to 2500 psi. Open sliding sleeve. Displace robing to diesel. Close sliding sleeve. Test tubing to 3000 psi. Install back pressure valve. Release rig at 0100 on 9/2/87. Mud Type: Brine WT: 9.6 VIS: PV: YP: FL: Solids: Temp: OF SURVEY MD ANGI.I:*. DIRECI~ON TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION CO. PAD · P ' (:5:2' 9 - 11 -17) P'38 Controlled Drilling LES HENDERSON Consultants, 333d552 Inc. CONTRULLED DRILLING CONSULTANTS, INC. 4234 KI~'GSTON DRIVE Anchorage, Alaska 99504 (907) 333-1552 . June 27, 1987 Mr. Brian Rose Standard Al'a'ska Production OD. Pouch 6-612 Anchorage, AK 99S02 Magnetic Single Shot Survey Job No. 0587-031 Well P-38 (32-9-11-17) Endicott North Slope, Alaska Date oF Survey 5-31-87 to 6-13-87 · · Dear Mr. Rose: Please Find enclosed the "Original" and six (6) copies oF our Magnetic Single Shot Survey on the"above-well. The method used in calculating this 'survey was Radius oF Curvature. The ,'depth oF the Survey was 486 to 10992. ':Tha'nk you For giving us this opportunity to be oF service. · Yours very truly, Controlled Drilling Consultants, Inc. C.W. Harri ngton DirectiOnal Supervisor STANDARD ALASKA PRODUCTION CO, MAGNETIC SINGLE SHOT $ORVE¥ RADIUS OF CURVATURE METHOD OF COMPUTATION ENGINEE~ C,W,HARRINGTON COMPUTED FOR CDC .BY OCEAHTECH BELL. P-38 SURVEY DATE 057~i787 PROPOSED DIR $82-~6E RECORD OF SURVEY TRUE ME~S. DRIFT VERTICAL DEPTH ANGLE DEPTH DRIFT DiREC TOTAL COORDINATES C L O S U R E S L~.iOTANCE AN~, E ASgUMED VERTI~.RL TO 0 0 0 486 0 30 946 0 0 1491 ~947 0 0 2482 1 0 2776 3'156 ~ 42 3536 0 24 3906 O 4276 0 30 4655 O 495I 0 18 5094 3 54 5195 ~ 24 5290 8 48 5383 I0 48 5477 1~ 30 5572 t4 54 5694 18 12 5789 20 6 945,99 I946,98 2481,96 2775,9~ 3~55,90 3535,89 3905,88 4275, 4654,87 4950,86 5093,74 5194,33 5288 49 53~8 12 5472 5564 5681 03 5770 77 0 FT, -55, ! 8 N . OOE 4~0,8i S50, OOW 898,81 N , OOE 1435,8i N48, OOE 189I .80 N , OOE 2426,78 N58, OOE 2720 ~= N4i OOE 3480,7~ N34 , OOW 3858,70 N4i ,OOW 4220,70 9i ~ , OOE 4599,69 S5i , OOE 4895,68 922, OOE 5038,56 S79,8OE 51~9, i 5 98~, OOE 5233,3 ~ S86 . OOE 5~24 , 94 S86 · OOE 54~ 6.8~ 988. OOE 5508,93 S88 , OOE 5625,85 N9 O, OOE 5715,59 S99, OOE ,69 4,14 7,02 9.i7 N i2,04 i'2.69 i0,47 9,23 6,04 4,62 3,42 2,3! i,28 .46 ,'I4 $ .42 O0 8,35 7 06 34 ~4 50 43 70,19 93,48 328,22 W E E E E E E E E E E E E E E , O0 s 90 o 0 2 32 15 2,3 S 77 2~, 40 N 84 26 H 23 4 N 32 47 N 4i 4'2 N 37 47 i4 32 5 t 4 ~4 22 ~4 5O 70 93 159 46 E 5':~, E 4 E 9 E 52 N 29 :.4, lO E 42 N .~8 4,4 39 EL 50 N 65 ~-~4 ~4 E G2 N "~ 55 E 81 N 84 22 ~2 E ~0 N s7 :'.~ 48 N 89 4~ 59 E 22 S ~q ~¢. 8 E , ooO ,055 , ~87 ,026 ,079 ,053 "' 527 2,7tC 2, 004 WELL :~ t f-4GLE SNOT JOri NO A--0587-03I COP, PUTER ....,~'3':,~. -) ~7 ~tEA$, DR[PT OEPTH ANGLE 5979 23 42 6080 26 6 6t73 28 30 6269 30 36 6363 32 48 6635 40 54 6832 41 30 7020 7213 43 36 7397 43 7581 42 7778 4I ~2 7968 40 24 8~43 39 24 8339 39 24 8528 40 30 8723 40 42 9008 39 54 9394 37 68 9564 38 12 9764 ~9 I8 9967 40 42 0~24 40 18 0323 39 48 ,=,.T!CAL DEPTH 5947 4 6574 7066,49 720~,7t 7348~68 7492,5i 7626,76 7778,22 7923,~1 8071,16 8288.52 8~88 '?8 8?22 74 ~878 72 98~4 22 916i 2~ 9~ O~ 88 S d E SEA 6149,97 6,229,94 6446,42 65~9.6~ ~.594,76 6877,5 ~ 7!46,,53 729~,50 7437,33 7723,04 7867,93 ~015,98 G233,34 8533,E,~ 9667,56 8979,04 DRIFT $89, O OE 998, O OE ~85.00E $85.0 OE 984, OOE S84 ,. 0 OE S8;, O OE 9~6, OOE 982,00E 9:3~, 0 OE SS~. 00E S8~, 00E S84, O OE S84,0 OE S86, O OE S86,00E S8~, 00E S8~, OOE S92. OOE $82.0 OE S8 ~, 80E S79.80E S79. OOE TOTAL C FPD ~.. e 1,00 2,75 4,24 5,89 8,04 ~.~O 20.0~ 25,56 3i,88 44,92 59,70 78,37 97,89 iJ5,Oi .i43.82 i57,90 !70,59 iSi ,G5 i94.5! 206,38 .222,89 238,36 255,78 275, 07 293.90 3!7, i 1 27i 314,43 36 i, 75 4i t, 09 4~4.29 5?4,9? 678 36 704 06 828 07 957 86 i 082 77 1206 O0 1459,28 1570,70 ~E, 94 ~8~5,00 2i25,29 2248,6~ 2469.60 259~ 282S.4i 2948,79 E E E E E E E E E E E E E E E E E E E E E E E E E 2.71 ,82 S 99 354,46 $ 89 411,17 8 88 464,43 $ 88 575,32 S 8.S 638,,88 S 87 ?04,78 $ 87 829.29 $ SE. 959,72 S 86 885,68 9 8~ 209,97 S 85 I34J,00 $ 85 9 E 28 E ~.7.~ E 40 E '4 E ~ E 4 E 7 2 E 0 E 4 E 7 t465,07 8 84 54 !7 E 1 577 '7'~ .... ., .~, '.~; :34 1701.~4 S ~',4 4vt' 72 E ~822,99 S $4 37 50 E 1949,89 S 84 JS i6 E 2~58,06 S 84 45 2~ E 2606,i4 S ~4 22. .S E 2736,47 S 84 2844, ~4_ 2965,79 S 93 5': .,t:~ E EVER: TV DEG / ~ O OFT ,26 S 742 59~ o06 594 065 . 657 ,42I ,57 'i ,449 .28i ,550 ,72f ,265 __ .i--.__... S::? 4'9 ........ 4-~: 702 957 ';'57 .... 'i 09~, 9~ ......... !576 .<" i 700 :: : 948 2 i72; 64 ....... ':2=6,45 .... 2 S TT", 0 7 ..... 2479', 77--- ::965, SINGLE SNOT SURVEY RECORD OF SURVEY TRUE ~.,IEAS. DRIFT VERTICRL SV~ DRIFT DEPTH ANGLE DEPTH SE~ DIREC TOTAL COORD!N~TES ~0898 3,4 42 9760,19 9705.,0I S70,OOE THE FOLLO~JING iS EXTRFtPOLATED TO TD t0992 ~ t2 98~8~7 9782,99 $68,08E 745,!4 $ S0'70~2~ a~2,40 S 7297,49 BOTTOM HOLE CLOSURE 73~4,25 FEET A'T S 92 78 8 E DO~ LE~ C L 0 S U R E S SEVERITY 32 06,16 S 83 'I.~¢- 3 E ,, FEET OF SLiD SEA DEPTH, TRUE ~IEASURED VERTICAL SUB ND-T'VD VERTICAL DEPTH DEPTH '~ =~"?~'1''''~ '~' ~'~'~ T CuuR,. i NA'E'ES 0 255 355 555 755 ~055 1455 1755 ~855 2055 2155 2255 2355 2455 2555 2655 2755 2855 295~, 3055 3i55 3~55 255. 355. 455, 5S5, 655, 755. 955. 1t55, 1255 1455 ~555 1655 i755 ~855 ~ 955 2055 2i55. 2355 2455, 2555 2655 2755 2e55 2955 3055 3i55 3255 -55 ~80 200 300 400 500 600 700 800 900 lOO0 JJO0 j200 ~300 t400 !500 16OO 1700 18OO 1900 2000 2100 2200 2~00 2400 2508 2600 2700 2800 2900 3000 3~00 3200 3300 ~400 .22 'i O~ 69 64 ,ii ,4.3 ,72 ,94 i, 09 i ,i4 i 8" '" 50 · S, 99 4,94 5,95 6,85 7 8,80 9,16 o,55 7 , 7 'i N S S S $ S S S S N H N H N N i-,i N N ,54 3,i? o . 2.6 '~ 7.07 3. 03 2 . 74 ":' O0 i f i. 74 ~, '2.S ,~0 · dhF' J ~ E,, ,=:2,. i<8 ~.EV 55. ~ 8 SONiO WELL SIi4GLE S:.;-iOT SURVEY HEASURED DEPT~ AND OTHE6'. r~', · ,-"'; ~,~TA FOR EVERY E~4EN 100 FEET OF .:,.dS SEA DEPTH, CO;~PU i,< 9 E L E S TRUE M~A~UR~D VERTICAL SUB ~D--TVD VERTIb~.. . P TO DEPTH DE TH SEA DIFFERENCE CORRECTIOi'i T~L . , o.>OO O O ~85S 3855 .~,800 0 0 395~ ~955 ~9¢0 O 40~5 4055. 4008 O O 4i55 4t55. 4i00 O O 4255 4255. 4200 0 0 4355 4~55. 4:300 0 4455 4455. 4400 0 O 4655 4655, 4600 0 O 47'55 4755 , 4780 O 4855 4855, 4Coo o 4955 4 :~ ..... 4900 0 O 5055 5055. 5000 O =~ 56 5i55 5! O0 O 5256 5~5. 5200 5460 5455, 5400 4 2 556~ 5555. 5500 5667 5~55. 5600 i 'i 4 5772 5755, 5700 5e79 5~55. 5~00 24 7 5988 5955. 5L~O0 6098 6055, 6000 42 i O 6211 6!55. 6t00 56 ',4 6r~28 6255. 6200 72 6448 6355. 6300 92 20 6574 6455, 6400 I i9 27 6706 6555, 6500 68~9 6655. 6600 697~ 6755, 6700 2 ! 7 34 7i 07 6855. 6e08 25i 34 ~244 6955. 6~00 288 37 t2.6~ iq i3.24 hi tl .37 N i0.47 N i0,i0 N 9,68 N 9.2~ N 7,i2 N 5,i9 N 2,6~ N .54 N .iO S ,~S S .42 S '1,70 S 4,88 S 7.12 S i6.73 S 20,0i S 5~,29 S 62.40 S ¢3.91 8.4?2 7.~2 '7.~0 7,;24 8 40 E 29 '7¢~ 45-8 i 66. ;2.~ 9 ~ . ~ 2 ii9.q! 153 7'~ s 2~:2, ?3 279 ,~;~ 453.94 :':: 02 ~.~ ~ , 647.7 0 7 08,68 796 -S .3 ~85,9~ I'iE~SURE'D I)EPTH AND OTHER DATA FOR E?ER¥ .... ~:'VEH JO0 FEET OF SUB ,=E~-~ ' OEPTH~ . DEPTH DEPTH ~^ '-~ ~' ~ D~FF~.,ENuE CORRECTION 7653 7255. 7200 397 0~09 7755, 7FO0 ~54. 8439 785~., 7~00 5~3 29 957 0 7955, 79 0 O ~, 'i 5 ~2 8702 8055, e080 64.~ 8964 8255, 8288 709 9095 8355, 8~00 7~9 9224 8455, 8400 768 29 9351 8555, 8500 796 28 9605 875~, eTOO eSO 9734 8855, 8800 878 28 9863 8955, eSO0 9Oe 30 9995 90~5, 9000 939 31 0i26 9i~5 91 O0 '~70 03,97 9355, 9300 i OS! 0516 9455 , 9400 i 060 29 0643 9555, 9500 i 088 28 0769 9655, 9600 Jil~ 25 0892 9755 , 9700 i ! ~6 0992 9838 , 9783 i i 53 ! 7 TOTAL 76, 91, i04, !15, i64.. i7'.3, i92, J 99, 207, 277 3~5, 365, 38 ?, 41i, ~,~ i , 46 '7O 5'9 5',-9 56 99 89 76 3~ 029 35 2J i u,' ,:,¢9 z 'i253 SCi? E t.~. t G6 E ! 5t i, ,'-'E~ E i84.2,30 E t 927,7E: E a 09 ,"' 4 ,,:' ~:~4t}, 2i E 24!7. '~7 E 2¢~ , ,.~,9 ~0 E 24 ~ 9,60 2656.26 E ~8.=. g::; E 2907 2r; E :?988 ~ 7 E .~06~ :SE:E 3!43 ~6 E S216 2;':E SOHIO MELL'P-~8 INTERPOLATED 9ALUE9 FOR EVEN S I NaL£.~.c'-H 0 T~ SURVEv, OEP'TH. CO~iPUTER- KB E:LEV TRUE HEASURED VERT I CAL DEPTH DEPTH SUB SEA 'TOTAL COORDINATES 0 lO00 2000 4OO 0 ~ooo ~000 7000 8000 9000 i0000 0992 7517.. 74~2, 90~9. i.80 278.5~ 431,2i :3,,08 W 237,82 E i479,83 E 2~28, ~7 E ~:3~6,50 a HORIZONTAL VIEW .......................................... STANDARD .tTd..ASKA I~RODUCTION WELL P-3,8 RADIUS OF CURVATURE -:-----MAGNETIC -StNGLE- J, ~IOT----*~ SCALE: I"= I000' . . . ...... I..... ~1 .... :.. ........... ~ ........ $ UB.$ URFA CE DIRECTIONAL SURVEY r~ UIDANCE ~'~ONTINUOUS [-~ OOL Company STANDARD ALASKA PRODUCTION COMPANY 'Well Name 4-42/P-38 SDI(267,,3' SNL)62,81,' WEL~SEC 8~TllN,Rll,7EI FieldlLocation ENDICOTT) NORTH SLOPE, ALASKA , Job Reference No. 72377 Lo~j:ed By: Date 6/23/87 Computed By: STEVENS GCT DIRECTIONAL COSTOMER bISTING FOR STANDARD AbASKA PROOUCTION CO, 4-42/P-38 ENDICOTT NORTH MLUPE,AbASKA SURVEY DAT~{ 23-JUN-87 ENGINEER; G, SARBER METHODS OF CO~PUTATIO{~ TOO[, 6UCATION: TANGENTIAL- Averaged deviation and azimuth I~qTE~POLATi[)N: LII~EAR VERT.ICAL SECTION: HORIZ, DIST, PROJECTED ONfO A TARGET AZIMUTH OF &OUFH 82 D~G 56 MZN EAST STANDARD AGASKA PgODUCT[UN CO, ¢-42/P-]8 8D! ENDICOTT NORTH S[..UPE,AhASKA COMPUTATION DATEI 1-OUb-87 INTERPOLATED VAGUE$ fOR EVEN lO0 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED V£RTICAb VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 0 O0 1 O0 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 aO0 O0 900 O0 0,00 -55,18 0 0 N 0 0 E 100.00 44.82 0 28 N 84 7 W 200.OO 144,82 0 21 $ 74 1! W 299 99 244.81 0 2i S 76 51 W 399:99 344.8! 0 19 $ 77 50 W 499.99 444.81 0 9 $ 47 58 W 599.99 544.81 0 Il S 79 0 w 699,99 644.81 0 11 $ 54 32 ~ 799.99 744.81 07 $ 13 47 ~ 899.99 844.81 0 10 6 56 lb ~ 1000 O0 999 99 944.81 1100"00 1099i99 1044,81 1200:00 1199 99 1144.81 1300 O0 1299'99 1244.81 1400 O0 1399,99 1344.81 1500 O0 1499.99 1444.81 1600 O0 1599.99 1544.81 1700 O0 1699.99 1644,81 1800 O0 1799.99 1744.81 1900 O0 1899.99 1844.81 0 11 $ 21 3¢ W 0 8 S 23 6 E 0 4 S 16 59 E 0 5 $ 67 44 W 0 7 S 10 ]7 E 0 5 m 58 23 E 0 5 N 30 43 , 0 2 $ 9 37 E 0 9 N 1 41E 0 10 !~ 28 40 W 2000 O0 1999.99 1944.81 2100 O0 2099.99 2200 2300 2400 25O0 2600 2700 2800 2900 2044.81 Oo 2199.98 2144.80 O0 2299.98 2244.80 O0 2399.97 2344.79 O0 2499.97 2444.79 O0 2599.97 2544.79 O0 2699.97 2644.79 O0 2799.96 2744.7E O0 2899.96 2844.78 0 5 S bO 49 W 0 14 N 29 lO E 0 31 m 33 0 E 0 34 N 32 b E 0 37 N 48 12 E 0 25 N 53 24 E 0 17 N 54 37 E 0 20 :'~ 62 17 E O 26 N 56 43 E 0 33 N 48 48 E 3000 O0 2999.95 2944.77 3100 OU 3099.95 3044.77 3200 O0 3199.94 3144.76 3300 O0 3299.94 3244.76 3400 O0 3399.94 3344.76 3500 O0 3499.93 3444,75 3600 O0 3599.93 3544.75 3700 O0 3699.93 3644.75 3800 O0 3799.93 3744.75 3900.00 3899.9~ 3844.75 VERTICAl,, DOGbEG RECTANGUbAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/$OU~H ~AST/WE~ DI~T. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MXN 0.00 0.00 '0.42 0.34 '1,16 0.18 'I.71 0,19 00~ -2.86 0i07 -3.17 0 30 '3.26 0.08 '3,39 0.04 0 O0 N 0 09 N 00J N O 18 $ 0205 0 '~6 S O 59 $ 0 69 S 1,11 S 0.00 0.41 1.17 1.75 2,34 2,70 2.90 3.29 3.~i 3.56 0.00 N 0 0 g 0.42 N 78 5 W 1.17 N 88 20 W 1.76 S 84 3 W 2.35 S 83 39 W 2,74 S 80 14 ~ ) 3,02 $ 78 42 k 3.36 $ 78 7 W 3.53 $ 74 42 W 3,73 S 72 41 W -3.59 -3.52 -3.42 -3 48 -3:59 -3.44 -3.41 -3.50 -3.44 -3.58 0 33 0 02 0 13 0 09 0 46 0 12 0 24 0 20 0 30 0 05 I, 3'.t $ 1,61 179.5 1 87 S 2025 2078 1938 1,~2 $ 1. 4 S 1,54 3.79 3.75 3.68 3'75 3.73 3.69 3.78 3,70 3.81 4.02 S 70 35 W 4.08 $ 66 49 W 4,09 S 64 4 W 4,i9 S 63 31 W 4.38 S 62 29 W 4.27 $ 61 3 W 4,lb $ 62 26 W 4.24 S 63 2 W 4.14 S 63 34 W 4.11 S 67 58 W -3 78 -3:79 -3,49 -3.1o -2,55 -1,84 -1,41 -1.02 -0,48 0.14 0 09 0 34 0 21 0 09 0 09 0 84 0 23 0 24 0 08 0 11 1.47 1.40 0.82 0 02 0:82 1,52 1.83 2.07 2.45 3.04 4.00 4.00 3,63 3.12 2.47 1.66 1.19 0.76 (),lb 0,53 4.26 S 69 52 W 4.24 $ 70 45 W 3.72 S 77 18 W 3.12 N 89 38 W 2.60 N 71 38 W 2.25 U 47 33 W 2.18 N 33 4 k ) 2,21 N 20 IOW 2.45 U 3 40 W 3.08 N 9 59 E 0,91 1.79 2.65 3.11 2,97 2 61 2!41 2 23 2.04 1.88 0.05 0,17 0,47 0,49 0,25 0,27 0.33 0,24 0,14 0,12 3.b0 4.04 4.4] 4.90 5.85 6.67 7.36 7.89 8.25 8.55 1,3~ 2.33 3.2b 3.7~ 3.76 3.49 3.39 3.27 3.13 3.Ol 3.85 h 21 2 E 4.6b N 29 55 E 5.49 N 36 ll E 6.24 N 37 18 E 6.9b N 32 42 E 7,53 N 27 3~ E B,IO ~ 24 43 E 8.54 N 22 32 E 8.82 N 20 45 9.06 a 19 22 £ STANDARD ALASKA P~ODUCTION CO, 4-42/P-]8 ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DA~rg~ 1-dUb-87 PAGE 2 DATE OF SURVEY: 23-JUN-87 KELLY BUSHING ELEVATION: 55,18 FT ENGINEER: G,~ SARBER INTERPOLATEP VALUES FO~ EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH D~PTH DEG MIN PEG 4000 O0 3999,93 5944,75 4100 O0 4099 93 4044,75 4144~75 4 44,74 42O0 4]00 4400 4500 4~00 4700 48OO 4900 O0 4199 93 O0 429Q 92 O0 4399 92 4344,74 O0 4499 91 4444.73 O0 4599.91 454~,73 O0 4699 gl 4044.73 00 4799:9~ 4744.73 O0 4899.90 4844.72 0 7 $73 2 W 0 28 $ 21 37 E 0 28 $ 28 5 E 0 31 $ 14 37 E 0 28 S 17 3 E 0 22 $ 14 38 E 0 20 S 35 55 g 0 18 S 34 15 g 0 19 $ 33 24 E 5000 O0 4999 90 4944.72 0 44 O0 5199 47 5144.29 6 30 5300 O0 b298,5b 524~ 38 8 51 5400 O~ 5397,03 5341:85 11 9 5500 O0 5494.71 5439' 53 13 35 5600 O0 5591,41 5536,23 15 51 5700 O0 5686.95 5031,77 18 17 5800 O0 5781.35 5726.18 20 4 5900 O0 5874.84 5819,56 21 38 S 52 bE S 73 6 E 8 70 32 g S 84 18 E S 85 22 g S 86 25 E S 87 52 E S 88 20 g S ~7 55 E S 87 29 E VERTICAL DOGLEG RECTANGUI,AR COORDINATES HORIZ,, DEPARTURE ~ECTIUN SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 6000 O0 5967,00 5911,82 24 5 6100 O0 6057,36 6002,18 26 26 6200 Oo 6145.90 6090.78 28 56 6300 O0 6232 50 5177,32 31 8 6400 O0 0316:87 6251.69 34 0 6500.00 6397 98 ~342,80 ]7 27 6600.00 6475:96 6420.77 39 49 6700.00 6551,99 6496.8! 40 51 6800.00 6627.54 5572.36 41 11 6900.00 6702.68 6647.50 41 25 S 87 17 E S 86 43 g 8 86 31 E S 86 9 g S 85 22 E S 84 51 E S 83 44 E S 82 20 E $ 82 21 E S 82 10 E 1,77 0,44 8,69 N 2.91 1.75 0 67 8.81 N 2,91 1.88 0:~ 8 3, N 2.98 2.36 O,~. 7:57 N 3.37 2,71 0,09 6,73 N 3.~1 3.07 0,52 5.93 N 3.87 3.39 0,07 5.16 N 4.08 3.7! O 50 4,59 N 4.34 4.11 0:23 4.o/ N 4.6u 4.55 0,05 3.61 N 5.06 7000,00 6777.81 6722.53 41 20 7100.00 6852.25 6797.05 42 34 7200.00 6925.49 6870.31 43 14 7309.00 699821 6943,03 43 19 7400.00 7071124 7016.06 42 4~ 7500.00 7144'80 7089.62 42 22 7600.00 7218.9~ 7163.76 41 59 7700.00 7293.6~ 7238.48 41 ~0 7800.00 7359.07 7313.89 40 58 7900.00 7444.8~ 7389.08 40 17 5 22 7;92 16.50 ~9 89 47:23 68 56 93 91 123 27 156 07 191 44 230,09 272,77 319,01 369,00 422,56 480 96 543 53 608 47 673 98 739 97 S 81 57 E 805 96 S 8! 10 E 872 70 $ 80 3~ E 940 76 S 80 29 g 1009 36 S ~0 28 E 1077 63 $ 80 26 E 1145,31 $ 80 43 E 1212,38 S 80 52 E 1278,81 S 80 48 E 1344,45 S BO 55 E 1409.56 9,17 N 18 30 E 9,28 N 18 ~7 E 8,85 N 1939 E 8,28 N 23 5R E 7,64 N 28 12 F , 7,08 N 33 4 I ] b,58 N 38 22 h · 6,32 N 43 23 E 6,20 N 48 59 g 0,21 N 54 31 E 0,72 4.44 3 21 2 36 2 25 2 07 2 42 1 86 ! 54 2:13 2.95 N 5.65 1.75 N 8.21 0,09 S 16.62 1.99 S 29.88 3,44 S 47.18 68,4'? 6,37 N 62 26 E 8.40 N 77 58 E 16.63 S 89 41 g 29,95 $ 86 11 E 47,31 S 85 49 E 68,66 5 85 44 E 5,10 S 6,25 S 93,89 E 94,10 S 86 11 E 7.1'7 S 123,38 ~; 123,59 S 86 40 E 8,21 $ 156.~1 g 156,53 $ 86 59 E 9,bi S 191,80 E 192,04 $ 87 7 E 2,61 1,72 2, 27 0,29 0,41 11 3~ S 230,54 h 230,82 S 87 10 E 13:63 S 2'13.29 g 273,63 S 8'1 8 E 16,34 S 319.57 g 319.99 S 87 4 g 19,40 S 359.57 E 370,08 S 8b 59 E 23,44 S 423.06 E 423,71 S R6 49 E 28,41 $ 48i.31 k: 482,14 S 86 37 r 34.5~ $ 54],60 ~ 544,70 S 86 2~ l. ) 42,48 $ 608,06 E 609 54 $ 96 0 E 51,17 S 673.0U E 674:94 S 8~ 39 E 60,05 $ 738.39 g 7~0,~3 S ~5 2~ E 0.53 I 39 0 65 0 34 0 23 0 36 0 17 0,65 0,35 0,77 69.17 S 803,74 g 805.71 S 85 4 E 78 91S 859.7~ g 873.35 S 84 48 E 89:79 S 937.00 E 941,29 S ~4 $! E 101,14 S 1004.70 E 1009.7U S 84 15 E 112,44 $ 1072.08 E 1077,96 S ~4 0 K 123,b9 S 113~.~7 g 1145.57 S 83 ~8 g 134,69 S 1205,07 E 1212.57 S ~3 37 E ~45,29 S 1270.68 E 1278.96 $ 83 28 E ~55,72 S 1335.51 ~ 1344,56 $ B3 20 E 166,10 $ 1399.92 g 1409,74 S 83 14 E COMPUTATION OATEI 1-dUb-8? PAGE STANDARD ALA6KA PRODUCTION 4-42/P=3B ENDICOTT NORTH $60Pg~A6ASKA [)ATE OF SURVEY: 23-JUN-87 KELLY' BUSHING E&EVATI[)N: 55.18 FT INTERPOLATED VAbtJES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEP'fH DEPTH DEG FIN DEG FIN VERTICAL DOGLEG REC%ANGULAR CO{)~UI~ATE$ HGAIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WE.ST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 7521.45 7466,28 39 45 8100.00 7598 69 7543,51 39 17 8200 O0 7676,19 762~ Ol 39 8300 O0 7753.76 769~:58 39 4 8400 O0 7~31.39 7776,2~ 39 16 8500 O0 7908,~4 7853,16 40 4 8600 Oo 7984,82 7929,64 39 57 ~700 O0 8061.3~ 800~.20 40 3 8~00 O0 813'7 ~9 ~082,51 40 19 ~900 O0 8214102 8158,~4 40 4 S 81 24 E 1473.92 $ 81 15 g 1537,43 S 81 9 g 1600.6! $ 81 17 g 1~.70 0 74 0 33 0 15 0 17 0 85 0 65 0 67 1 22 0 26 071 175 95 $ 146~.44 E 1473 98 S 83 8 ~ 185 43 S 1526,26 E 15.37 48 S 83 4 E 195 18 S 1588,71 E 1600 65 $ 82 59 g 204 80 $ 1651,08 E 1663 73 S 82 55 E 214 21S 1713.41 E 1726 75 $ 82 5~ E 223 12 $ 1776.65 E 1790,61 S 82 50" ) 231,64 $ 1840.49 ~.i 1855,01 S 82 49 L 239,32 S 1904,36 E 1919,34 S 82 50 E 245,49 S 196R,70 E 1983,95 S 82 5] E 251,80 $ 2033,00 E 2048,53 S 82 56 E 9000 Oo B2qO 76 8235.58 39 41 9100 00 8307~99 8312,81 39 10 9200 O0 84~5,75 9390,58 38 41 9300 9400 9500 9~00 9700 9800 9900 00 8524.17 8468,99 38 4 O0 8503 18 8548,00 37 33 00 8682:61 8627.43 37 26 00 8761; 64 8706,46 38 5 O0 8840 O1 8784,83 39 44 O0 8917:70 8862,52 39 18 00 8994.~0 8939,62 39 54 6 83 14 E 2112,60 S 82 10 g 2176.13 $ 81 18 E 2238,98 $ BO 27 E 2301,03 S 79 57 E 2362 26 $ 79 49 E 2422:95 S 79 28 E 2484i 13 S 79 13 f 2546 15 $ 79 16 g 2609:00 S 79 14 E 2§72,5~ 0,57 0,84 0,96 0,75 0.54 0,53 0.58 0,54 0,52 0,83 258,97 S 2096 71 g 2112.65 $ 82 5~ E 267,00 S 2159:73 E 2176,17 S 82 57 E 276,03 $ 2221 94 E 2239,02 S 82 55 E 285,93 $ 2253:22 E 2301,06 $ 82 5! E 2 96,34 S 2343,51 E 2362,27 $ 82 47 E 307,05 S 2403 42 E 2422 95 $ 82 43 E 318,03 S 2463:09 E; 2484:1~ S 82 38 E 329,5b $ 2524,73 El 2546,15 $ 82 33 E 341,30 $ 25~,5~ E 2609,00 $ 82 28 E 353,18 $ 2649,15 E 2672,59 $ 82 24 E 10000.00 9071.11 ~015 93 40 38 10100.00 9146.85 9091:~7 40 27 10200.00 9223,27 9168,09 40 6 10300.00 9299,90 9244,72 39 42 10400 O0 9377,13 9321.95 39 14 10500:00 9454.89 9399.71 38 42 10600.00 9533 37 9478.19 37 51 10700.00 9612:70 9557.52 37 3 10800 O0 9693.07 9~37.89 36 0 10900:00 9774.69 9719.51 34 32 $ 78 4~ E 2737,08 $ 77 48 E 2802,18 S 77 24 E 2866.44 $ 76 55 g 2930,41 S 76 21E 2993 5~ S 74 55 E 3056:00 S 73 33 ~ 3117,32 S 71 45 E 3177.30 S Oq 53 E 3235,55 S 68 14 E ]291,70 1,35 1,05 0,35 1,15 0,66 1,02 1,17 1,64 3,70 1.83 355 35 $ 2712.61 E 2737 11 S ~2 19 E 378 67 $ 27'16.53 E 2802~23 S 82 14 g 392 63 $ 2839,52 E 2856,54 $ 82 7 E 406 78 $ 2902,19 E 2930,55 S 82 ! E 421 42 S 2963,99 E 2993,80 S 81 54 E 436 9~ $ ]024.91 E 3056,~1 $ 81 46 F 453 78 S 3084,57 g 3117,77 S 81 37 t ) 471:8~ $ 3142,?0 E 3177,93 S O! 27 E 491,41S 3198.90 E ]236,43 S 81 15 ~ 511.9; S 3252.86 E ~29~.90 $ B! 3 E 11000 O0 9851,77 9802,59 ]3 4 11100 O0 9942.29 9887.12 31 54 11200 0(} 10027.28 9972,10 31 34 11300 O0 10112,73 10057.55 30 58 11400 O0 10198.6~ i0143.50 30 24 11500 O0 10285,24 10230.06 29 43 11600 O0 10372.41 10~17,23 28 4b 11700.00 10460,5b 10q05,38 27 53 11800,00 10548.99 10493.81 27 50 1183g,0t) 10583,48 10528,30 27 50 $ bO 43 E 3345,42 S 64 38 E 3396 58 S 64 24 E 3446:51 S 64 35 E 3496~00 S 64 44 E 3544,64 6 64 41 E 3592,30 S 64 30 E 3638,93 $ 63 59 g 3683 7~ $ 54 1 g 3727:9, S 64 ! g 3745,24 1.81 0,93 0,52 0,61 0,83 0,67 1,55 0,36 0,00 0,00 533,35 S 3304.25 E 3347,02 $ 80 49 E 555.24 $ 3352.99 E 3398,65 S 80 35 £ 578.07 $ 3~00,40 ~ 3449,26 $ 80 2! E 600,42 $ 3497.38 ~ 3499.28 S 80 7 E 622,21S 3493 O0 E 3548,58 $ 79 54 E 643,63 S 3538:87 E 3596.93 $ 79 41 g 654,5~ $ 3583.18 E: 3644,29 S 79 29 E 685,15 $ $525.66 E 3689,83 $ 79 17 E 705,62 S 3657 54 E 373~.90 ~ 79 6 E 713,59 S 3684:02 E 3752,49 $ 79 2 E COMPUTAI'IOh bATE: 1-dU6-B7 PAGE STANDARD ALASKA PRODUCTION CO, 4-42/P-38 SDI ENDICOTT NORTH SLOPE,ALASKA DArE OF SURVEY1 23-JUN-BT- KE66Y BUSHING EbEV~TION{ 55.1B FT ENGINEE~t G, SARBER INTERPObATEO 'VALUES FOR EVEN 1000 FEET OF 'MEA$IJHED DEPTH TRUe; SUB-SEA COURSE MEASURED VERTIC~A[, VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG ~IN VER~ICAB DOGb~G bt~CI'ANGULAR COORDI{~ATE$ HORIZ. DEPARTURE BECTIDN SEVEEIIY NORTH/SOl)TH EAGT/,ELT DIST.AZIMUTH FEET DEG/IO0 FEET F~SE'I~ FEET DEG MIN 0 O0 0 O0 "55,18 0 0 1000 O0 g99 99 944,81 0 11 2000 O0 1999 99 1944,81 0 5 3000 O0 2999 9b 2944.77 0 36 4000 O0 3999 93 3944.75 0 4 5000 O0 ~999.90 4944,72 0 44 6000.00 59h7.00 59]~.$2 24 5 7000.00 b777.81 b722.6~ 41 ~0 8000,00 7521 4b 7466.2~ 39 45 9000.00 8290~75 8235.58 39 41 N 0 0 E 0,00 0,00 $ 21 34 W '3.59 0.33 $ 60 49 W "3,78 0,09 N 61 49 E 0,91 0,05 N 02 43 g 1,77 0,44 S 52 5 E 5.22 0.72 S 87 17 E ~30,09 2.61 S 81 57 E 805.96 0 53 S B1 24 E 1473,9~ 0:74 $ 83 14 E 2112.60 0,57 0.00 N 0 O0 g 0,00 N 0 0 E 1,34 S 3~79 w 4,02 $ 70 35 W 1,47 $ 4,o0 w 4,2b $ 69 52 W 3,60 N 1.38 £ 3,85 N 21 ~ E 8,69 N 2,91 ~ 9,17 N lB 30 ~. 2 95 N 5'65 E 6.37 ~ 62 26 E ) 11 38 S 230.54 E 230,B2 S 87 10 E ' b9 17 $ 803'74 E 806,71 $ 85 4 E 1.75 95 $ 1463,44 g 1473,98 S 83 8 ~ 258 97 S 2096,71 i 2112.b5 $ 82 57 E 10000 O0 9071 11 9015.93 40 38 11000:00 9857~77 9802.59 33 4 11839,00 10583,48 1.0528,30 27 50 S 78 48 E 2737.08 S ~6 43 g 3345.42 S 64 1 E 3745.24 1,35 1,81 0,00 365 35 $ 2712,61 k 27~7,~1 S 82 19 E 533:35 5 3304.25 g 3347,.2 S 80 49 E 713'59 S 3684.02 E 3752,49 S 79 2 ~ STANDARD ALASKA P~ODUCTION CO, 4-42/P-38 ENDICOTT NORTH SLOP~AbA~KA COMPUTATION DA~E~ 1-~UL-87 PAGE DA~e: OF SORV£X, 23-JUN,,8?- KEbLY BUSHING ELEVATION)55* INTERPObATED VABtJES FOR EVEN 100 FEET OF SUOmSEA DEPTH TRUE SUB-SEA COUR$E MEASURED VERTICAb VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN LEG 0 O0 55 18 155 lB 255 19 355 19 455 19 555.1q 655 19 755!19 855 lq 0 O0 55 18 155 18 255 15 355 16 455 18 555,18 655.18 755 18 855~1~ -55,18 0 0 N 0 0 E 0,00 0 17 N ~3 5 W 1o0.00 0 26 $ 84 48 W 200.00 0 2! $ 67 20 W 300,00 020 $ ~4 20 w 400,00 0 13 S 53 48 ~ 500.00 0 10 S' 67 31 W 600,00 0 11 S 72 55 W 700,00 0 9 $ 17 9 w 800.00 0 8 S ~5 2b ~ 955 19 955 18 900,00 1055 19 1055:18 1000.00 .1155 1255 1555 1655 1755 1855 19 1155,18 1100,00 19 1255 18 1200,00 19 1355i18 1300,00 19 145518 1400.00 19 1555,18 1500,00 19 1655.18 1600,00 19 1755,18 1700,00 19 1855,18 1800,00 0 11 S 45 55 W 0 9 S 13 35 E 0 6 S 26 3 E 0 7 839 8 W 0 5 S 84 27 E 0 5 N 14 14 g 0 3 S 79 52 ~ 0 5 N bl 48 E 0 1i N 20 45 W 1955 19 1955,t8 1900 O0 2055 19 2055.1~ 2000:00 )55 19 2155,18 2100.00 255 20 2255,18 2200,00 2355 2455 2555 2655 2755 2855 20 2355,18 2300.00 21 2455,18 2400.00 21 2555.18 2500,00 21 2555.18 26U0.00 22 2755.18 2700.00 22 2855.18 2800,00 0 8 N 86 52 W 0 25 N 32 48 E 0 33 N 30 0 £ 0 35 N 37 53 E 0 38 N 48 47 E 0 18 N 57 36 E 0 lb N bO 25 E 0 24 N 57 U E 0 33 N 45 38 E 2955 22 2955.18 2900,00 3055 23 3055.1~ 3000.00 3155 24 3155.18 3100,00 ]255 24 3255.18 3200.00 3355 24 3355.18 3300.00 3455 25 3455.~8 3400.00 3555 25 3555.18 3500.00 3655 25 3655.18 3600.00 3755 25 3755.18 3700.00 3855,25 3855.18 3800,00 VERTICAL OOGbiO RECTANGULAR COt)HOINATE& HORIZ, DEPAATURE SECTION SEVERITY NORTH/SOOtH EAS~/WEST DI~T, AZIMUTH FEET DEG/IO0. f'EET FE~T FEET DEG MXN 0.00 0,00 '0,13 2,49 '0.87 0,25 :1.4 ,04 0,05 52 0.38 '2~73 0 14 : .o4 o:,s '3.25 0,i7 '3.30 0,18 0 O0 N 0 02 N 0 08 N 0098 0238 0378 0.55 0,63 S 0,83 S 1,03 S 0.00 E 0,00 N 0 0 E 0.13 w 0,13 N 81 38 W 0.87 w 0,88 N 8435 W 1,48 w 1.48 $ 86 39 W 2.08 W 2,09 S 83 45 W 2.59 W 2.62 S 81 48 ~ ) 3,]8 , 3,48 S ? I W 3.45 w 3,61 $ 73 20 W '3.52 0 16 '3,57 0[11 -3.45 0 12 '3 42 0,12 =3i56 0,15 '3 50 0,14 '3,39 0,17 '3,48 0,15 '3.46 0,24 '3.50 0,13 1225 1505 1725 1845 1938 2 08 S 20U S 1895 1955 1,67 3,70 w 3,90 8 ~ ~ W 3,79 W 4.08 S W 3.71 W 4,09 S 65 2 W 3.69 w 4,12 66 I, ~4 W 4,30 $ 6 W ,80 ~ 4,34 $ $1 1~ W 3,68 W 4,19 $ 61 32 W 3.75 w 4,20 $ 63 14 W 3.74 ~ '4,20 $ 62 42 W 3.75 W 4.10 $ 65 59 '3,70 0,37 "3.82 0,50 '3.66 0.40 '3.20 0 14 -2.84 0~18 -2.15 0.08 '1,60 0.07 "1 23 0,40 -0:73 0.17 -0.13 0,37 1.44 $ 1,49 S 1.1J S 0,35 S 0,48 N 1,2J N 1,70 N 1.97 N 2.25 N 2,74 N 3.02 4,05 3.35 2,80 2.01 1.39 0,98 0,44 0.22 4.17 S 69 48 W 4.32 $ 69 46 W 4,00 S 73 31W 3,37 $ 83 47 W 2.84 N RO ~1 W 2,35 N 58 31 W 2 20 N ]9 2i k 2:20 N 26 31 W 2 30 N 11 ~ W 2~75 N 4 39 £ 0,52 0,40 1.39 0,04 , 27 0,35 ,94 0,37 3.10 0,24 2.76 0,24 . 51 0,10 .32 0,21 2,12 0,25 1,98 0,34 3,37 3,85 4,28 4,m7 5 44 6 33 7 06 7 65 8 09 8,41 1,90 2,84 3,57 3,8] 3,60 3,44 3 34 3~19 3,09 3,50 4,29 N 26 5,14 5,88 6,66 N 35 7,29 7,85 N 26 0 8,35 8.?0 STANDARD ALASKA PRODUCTION 4-42/P-38 SOI EhDICOTT NORTH SLUPE,ALASKA COMPUTATION DATEr 1-JUh-87 PAGE DArE OF SURVEY: 2S-JUN-87 KEGi~ BUSHING ELEVATIONI 55,iq E~GINEER{ G, SARBER INTERPOLATED VALUES FOR EVEN 100 f'EET OF SUB-SEA DEPTH TRUE SUB-SEA NEASURED VERTICAL VERTICAL DEVIATION AZINtJTH DEPTH DEPTH DEPTH OEO 3955 25 3955,18 3900,00 4055 25 4055,18 4000 O0 4155 4255 4355 4455 4555 4655 47 25 4155,18 4100,00 26 4255,18 4200,00 26 4355,18 4300,00 26 4455.18 4400.00 27 4555.18 4500,00 27 4655.18 4600.00 27 4755.16 4700.00 27 4855.18 4800,00 VERTICAL DOGLEG RECTANGULAR COOrDINAtES HORiZ, DEPARTURE SECTION SEVERITY NORTH/SOUIi{ EAST/WES~ DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~IN 50 .29 5155.49 525 6 6.1 535~,4~, 545 41 556~:4! 5666.5g 587 87 0 5 N 38 3 W 1,76 0 6 N 0 26 E 1,81 0 18 S 10 51 g 1,74 0 30 S 28 b E 2,14 0 31 S 12 32 g 2,56 0 27 S 17 38 E 2,89 0 30 S 17 1 g 3,26 0 21 S 24 3 E 3,54 0 22 S 32 53 g 3,94 0 22 S 44 53 f 4,35 S 39 53 E 4.83 S 62 35 g $ 78 6 E 12,06 $ 81 35 E 23,58 S 85 30 E 39,31 S 85 31 ~ 59 38 S 87 35 E 83:95 S 88 19 g 112.99 $ 88 ~ g 146,61 S 87 33 g 183,74 4955.18 4900.00 0 31 5055 18 5000'00 1 3 4 5155~1~ 5100,00 5 2 5255 18 5200,00 7 44 5355 18 5300.00 I0 7 5455 18 5400,00 12 33 5555 18 5500,00 15 2 5655 18 5600.00 ' 17 36 5'155 18 5700,00 19 38 5855,18 5800,00 21 & 87 21 g 224 83 $ 86 43 g 271:68 S 86 30 ~ 324,15 S 85 56 E 382,86 S 85 8 E 449 10 S 84 4 g 526~37 S 82 25 E 611.23 S 82 16 E 698,21 & ~2 O g 786.09 S 81 8 E 875,40 5987 05 5955,18 5900.00 23 45 6097:56 e055,18 6000,00 26 23 6210 56 ~155 18 6100,00 29 10 6326:60 6255:18 6200.00 31 46 6446 63 6355.18 6300 O0 35 40 6573 05 u455 1~ 6400:00 39 18 6704 22 ~555:18 6500.00 40 50 6836 75 6655~18 6600.00 41 13 6969 88 6755,18 6700.00 41 13 7103 98 6855.18 6800.00 42 37 7240,83 5955,18 6900,00 43 21 7378 11 7055,18 7000,00 42 53 7514 04 7155.1~ 7100,00 42 18 65 7255,1~ 7200,00 41 38 62 7355,18 7300.00 40 57 52 7455 18 7400,00 40 il 78 7555~18 7500,00 39 25 92 7655.18 7600.00 39 8 83 7755.18 7700.00 39 4 78 7855,1~ 7800.00 39 30 S 80 28 E 958,78 S 80 28 E 1062,77 S 80 28 E 1154,76 S 80 49 E 1244,82 S 80 50 E 1332,41 $ 80 59 E 1418,39 S 81 27 E 1501~83 S 81 7 E 1583~53 S 81 17 E 1664,86 S 81 52 E 1746,25 7648 7781 791i 804 8172 8301 8430 0,40 0,36 0 53 0 17 0 22 0 28 0 34 0,19 ~o37 8,65 N 2.90 5 9,14 N 18 30 g 8,75 N 2,97 g 9,25 N 18 42 E 8,64 N 2,88 g 9,10 N 18 26 E 7,90 h 3,18 E 8,52 N 21 55 g 7,13 N 3,51 g 7,95 N 2b 11 6,28 N 3,7,3 ~ 7,30 5 4'; N 4,00 E U,78 4:82 N 4,19 ~ 6,39 N 40 59 E 4.28 N 4,53 E 6,23 3.81 N 4,88 E 6,19 0.45 2,90 2,62 1,78 2,70 2,56 2,02 2,24 1,72 1,72 3,28 2,39 0,75 1,25 2,82 4,45 5'86 6 85 7[87 9 29 5.29 E 6,23 N 58 13 E 6,47 E 6,90 N 69 45 E 12.26 E 12,29 N 86 30 E 23.62 E 23,65 $ 86 58 E 39,28 E 39,38 $ 85 53 ~ 83,9U E 84,10 S 86 113.05 E 113.26 $ 86 31 E 146,82 E 147,0t $ 86 5~ E 184,08 g 184,31 S 87 6 ~ 2,57 1,65 2,30 2,49 3 73 2 17 0 29 0 21 0 81 I 19 11,1J $ 225,27 E 225,55 $ 87 10 g 13,57 S 272.20 E 272,53 $ 87 8 E 16,65 S 324,71 g 325,14 S 87 3 E 20,42 S 383,42 E 383,9~ $ 86 57 g 25,64 $ 449,55 E 450,28 S 8~ 44 E 32,7b S 526,54 E 527,55 S 86 26 F 42,85 S 610,80 E 612,30 S 8S 59 ~ 54,40 S 697,01 E 699,13 $ 85 32 E 56,41S 784,06 E 786,87 $ 85 9 ~ 79,32 S 872,45 E 876,05 $ 84 48 ~ 0,49 0,64 0,47 0,89 0,28 0 68 0 76 0 26 0 18 I 04 94,42 $ 964,65 E 969,2b $ 84 24 g 109,98 S 1057,41 E 1063,11 S 84 3 E 125,2o 5 1148 19 E 1155,00 S 83 46 g 139,89 $ 1237~10 E 1244,99 S 83 32 E 153,79 S i323'63 g 1332,5J S 83 22 E 167,48 S 1408 55 E 1418,47 S 83 1~ E 180,10 $ 1491:0b E 1501,89 $ 83 6 E 192,54 S 1571,82 E 1583.57 S 83 0 g 204,97 $ 1552,22 E 1664.88 S 82 55 E 217,01S 1732,7] ~ 1746.27 S 82 51E STANDARD ALASKA PRODUCTION CO, ~-42/P-38 SD! ENDICOTT NO~TH $bOPE~ALASKA COMPUTATION DATE: 1-JOb-87 DArE OF SURV£Y: 23-JUN-87 BUSHING EEEVATIONI 55,18 FT ENGINEER~ G, SARBER INTERPOLATEO VALUES FOR EVEN 100 FEET OF SUB-SEA OEPTH T~IiE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZI~iJTfi DEPTH DEPTH DEPTH DEG SIN DEG YERTICAL DOGLEG RECTANGULAR CO0~OINATE$ HORIZ, DEPARTURE SECTIOM SEVERITY MORTH/SOU~H EAST/WEST LIST, AZIMUTH FEET DEG/100 FEET FEET FgET DEG NXN 8561 28 7955,18 7900,00 40 5 869~ ~ 8055,18 8000,00 40 13 oo.oo 895 73 8255 18 8200,00 39 51 9083 48 8~55 lB 8300.00 39 15 9212 07 8455.18 8400.00 38 35 9339 33 8555.~7 8499,99 37 51 g465 49 8655,18 ~600,00 37 22 9591~7~ 8755,18 8700,00 38 3 9719,46 8855,18 8800,00 38 50 9848 52 8955 18 8900,00 39 31 9979 04 9055 18 9000.00 40 27 101 10371 10500 10627 10753 10876 10996 93 9155 18 9100.00 40 22 73 9255 18 9200.00 39 59 63 9355 18 9300,00 39 21 37 9455 18 9400.00 38 42 58 9555 1~ qSO0,O0 37 40 03 9655 18 9600,00 36 27 24 9755,18 9700,00 34 49 91 9855,1~ 9800,00 33 7 11115 17 9955,18 9900.00 31 52 11232 71 1005~,18 10000,00 31 24 11349 46 10155.18 10100.00 30 45 11 465 35 10255 18 10200.00 29 57 11580 33 10355:18 10300.00 29 4 11 807 oO 10555.18 10500.00 27 50 11839.00 10583.48 10528.30 27 50 $ 82 27 E 1830.09 S 83 43 E 1914.08 S 84 ]4 E 1998'77 $ 83 31 g 2083.02 S 82 21 E 2155,69 S 81 10 E 2246.53 S 80 16 E 2~25,19 S 79 50 E 2402,03 $ 79 ~0 E 2479,07 S 79 1] E 2558,32 S 79 1¢ E 2539 7~ $ 79 0 ~ 2723~48 $ 77 43 E 2809,23 S 77 19 E 2893,21 $ 76 35 E 2975,7t S 74 5a E 3056,22 S 73 8 E 3133.99 S 70 40 E 3208,~1 S 68 40 E 3278,56 S 66 .45 g 3343.79 S 64 25 E 3404,19 $ b4 30 E 3462, 85 $ 64 47 E 3520,13 S 64 39 k; 3575,89 S 64 37 E ]629.9(.) S 63 59 E 3681,01 S 64 1 E 3731,07 S b4 1 E 3745.24 0.52 1.19 0.33 0.73 0.92 1.09 0.55 0,34 0,62 0,48 0,42 0.93 0,95 0,69 0.59 1.03 1,06 1,53 1.44 1,79 0.52 0,50 0,49 0,65 1,38 0,25 0.00 0.00 228,42 S 1815,79 E 1830 10 S 82 49 E 238,77 S 1899,15 E 1914 10 $ 82 50 E 246.87 S 1983.50 E 1998 80 S 82 54 E 255,50 $ 2067,32 ~ 2083 06 S 82 57 E 205.59 .5 2149.39 E 2165 73 $ 82 5, , 277i17 S 2229740 E 2246.56 $ 82 54 ' ) 289 9~ $ 2307 06 E 2325,21 $ 82 50 ~. ~03 ~O S 23~2 80 E 2402,04 $ 82 44 E 317 10 S 2458,70 E 2479,07 $ 82 ]9 ~ 331,8~ $ 2536,'71 E 2558,~2 ~ 82 ]~ g 352.7e S 2599 24 E 2'123,51 $ 8220 E 80,17 $ 2783:45 E 2809,29 S 82 13 g 98,50 $ 2855,75 E 2893,33 S 82 $ E 417 22 $ 2946,51 E 2975,91 $ 81 ~6 E 437 02 $ 3025,i3 E 3056,54 $ 81 4~ E 458 62 $ 3100,75 E 3134,48 $ 81 3S ~ 482 04 $ 3172 75 E 3209,16 $ 81 21 £ 507 01 8 3240:25 E ~279,68 $ 81 6 B 532 6~ & 3302.69 E ~345,37 $ 80 SO ~ 558 70 $ 3360.22 E 3406 35 585:44 S 3415,90 E 3465 7! S 80 16 611.25 S 3470.31 g 352373 S 80 0 g 636 25 S 3523.29 ~ 3580 2~ 8 79 ¢5 £ 660 50 S 3574.61 g ~6~5 12 $ 79 31 g 683 9! $ 3623.11 E 3687 09 707 05 $ 3670,58 E 373~,06 S 79 5 ~ ') 713 59 $ 3~$4,02 g ~752,¢9 $ 79 2 STANDARD ALASKA PRODUCTION 4-42/P-38 SDI ENDICOTT NORTH 5bOPE~AbASKA ~ARKER CO, COMPUTATION DATE~ INTERPOLATED VALUES MEASURED DEPTH BELO~ KB 11839,00 FOR CHOSEN FRON KB 105B3,4B HORIZONS SUB-SEA 10528, :t0 DA'I~E OF SURVE)'~ BUSHING Eb~VATIONt ENGIN~ER~ PAGE 23-JUN-8~ 55,18 G, SARBER 628 SURFACg LOCATION AT ~EL, SEC 8~ TllN~ R17E REC~ANGULAR COORD]~NATE$ NORTH/SOUTH EAST/~EST 713.59 S ~}68~,02 E STANDARD ALASKA PRODUCTION CO. 4-42/P-38 SOl ENDICOTT NORTH SLOPg~ALASKA CO~PUTAT~ON DATg~ 1-dOb-87 PAGE DAT~ OF SURV~¥~ 2)-JUN-8~ KELLY ~USHING EGEVATION: 5§,18 ENGINEER) G, SARBER DRILLERS DEPTH MEASURED DEPTH 11839,00 FROM K8 10583,48 ORIGIN= 2673 SNL, 028 TVD SUB-$~A 10528,30 713.59 $ ]684,02 E FINAl, WELL 6OCATION AT :r~OE SUB-SEA ~E;ASOREL) VE~TICAb VERTICAL DEPTH OEPTH D£PTH 11839,00 1058],48 1052R,30 HORIZONTAL DEPARI, URE DISTANCE AZIMUTH FEET OEG MIN 3752.49 S 79 2 g SCHLUMBERGER 13 1 REC T I ONAL SURV E Y COMPANY STANDARD ALASKA PROD. CO. WELL 4-42/P-38 SDI FIELD END I COTT COUNTRY U.S.A. RUN 1 DATE LOOOED 23 - JUN - 87 REFERENCE 72377 WELL' 4-42/P-38 SDI · (2673' SNL, 628' WEL, SEC 8, TllN, R17E) HORIZONTAL PROJECTION NORTH 4000 3000 2000 ! ooo - 1000 -2000 ========================================== '"%'T"T"T"T-T"%'T'"i .... ~: ........ ::u..:...: .... :. :::::::::::::::::::::::::::::::: -3000 ---~-.+--~ ....... h,.i,.--~---~-.-+.- · T "~---~.--~ i: .--i.-.H---+---?H-..+.---i.....--~.-~-.--~..--~-+-~---?-~--. ..... · '"'T"'?"'~ ...... ?"'?"'?"'T" ................ ~ ...........-c.c-+---+--.m.-c.c ~-.. "-=- =--,-"?--',-'-?'.'=v-- $C~TH -4000 1 .... ; ..... -2000 - 1000 0 1000 2000 6000 EClST 3000 4000 SO00 WELL' 4-42/P-38 SDI VERTICAL PROJECTION "(2673' SNL, 628' WEL, SEC 8, TllN, R17E) 277. -2000 - !000 0 0 ]000 2000 9000 4000 5000 ....... : ........ :..~...:....;,.,.;...: ....... ; ...... ;,...:u ......... : ............ '"~"';"-';"; ....... :"';'":'"~"'1 ....... ;...:.u...;: ........ =====================':-':'T::::'::' :::?;::7z:!::/:::::::::!":;:7::::;':.,:::-':::;::;::t-- ..... : .......... .~ .................... :....: ............. .~ ......... : ....... :.. ; ;..;;,ri ;; f'";": "'Z'T';"?'"; t";"¢' :":';~ .... ; 't": ,'? :t ' :'-; i ....... : ..; ~ .... · . .~ ......... ~ ,~ZZ . . ~. -'Z"'~'7":'"r'"Z""y'~ ...................... ~ ..................................................... ...................... .................... i ................. ' ........................... ~ ....... ~ ................. r ....... ~.--i-;.--i;;N;Z.---...i;.;.Z...~ .;....' i..;...~i;;;...~...~ .Z.:.;.;;..:;.;.;.:..;:..' L;;;...;...;;; ....; .............. L.:;;_.; ........ ; ............. ............................. ~ .............. · ............................... , ........ u.~...~ ............ ~ ................ ~ ............... i t:{' ::!'{ !, i :.. ::':":": : ........... :'":'": .... : ........ :":;::.:::': :: i ..:::::: ':'":' :;' .:y: :"i'"::: ~. :: : ..... :":"::: :-:':'-~-':":y-.: .... :.::.:! : ..... :-: .... ................... : ..... :-, ............. : ................. t ................... ? ............ ?.~.., ......................... T ........................... ~ , ................. ~Z~nnt12.`-/-;ZZ./."Z;~L`-Z;~;;;Z-~..`-;;;~`-~;;.;-;~/-~L~.Z-;LZZ..J.;~..Z;.;L~;...;~y.Z;;;..]-;;;~...:-;;~.;~L- ;;.; '. !.. !; .;.; -; ;; .;-.-;. [ ;; '.' i ~'; ;'; ; ! ' ;; '' ;"; ;';.; ..... ;.]"t ;;..; ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::..; '.u';'; ';...;... :::::::::::::::::::::::::.;.;.z"'; ............ CO00 97. 0 Z -q PROdECTION ON VERTICAL PLANE 97.- 277. SCALED IN VERTICAL OEP'J'HS HORIZ S,.CA~E~ =: 1/10rlo__ I~l';--'r,.. , Standard Alaska Production Company~ 900 Eost Benson Boul~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION JUL 2, 1987 William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 magnetic tape and listing for: P-38 Run 1 -"~'* LIS (updated)~L~~,e,¢~e~ 1 sepia print and 1 blueline print for: //~~- - P-38 Run 1 June 23, 1987 -" * CBT ~ * CET RECEIVED AUG ~ i l~S7 Received b~aska Oil & Gas Cons. Commisslo. Anchorage Sincerely, Bruce St. Pierre Date A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870 Standard Alaska Production Cornpan,'~-'' 900 East Benson Bou, J P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION JUN 24, 1987 William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 magnetic tape and listing for: Run 1 June 18, 1987 * LIS Sincerely, Bruce St. Pierre A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870 Standard Alaska ~ Production Compan' 900 East Benson Boule~ .,rd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 JUL 13, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 sepia print and 1 blueline print for: P-38 Run 1 June 18, 1987 * BCS/GR * DLL/MSFL * SLD,,"CNS 1 Magnetic tape with listing for: Run 1 June 18, 1987 * ULTRA Bruce St. Pierre Received by Date A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALAg..A OIL AND GAS CONSERVATION COlt, .... SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown EX Re-enter suspended well UJ Alter casing Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order U] Perforate L'.] Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 4. Location of well at surface 2673' SNL, 628' WEL, Sec. 8, TllN, R17E At top of productive interval 3275' SNL, 2452' WEL, Sec. 9, TllN, R17E At effective depth At total depth 3387' SNL, 2224' WEL, Sec. 9, TllN, R17E 99519-6612 5. Datum elevation (DF or KB) 55.18 feet 6. Unit or Property name Duck Island Unit/Endicott 7. Well number 4-42/P-38 SDI 8. Permit number 87 -56 9. APl number 50--029-21731 10. Pool E~dicott Pool 11. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Size Structural Conductor 30" Surface 2435' 13-3/8" Intermediate 11012 ' 9-5/8" Production Liner 1042 ' 7" Perforation depth: measured true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Cemented Measured depth Structural Drive Pipe 4348 cu.ft. Permafrost 575 cu.ft. Class G 161' 2481' 11057' 375 cu. ft. Glass G RECEIVED 11839' True Vertical .depth 161' 2481' 9903' 10583' 12.Attachments Description summary of proposal []' Detailed operations program E] BOP sketch 13. Estimated date for commencing operation Auqust 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby, certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~.~. ~ Title Division Drillina Enaineer Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearance I NO. Approved by Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 1 Q1R~ Submit in triplicate WELL 4-42/P-38 (SDI) Permit Number: 87-56 Approval Date: 5-28-87 OPERATIONS Well operations will be shutdown after clean out to 7" float collar. Test 7" liner and lap to 3000 psi. Change over to NaC1 packer fluid. Nipple down BOPE. Install 4-1/16" tree on wellhead and release rig. Run CBT/CCL/GR, CET~ and gyroscopic survey from PBTD to surface and downsqueeze the 13-3/8" x 9-5/8" annulus with a non-freezing fluid once rig is off location. The well will be completed by moving a rig on location in mid-1987 and perforate well under balanced utilizing drill pipe conveyed guns. Flow well for simple clean-up. Kill well and complete with simple completion configuration using a 9-5/8" packer with 3-1/2" tailpipe run on 4-1/2" 12.6#/ft., L-80 TDS tubing with GLM's. A sub surface safety valve will be installed below base of permafrost. Install and test tree. Release rig. MAW/kb/1918D Rig: PAA #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT May 30, 1987 at 0600 hours AFE # 717534 APl: 50-029-21731 0600 Depths 500' Days -1 24-Hour Ftg: 339' Current Operation~ Drilling 17-1/2" hole. Accepted rig at 1800 Hfs 5-29-87. RU. Spud at 0200 Rra 5-30-87. TYPE-Spud mud WTs8.7 VISe220 PVs20 YPt41 FLsl2 Pick up bit and BHA. SOLIDSs3 TEMP:42'F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 164 2h :~ Rig~ PAA #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT May 31, 1987 at 0600 hours AFE # 717534 APl: 50-029-21731 0600 Depth= 2497' Day: 1 24-Hour Ftg: 1997' Current Operation:Circ. and condition hole. Drilling. TrAp for bit. Drilling. Short trip. Condition and circulate mud to run 13-3/8" casing. MUD TYPE-Spud mud WT:9.5 VLS:160 PV:10 YP:50 FLz23 SOLIDS:8 TEMP:61°F SURVEY ,MD ANGLE DIRECTION TVD ~ I 486 .5 S50W 486 2 946 0 0 946 3 1491 .25 N40E 1491 4 1947 0 0 1947 5 2482 1.0 N50E 2482 COORDINATES DLS 1642h:~F~ SAPC Daily Drilling Report -- ENDICOTT June 1, 1987 at 0600 hours Rig: PlA #7 Well: 4-42/P-38 (SDI) AFE # 717534 API: 50-029-21731 0600 Depth~ 2497' Days 2 24-Hour Ftg= ' Current Operation= Top Dob on 13-3/8" casing. Circulate and condition hole. POH. Rig up and run 13-3/8" casing. RIH and stab into FC with 5" DP. Cement 13-3/8" casing with 4500 sx. No cement returns to surface. POH with 5" DP. ND riser. Perform top Dob. MUD TYPE- WT: VIS= PV= YP= FL~ SOLIDS~ TEMP~°F ~ MD ANGLE DIRECTION TVD SECTION COORDINATE~ DLS 1644h:~ SAPC Daily Drilling Report -- ENDICOTT June 2, 1987 at 0600 hours Rig ~ PAA #7 Well: 4-42/P-38 (SDI) AFE # 717534 APl: 50-029-21731 0600 Depths 3880' Day: 3 24-Hour Ftg: 1383' Current Operations Drilling. Finish 13-3/8" top job. Nipple up and test BOP's. RIH. Test 13-3/8" casing. Drill cement. Run FIT - 12.5 ppg. Drilling. MUD TYPE-Ligno WT:9.3 VIS:52 PVs11 YP:14 FL:lT.4 SOLIDS:7 TEMP:71'F ~URVEY MD ANGLE DIRECTION _ TVD ~ COORDINATES DL~ 6 2776 .6 N41E 2775 4.07 N4.89 E4.74 .14 7 3156 .7 N78E 3156 7.42 N7.04 E8.39 .11 1644h: SAPC Daily Drilling Report -- ENDICOTT June 3, 1987 at 0600 hours Rig: PAA #7 Well: 4-42/P-38 (SDI) AFE # 717534 APl: 50-029-21731 0600 Depth: 5000' Day: 4 24-Hour Ftg: 1120' Current Operation: RIH with Dyna-Drill. Drilling. Trip for bit. Drill to 5000'. Trip for BHA change. MUD TYPE-Ligno WT~9.4 VIS:40 PV:ll YP:10 FL:9.3 SOLIDS:8 TEMP:76eF SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATE~ DLS 8 3536 .4 N34W 3536 8.20 N9.91 E9.55 .24 9 3906 .1 N41W 3906 7.06 Nll.19 E8.57 .08 10 4276 .5 SllE 4276 5.86 N10.57 E7.29 .16 11 4655 .3 S51E 4654 5.47 N8.34 E8.62 12 4951 .3 S22E 4950 8.54 NT.11 E9.53 1644h:~ SAPC Daily Drilling Report -- ENDICOTT June 4, 1987 at 0600 hours Rig: PAA #7 Well: 4-42/P-38 (SDI) AFE # 717534 APl: 50-029-21731 0600 Depths 5643' Day: 5 24-Hour Ftg: 643' Current Operation: Ream Dyna-Drill run. Kick off at 5000' and drill to 5643'. bottom. Trip for BHA. Ream to MUD TYPE-Ligno WT:9.5 VIS:36 PV:9 YP:6 FL:8.4 SOLIDS:9 TEMP:76°F SURVEy MD ANGL~ DIRECTION TVD SECTION COQRDINATE$ DLS 13 5094 3.9 S79E 5093 12.79 14 5195 6.4 S83E 5194 21.85 15 5290 8.8 S86E 5288 34.41 16 5383 10.8 S86E 5380 50.21 17 5477 13.5 S88E 5470 69.93 18 5572 14.9 S88E 5564 93.13 N4 N2.5 N2 N.19 S.85 S1.66 E13.5 E22 E35 E51 E70.5 E94 1644h:~ SAPC Daily Drilling Report -- ENDICOTT June 5, 1987 at 0600 hours Rigs PAA #7 Wells 4-42/P-38 (SDI) AFE # 717534 APIs 50-029-21731 0600 Depth= 7000' Days 6 24-Hour Ftg~ 1357' Current Operations Drilling 12-1/4" hole. Drill to 6545'. Trip for bit. Drilling. MUD TYPE-Ligno wT:g.7 VIS:40 PV:ll YP:7 FL:7.4 SOLIDS:10 TEMP:74'F SURVE~ MD ~ DIRECTION TVD SECTION COORDINATES 19 5694 18.2 East 5681 127 S2 E128 20 5789 20.1 S89E 5770 158 S2.5 E159 21 5884 21.3 S89E 5859 192 S3 E193 22 5979 23.7 S89E 5947 228 S3.4 E229 23 6080 26.1 S88E 6039 270 S5 E272 24 6173 28.5 S88E 6121 312 S6 E314 25 6269 30.6 S88E 6205 359 S8 E361 26 6363 32.8 S89E 6285 409 S10 E411 27 6457 36.3 S86E 6362 462 S13 E464 28 6635 40.9 S85E 6501 573 S22 E575 29 6732 41.1 S85E 6574 636 S27 E638 DL$ 2.74 2 .O3 1.26 2.53 2.41 2.58 2.19 2.41 3.77 2.21 .21 1644h: Rig: PAA #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT June 6, 1987 at 0600 hours AFE # 717534 APl: 50-029-21731 0600 Depth: 7775' Day: 7 24-Hour Ftg} 775'' Current Operation: Drilling 12-1/4" hole. Drill to 7282'; Trip for bit & BI{A; Drill to 7775' MUD TYPE-Lignosulfonate WT:9.6 VLS:41 PV:12 YP:IO FL:7 SOLIDS:9 TEMP:78"F SURVEY MD .AN. gLE DIRECTION TVD SECTION COORDINATES DLS 30 6832 41.5 S84E 6649 702 31 7020 41.6 S84E 6790 827 32 7213 43.6 S83E 6932 958 33 7397 43.1 SSOE 7066 1084 34 7581 42.3 S82E 7201 1209 S34 E704 .77 S47 E828 .05 S61 E958 1.09 S80 E1082 1.15 S100 E1206 .86 1642h: SAPC Daily Drilling Report -- ENDICOTT June 7, 1987 at 0600 hours Rig: PAA #7 Nell: 4-42/P-38 (SDI) AFg # 717534 APl: 50-029-21731 0600 Depth: 8250' Day: 8 24-Hour Ftg: 475'' Current Operation: Drilling 12-1/4" Hole. Drilled to 8082; Trip for BHA; Drill to 7775'. MUD TYPE-Lignosulfonate WT:9.7 VIS:40 PV:12 YP:ll FL:7 SOLIDS:II TEMP:°F SURVEY MD ,ANGLE DIRECTION TVD SECTION COORDINATES DLS 35 7778 41.2 S83E 7348 1340 Sl17 E1336 .65 36 7968 40.4 S83E 7492 1464 S132 E1459 .42 37 8143 39.4' S83E 7626 1576 S145 E1570 .57 1642h: Rig: PAA #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT June 8, 1987 at 0600 hours AFE # 717534 API: 50-029-21731 0600 Depth: 9000' Day: 9 24-Hour Ftg: 750'' Current Operation: Drilling 12-1/2" Hole. Drill to 9000'. MUD TYPE-Lignosulfonate WT:9.7 VIS:38 PV:11 YP:7 FL:7 SOLIDS:ii TEMP:°F SURVEY ~D, ANGLE DIRECTION TVD SECTIQN COORDINATES 38 8339 39.4 S84E 7778 1701 S160 E1694 39 8528 40.5 S84E 7923 1822 S172 E1815 40 8723 40.7 S86E 8071 1949 S183 E1941 DLS .32 .58 .68 1642h: Rig: PAA #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT June 9, 1987 at 0600 hours AFE # 717534 APl: 50-029-21731 0600 Depth: 9500' Day: 10 24-Hour Ftgl 500' Current Operation: POH. Drill and survey 12-1/4" hole to 9500 ft. POH. MUD TYPE-Ligno WT:9.8 VIS:39 PV=ll YP:9 FL:7 SOLIDS:10 TEMP:10Z°F SURVSY MI) ANGLE DIRECTION TVD SECTION 41 9008 39.9 S86E 8288 2133 42 9203 39 S83E 8437 2256 COORDINATES S196 S208 E2125 E2248 DLS .28 1.08 1644h: Rig: PAA #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT June 10, 1987 at 0600 hours AFE # 717534 API: 50-029-21731 0600 Depth: 9755' Day: 11 24-Hour Ftg: 255' Current Operation: Drilling. POH for BHA. Test BOPE. RIH. Drill and survey 12-1/4" hole to 9755 ft. MUD TYPE-Ligno WT:9 VIS:38 PV=ll YP:8 FL=6.6 SOLIDS=12 TEMP:g6°F SURVEY MD ANGLE DIRECTION ~ SECTION COORDINATES 43 9394 37.8 S81E 8588 2375 S225 E2366 44 9564 38.2 S82E 8723 2480 S240 E2470 DLS .90 .43 1644h: Rig: PkA #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT June 11, 1987 at 0600 hours AFE # 717534 API: 50-029-21731 0600 Depth: 10100' Day: 12 24-Hour Ftg: 345' Current Operation: Tripping. Drill and survey 12-1/4" hole to 10100 ft. POH. MUD TYPE-Ligno WT:10 VIS:39 PV:14 YP:ll FL:6.1 SOLIDS:il TEMP: 104°F ~URVEY MD ANGLE DIRE~TIQ~ TVl) SECTION COQRDINATES __ 45 9764 39.3 S82E 8879 2605 S258 E2594 46 9967 40.7 S81E 9034 2736 S277 E2723 DLS .55 .76 1644h: Rig: P~ #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT June 12, 1987 at 0600 hours AFE # 717534 APl= 50-029-21731 0600 Depths 10375' Day= 13 24-Hour Ftgs 275' Current 0peration: Drilling. Trip bit. Ream to bottom. Drill and survey 12-1/4" hole to 10375 ft. MUD TYPE-Ligno WT~10.3 VIS~38 PV~15 YP~10 FL,5.8 SOLIDS~12 TEMP:100°F SURVEY ~ ANGLE DIRECTION TVD SECTION COORDINATES 47 10134 40.3 S79E 9161 2844 S296 E2830 DL~ .81 1644h: Rig: PAA #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENI)ICOFT June 13, 1987 at 0600 hours AFE # 717534 API: 50-029-21731 0600 Depth: 11071' Day: 14 24-Hour Ftg: 696' Current Operation: Short trip. Drill and survey 12-1/4" hole to 11071 ft (TD). Short trip. MUD TYPE-Ligno WT:10.4 VIS:40 PV:16 YP:13 FL:5.7 SOLIDS:12 TEMP:105°F SURVEY MD ANGLE DIRECTIQN TVD SECTION COORDINATES 49 10520 38.7 S75E 9458 3090 S347 E3070 51 10898 34.7 STOE 9760 3314 S415 W3288 DLS 1.40 1.69 1644h: SAPC Daily Drilling Report -- ENDICOTT June 14, 1987 at 0600 hours Rig: PAA #7 Well: 4-42/P-38 (SDI) AFE # 717534 APl: 50-029-21731 0600 Depth: 11071' Day: 15 24-Hour Ftg: ' Current Operation: Install 9-5/8" pack-off. Short trip. CBU. POH. Run 9-5/8" casing. Mix and pump cement. Install pack-off. Shoe at 11056 ft. MUD TYPE-Ligno WT:IO.4 VIS:42 PV:17 YP:ll FL:5.6 SOLIDS:12 TEMP:eF SURVEY MD ANGLE DIRECTION Till) SECT!QN COQRDINATE~ DLS 1644h: Rig: PAA #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT June 15, 1987 at 0500 hours AFE # 717534 API: 50-029-21731 0600 Depth: 11220' Day: 16 24-Hour Ftg= 149' Current Operation: Drilling 8-1/2" hole. Install and test pack-off to 3000 psi. Test BOPE. P/U 8-1/2" BHA and RIH. Test casing to 3000 psi. Drill float equipment and 10 ft new hole. Conduct FIT to 13.5 ppg EMW. Drill 8-1/2" hole to 11220 ft. MUD TYPE-Ligno WT:9.9 VIS:42 PV:14 YP:10 FL:7.2 SOLIDS:9 TEMP:92°F SURVEY MD .,ANGLE DIRECTION TVD SECTION CQORDINATE$ DLS 1644h: SAPC Daily Drilling Report -- ENDICOTT June 16, 1987 at 0600 hours Rig: PAA #7 Well= 4-42/P-38 (SDI) AFE # 717534 API= 50-029-21731 0600 Depths 11500' Days 17 24-Hour Ftgs 280' Current Operations Drilling. Driil 8-1/2" hole to 11344 ft. Trip bit. Drill to 11500 ft. MUD TYPE-Ligno WTsg.9 VISs38 PV:14 YP:10 FL:6.8 SOLIDS:9 TEMP:94°F SURVE~ MD ANGLE DIRECTIQN TVD SECTION COORDINATE~ DL$ 1644h: Rig: PAl #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT June 17, 1987 at 0600 hours AFE # 717534 APl: 50-029-21731 0600 Depth: 11700' Day: 18 24-Hour Ftg: 200' Current Operation: Drilling. Drill 8-1/2" hole to 11681 ft. to 11700 ft with high torque. High torque. Trip bit. Drill MUD TYPE-Ligno WT:10.2 VIS:39 PV:14 YP:12 FL:5.8 SOLIDS:10 TEMP:99°F SURVEY MD ANGLE DIRECTION TVD SECTION C00RDINATE$ DL$ 1644h: Rig: PAA #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT June 18, 1987 at 0600 hours AFE # 717534 APl: 50-029-21731 0600 Depth: 11839' Day~ 19 24-Hour Ftg~ 139' Current Operation: Run open hole logs. Drill 8-1/2" hole to 11839 ft (TI)). Short trip. CBU. POH. Run open hole logs. MUD TYPE-Ligno WT:10.2 VIS:39 PV:13 YP:ll FL:5.4 SOLIDS=Il TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATE$ _ DLS 1644h: SAPC Daily Drillinq Report -- ENDICOTT June 19, 1987 at 0600 hours Rig: PAl. #7 Well: 4-42/P-38 (SDI) AFE # 717534 APl: 50-029-21731 Current Operations Run liner. 0600 Depthz 11839' Day~ 20 24-Hour Ftg: ' Run open hole logs. Wiper trip. Run 7" liner. MUD TYPE-Ligno WT~10.3 VIS:38 PV:14 YP=ll FL~5.6 SOLIDS:11 TEMP=104°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINAT~ DLS 1644h: SAPC Daily Drilling Report -- ENDICOTT June 20, 1987 at 0600 hours Rig: PAA #7 ~ell: 4-42/P-38 (SDI) AFE # 717534 API: 50-029-21731 0600 Depth: 11839' Day: 21 24-Hour Ftg: ' Current Operation: Waiting on cement. Run 7" liner (shoe at 11839 ft., hanger at 10807 ft.). Circulate. Mix and pump cement. Rotate and reciprocate liner while displacing cement. Set liner hanger. POH with tools. RIH with 8-1/2" cleanout assembly. Hit green cement. Wait on cement. MUD TYPE-Ligno WT:10.3 VIS:37 PV:ll YP:8 FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1644h: Rig: PAA #7 Well: 4-42/P-38 (SDI) SAPC Daily Drilling Report -- ENDICOTT June 21, 1987 at 0600 hours AFE # 717534 API: 50-029-21731 0600 Depth: 11839' Day: 22 24-Hour Ftg: ' Current Operation: Displace well to brine. WOC. Drill cement to hanger. Circulate. POH. RIH with 6" cleanout assembly to LC. Drill LC and cement to 11740 ft. Test liner and lap to 3000 psi - OK. Displace well to 9.6 brine. MUD TYPE-Brine WT:9.6 VIS: PV: YP: FL: SOLIDS: TEMP:°F SURV~ MD ANGLE DIRECTION TVD SECTION COORDINAT~ DLS 1644h: SAPC Daily Drilling Report -- ENDICOTT June 22, 1987 at 0600 hours Rig: PAA #7 Well: 4-42/P-38 (SDI) AFE # 717534 API: 50-029-21731 0600 Depth: Day: 23 24-Hour Ftg: ' 11740' Current Operation: Move rig to 3-49/J-40 Displace well to brine. POH. Run tubing hanger. N/D BOPE. Install adaptor flange and tree. Test tree. Release rig at 0600 hfs on 6/22/87. Move to 3-49/J-40. MUD TYPE-Brine WT:9.6 VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGbE DIRECTION TVD SECTION COORDINATES DL$ 1644h: May 28, 1987 Telecopy.' (907) 276-7542 Mr. R. S. Allan District Drilling Engineer Standard Alaska Production Company P.O. Box 196612 Anchorage, AK 99519-6612 Re: Duck Island Unit/Endicott 4-42/P-38 (SDI) Standard Alaska Production Company Permit No. 87-56 Sur. Loc. 267.3'SNL, 628'WEL, Sec. 8, TllN, R]7E, UM. Btmhole Loc. 3185'SNL, 2066'WEL, Sec. 9, TI]N, RI7E, UM. Dear Mr. Allan: Enclosed is the approved apPlication for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern- mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission?may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatt~erton Chairman Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION jo Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of'Environmental Conservation w/o encl. Mr. Doug L. Lowery ,--, STATE OF ALASKA ALASKA iL AND GAS CONSERVATION C,..,vlMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill [] Redrill E]I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenE]I Service [] Developement Gas [] Single Zone L] Multiple Zone II 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company 56 feet Endicott Field 3. Address 6. Property Designation Endicott Oil Pool P.O. Box 196612~ Anchorage~ Alaska 99519- /~DT, 4. Location of well at surface 6612 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025> 2673' SNL, 628' WEL SEC 8, TllN, R17E Duck Island Unit/Endico':t _At.top of prodLtcti,ve interval ,., CJ~C, Cfu-'i,'~-''' 5-/~-~/¢'t) 8. Well number Number 31,ca~;j.,SNL ~'° WEL SEC '~, TilN, R17E ~,42/P~38' (SDI) KOO683449-G-14 At,total depth ~6 ¢ ~ %_ 9. Approximate spud date Amount ~¢8~ SNL o~ WEL SEC..J, TllN, R17E May 30, 1987 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in prOperty 15. Proposed depth (MD and TVD> property line Surface 11879' ~ ADL ~7503 2575 feet M-35 130 feet 2560 10566' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 5000 feet Maximum hole angle 40 0 Maximum surface 3900 psi~ At total depth(TVD) 9855 4840p~¢ 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Str~ctura] Driv,~ Pipe Surfac~ 161' 161' Drive 17~" 13-3/8" 68# L-80 Butt. 2444 Surfacm 2500 2500 2700 cu. ft. Permafro~, 12¼" 9-5/8" 47# NT80S NSCC 9158 Surfac~ 9214 8500 320 cu. ft. Permafros! 12¼" 9-5/8" 47# NT95H:; NSCC 1762' 9214' 8500' 10976 9866 525 cu. ft. Class G 8~" 7" 29# SM-ill) Butt. 1153' 10726' 9672' 11879' 10566 420 cu. ft. Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Liner Perforation depth: measured .¢~las~a 0i[ & O;~$ ;'"'" "' ~"' ~o~i Anchorage true vertical 20. Attachments Filing fee ~; Property plat [] BOP Sketch [] DiverterSketch [] Drilling program [] Drilling fluid program ~]' Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Commission Use Only ----' I APl number I Appro~)a.~ date .~d~.. See cover letter Permit N u mbej- -~'-/. ~ ?,~'--'?~; 50- o 5~,~ -0-;,~ ' '7 ~/ /28/87 for other requirements Conditions of approval Samples required [] Yes '1~ No Mud Icg required L-q Yes No ,/ . Hydrogen sulfide measures [] Yes [] No Directional survey required ~Yes [] No R equiredworki~orB~7; ~5M; [] 10M; ~ 15M Other: by order of Approved by ~ .. ,../ , Commissioner the commission Date Form 10-401 Rev. 12-1-85 ~ / ~ Su ate PROPOSED DRILLING AND COMPLETION PROGRAM WELL 4-42/P-38 Objective Well P-38 will be drilled as an oil production well. Zones 3B & 3C are the primary objectives. The deferred completion will be run in mid- 1987. Operation Execute a rig move from slot 4-6 to slot 4-42 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. and cement 13-3/8" 68#/ft., L-80 Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4840 psi at 9855 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 5000 ft. then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe and 5 ft. new hole and conduct a formation leak-off test. Drill 8-1/2" hole to TD. Run open hole logs. Run and cement 7" 29#/ft, SM-Il0 TKC liner to TD with approximately 250 ft. of lap in the 9-5/8" casing. Clean out to float collar. Test casing and lap to 3000 psi. Change over to NaC1 packer fluid. Nipple down BOPE. Install tree on wellhead and release rig. Run CET, CBT/VDL/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface and downsqueeze the 13-3/8" x 9-5/8" annulus with Permafrost cement followed by a non-freezing fluid once rig is off location. Move rig on location in mid-1987 and perforate well under balanced using guns run on drill pipe. Flow well for simple clean-up. Kill well and complete with a simple completion. A sub surface safety valve will be installed below base of permafrost. Install and test tree. · Release rig. ENDICOTT PROPOSED DIAGRAM WELL 4-42/P-:~8 ($DI) m . TVD (BKB) MD (BKB) 30" DRIVE PIPE ,,.. ,~ ~ ~,i~'.. · 161 FT 161 FT 1600 FT 1600 FT (ESTIMATED 2000 FT) 13-3/8" 68#/FT L-80 BUTT 2500 F-I' 25OO F'r BoI-rOM OF DOWN SQUFFTFCEMENT (ESTIMATED 3000 FT) KOP ( DIR: S 82.6 E; ANGLE: 40 DEG ) 5000 FT 4-1/2", 12.6#/FT L-80 TDS TUBING W/3-1/2" TAILPIPE 9-5/8" 47#/FT NT80S NSCC 8500'FT 9214 FT TOP OF 9-5/8' CEMENT (ESTIMATED 9296 FT) 7' LINER TOP 9672 FT 10726 FT 9-5/8' 47#/FT NT95HS NSCC 9866 FT 10976 FT PLUG BACK TD 7- 29#/FT SM 110 BUTT LINER w/TKC COUPLINGS 10566 FT 11799 FT 11879 FT IRR/5-13-87 B.O.P. STACK CONFIGURATION 13-5/8 IN. TRIPLE RAM STACK 5000 PSI WP DRILLING ,I 1 ANNULAR PREVENTER I' I I I PIPE RAMS I I t I I I BLIND RAMS 2 lNG KILL LINE J GATE: GATE J, ,, I ! DRILLING SPOOL J 4 IN. CHOKE LINE J GATE GATE i I PIPE RAMS I W c~N~ ry ~f ,4 P PLAT OF PROPOSED WELL LOCATIONS MPI Wells Located In Sec.36, T. IZ N-,R.16E.,Umiat M. SDI Wells Located In Soc. 8~T.IIN.,R.17E.,Um'~.at M. PREPARED FOR SOHIO ALASKA PETROLEUM CO. DATE: NOV. 13, 1(3385 SCALE: I"'1 MILE DRAWN BY: R,G:r. CHECKED'flY ' DRW NO. 116- 85 SHEET I of I0 REV. 0 , , ,, , PREPAR ED 8Y F.R. BELL ~' A~SSO~C. PRUDHOE BAY OFFICE PRUOHOE BAY, ALASKA 00000 00000000 0000000000000 000~400000 t DRW.~vO. I;6-85 SHEET 7' of IO REV. O Indicltes C'.elculeted Secti®, Cer~er PLAT SDI PROPOSEo W~L LOCATIONs LOCATED IN IiC. I, T. Il ~.~ R. 17 E. UMIAT PREP&RED FOR SOHIo ALASKA P£TROLF. UM CO. F.R. BELL & ASSOC. PRUDNoE BAY OFFICE PRUDHoE BAY, ALASI SCALE' I". SO' IIII I III IL I II II II~ IIII I I llL I II Ii_Il II ~ ' _ Wl.I. ~ ZONE $ UTi, ,IN( & I. ATzTuDI[ I,.Oi :UK 'IBII~ ................ I Y- S970965.47 #- 7101170.15 70°19'20.2409' i47"51'49.2799' 2535.2! 171.05 X- 27.0163.10 E- 2 Y-~970796'40 N-7801819,4~ 70~"19'18.'~B42' i470'~1'48.610~" 2703.73 85~,60 X,, 270181.~37 E- 467547.32 .... 3 ¥' ~5970966.52 iN- 7{3O2{3?2.22 70:19'20.2542' i 147~52°4{3'.c;'90{3" ' 2533.93 i {3e~.~4 ' X- 270173.75 '= E- 467544.08 ' 4 i ! , ] , ~ ......... i Y' 5970797.44 N" 7801819.80 ' 70~'19 i8.5975", 147<51 48,3213" 2702.38 i 845.69 / X' .2.70191,~51_, E' 467550.34 2 5 ¥' 5970907.56 i N" 78011371.59 ~ 70c19'20.2675" } 147¢51'413.7016" 2532.5{3 {358.22 I i X- 270183.69 E- 467547. I I. l 6 ¥- ~970798.49 N- 7'~301820.17 70o19"113.6108, i47o51'48.0321" 2701.02 835.78 X- 270201.46 E- 467~}53.37 7 Y-"§970968.&0 N, 7~01871.95 '70¢19'20".2808''" 1474"51'48.4~24'"' '2551.23 B4EI.$I X- 270195.64 [- 4675~}0.15 I Y- 5970799~4 N- 7801~20.54 70o19'18.6240' 147~5'i."4~'.7429" 2699.67 X" 270211.41 i, 467~56.$9 9 Y' 5970969.&~ N" 7801B72'$2 70°19'20.2940" 147°~1'48.1252'"'' 2~29.87 158.40 X' 270203.~SI] E" 467~55.16 10 Y" ~70800.~8 N" 7801B20.9(~ '70°19'1B'.6375" 147~1'47.4~37" 2698.32 B1~.9~ X" 270221.$~ E' 467~59.42 11' Y""~970970.69 N" 7801872.&9 70~19'20.$075" 147°51'47.ii340" ' 2~28'.~2 ' 828.49 X' 270213.~$ E' 4671~6.18 12 Y- 5970801.6:~ N- 780'1821.27 70~'1~'18.6506" 147o51'47.164~" 2696.97 806.04 X- 270231.30 E" 467~62.44 13 Y' 5970971.74' N' 7801875.06 70~19'20.$206" 147~51'47.'~448" 2~27.17 818.~7 X" 27022.3.47, E" 467~S~9.21 14 Y- ~970802.67 N- 7B01821.64 70°19'18.6659" 147oS1'46."117~4' 269~'.62 796:"13 X' 270241.24 E' 467~6~.47 1~ Y' ~970972.79 N" 7B01873;43 '70o29'20.355B"'' 147°~1'47.25~6" 2~2~.82 B08.66 X" 27023;3.42 E' 467~62.25 16 Y' ~970803.72 N'-'7801822.01 70°'1~'18.~,771" 147°51'46.~862" ~6~4.27 786.21 X' 2702~S1.19 E' 467568;49 17 Y' ~970973.85 N' 7801873.80 70°19'20.3471"' ~47°~1.'46.96'64' 2524.47 798.7~ X' 270243.36 E' 46756~.26 18 Y' 5970804.76 N''7801822.38 70°~9'18.6904" 147°51'46.'2970"' 2692.91 776.30 _ X" 27026..1.13 E" 467~71.~2 19 Y- 5970974.88 N- 71101B74.16 '70°19'20'.3604" ~ 147°51'46.&772'~' 2523.'12 78i3;85 X- 270253.31 E- 467~68.28 20 Y' 5970805.81 N- 7801822.75 70°19'18.7037' 147051'46.0078'' 2691.~6 7&6.39 X' .270271.08 E,, 4&7574.54 21 Y- 5970975.92 N- 7B01174.55 70019'20.3736' 1~,7051'46.3iiB0' '~ 2521.76 771.92 X- 2702&$.2~ E- 4&7571.30 , ....... , I Ii~ iii III i I i i SDI PROPOSED WELL LOCATION UST 4,,'"~_'~'~'-~-%'~-'~C~'-z"~, -- ?~ LOCATED IN SEC." ,'T. IIN.,R.17E. UMIAT 4/.- I :: -' ';:./ ........... ............. Ii~',,?."L//-Z2,.2F'.,.~_e'I _'" F." BELL & &SSO C :e~,,~eeer.:qlLt) ~,,m SHE[?" of IO ' ' SCALE: N/A ~ 7o~s,~v':,~ PRU DHOE BAY OFFICE ...... ---- i i I ii i ii i iii i i i i i iii i ! iii i ii I II i iiii i i ii I III ~I IIIII II I I II II(LL dbld~"1011E' I uti 'j#E 6 LATITUDE L~ tUB( lilt~.. Illl~ , 2~' Y- 1~70106,15 N- 7101123,1~ 7~19'J1,7169' 14~11'4S,7116'~ 26~,11 7~,47 X- 270~81.02 [- 4~7577,_5~ 23 Y-5970976.97 N-7801874.90 70~19'20.3869' 147°51'46.09~9' 25~0.41 769.0z X- 270273.20 E- 467574.33 X- 270290.97 ~ E' 467~80,~9 X- 270300.9~ E- 467583,6t 27 Y- 59709'a2. t9 N- 7aOtB76.74 '70~9'20.45~3· 147o51'44;-&5-2~-" ........ 25't3';65 X- 270322,92 E- 467589,4~ 28 Y- S970B~3.~2 N- 7B0~82~.~2 "7~"9"~e.7966, ~47o~.4~.98'~, 2~1~.~0 ~ 197.00 X- 270~40,~9 E- 467~9~,7~ 29 Y~ ~97098~,.24 N- 7B0~877,~ 70~9~20,466~' ~47~5~'44,~&37' 2~2,~0 ~ 709,~ X- 270~2,87 E-. 467~92,48 30 Y- ~970824,~7 N~ 7B0~82~.69 70°~9'~8.1098' ~4~'43,&94~' X- 2703~0,64 E- 467~98,74 31 Y" 5970984,28 N" 7B01877,48 7~9'20,479B' 147°~'44,074~' 2510.9~ 699.62 X" 270342,B~ E" 467595,50 32 Y' 5970815,21 N" 7801826;06 70~i9'18,B231" 147~51'43.4052" ~2679,40 677. t7 X" 270360.se E- 467601,76 33 Y- 5970985,33 N- 7801877,85 70~19'20,49.31· 147~51'43,"70~3· 2509,60 689,71 X- 270~52.76 E- 467598.53 ,, 34 y- 59708~6.26 N- 7801826,43 70c19'18,8364· 147o51'43,1160· 2678.04 667,26 ~ X- 270370,53 E- 467604,79 35 Y" 5970986,37 N' 7801878,2'i 70°19;20 5063 147°5~ 43'4961' 2508.25 , · ' ~ 679,79 X" 270362,70 E" 46760~,55 36 Y' 59708~7.31 N" 7801826,80 70:19 ' ~8. 8496" 147~5~'42.B268" 2676.69?' 657,35- X" 270380.47 E" 467607,8~ 37 Y' 5970987,42 N" 7801870'.58 70c19'20,5196" 147°51'43,2069' 2506,19 669,18 X" 270372,65 Em 467604,58 4 , 38 Y" 59708~8,35 N" 7801827,~6 70~9'1B.8629" 147051'42.5376' ~ 2&75,34 647,43 X" 270390,42 E" 4676~0,84 39 Y" 5970988,46 N" 7101078,95 "70°19'20;5329' 147°51'42,9171' 2505'54 659,97 X" 270~82.59 E" 467607.60 40 Y" 59708~9.40 N" 7801827,53 70~19'IB.B762" 147° 51' 42. 2484~ 2673,-~9 637,52 X" 270400.36 E" 4676~3.86 41 Y' 5970989,5~ N" 7B01879,32 70°J9'20.546~" 147°5~'~42.6286" 2504.19 650.05 X" 270392,54 E" 4676~0,62 42 Y" 5970820,44 N" 7e01i27,90 70°i9'~1,1894" 1'4~'41,9592' 2672,64 627,61 X' 270410,31~ E- 4676t6,98~ .. ii i i i i i i I I i SDI ~~SED WELL L~ATION LIST ~.-~--.~,.m SOHIO ALASKA PETROLEUM CO F.R BELL · ,SSOC lb~..~~ SHEET ~ of IO · - SCALE' N/A ~V.~s~-~ . _ PRUDHOE BAY OF~CE DRAWN -~~~ REV. 0 PRUDHOE ~Y, ALASKA CHECK[O IY: i i i illl id I i ii i I ii i I i ii ?.. BI I III I II III I I III I I I II I I I I I I I ~ 43~Y, S970990,SI N; 710~17t,69 70°19'20','~594' 14~Sl'42,3394' 2SG2.14 iii, Ii ~ I- 27~402,49 l' 4i7i~T. iS 44 Tm S970i~,4' N~ 710~121.27 '70G'Ig"II.9027'' S47°Bl;'41.i7~ X- 270420.25 E- 4S"' Y- ~97'099Z.iO N- 7IOZBSO.O& ~0~9'20.~72'7· l'47~1'42.05'02· 250~.49 630.23 ~ X- 2704Z2.4~ E- 4676Z6.67 ' 46 Y- ~970822.~ 'N- 780~828'"64 70~9'28 9260' ~ . . i Z47~2'4~.3G09~ 2669.93 607.78 ~ ~ X- 270430.20 [- 467622.93 ~~ '. ~ 47 ~yi ~970992.6~ N' 7802880.42 70~9"20.~86'0' ~ 247e~'"4~.76'20'' 2~00.'~4 X- 270422.38 E- 4676~9.70 48 Y- ~970823.~8 N--7gO~829.0Z~ 70~i9'18.9292' ~' X- 270440. A5 E' 467625.96 49 Y' 5970993.69~ Nm 7101180.79 7'0019'20.~992' J47°~'4~.47~1' 249B.71 610,40 Z~ 270432.32 E' 467622.72 SO Y- ~970824.62 N- 7801829.37 70~19'1B.942~' 147~1'40'.B02~' 2667.23 ~87'96 X' 2704~0..09 E~, 467628.9B .... [ .... I ~ I I i I i I SDI OPOSED WELL LOCATION LIST ...... , ........... ~-~. ~11~ .~ 0RW. NO. 116-85 P~EPARED BY DATE' NV. 13, Ill5 ~~SSl~~__~ SHEET ~ of IO · SCALE ' N/A ~Sss~~ PRUDHOE BAY OFFICE ...... ' ~AWN IV' R.G.T, ReV. O PRUDHOE BAY, ALASKA II III III I III II I I I II I I II I I II I I ENDICOTT DEVELOPMENT WEI,,I., 4-42/P-38 (SDI) SLOT 4-42 SURFACE LOCATION X -- 270,410 FT ; Y = 5,970,820 FT 2673 FT SNL; 628 FT WEL $EC8, T11N, R17E TRUE NORTH GRID S82° 36' E DEPARTURE TO BHL: 3870 FT 11879 FT MD 10566 FT TVD BKB DEPARTURE TO TARGET: 3473 FT 11250 FT M D 10079 FT TVD BKB NOTE: THE NEAREST WELL TO P-38 IS M-35 LOCATED 130 FT WEST AT SLOT 4-20 IRR/4-9-87 --. /,, · Close.(. Ap~roac~ A n a i q s i s Dat~ aO-MAY-87 Time OS 3! 09 All depths in ¢oet Below Kellg Bushing WELL I DENT Closest Approach Vewtical Intersection /PROPOSED\ /NEARBY\ CLOSEST /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART DISTANCE TVD DEPART TVD DEPART VERTICAL DISTANCE 999999999 51~32 Aooo-ooooo25 SI -25 A000-0000026 o1-26 A000-0000028 SI -28 A000-0000049 SI -49 A _ ~9-~.0~8000 SI-DI 1 A0~9-202800 I [31 Di2 A029-21 56900 SI -~35 Ar'~'~°-~~.~_. ~_~ 58600 51 -M33 AC, 29--21 -',~400 '~ I -029 /,u~...~--~ 164000 31 -T34 A029--216400 ], ~: ~ -'-MB 5 "¢"'-'~--2154500 ',n"o ~* 66800 ,xJ~.?~-2 ! e. 7800 ,,", .;) ? q'-- 216 U' 20 0 ,':,'-';:'5 .... 2170 !00 , ': · - L.. :~ O. 0 O. 0 O. 0 O. 0 210. 2 O, 0 O. 0 O, 0 O. 0 202. 7 0.0 0.0 0.0 0.0 109.6 0.0 0.0 0.0 0.0 69.4 0.0 0.0 0.0 0.0 175.4 5998. 7 229. 6 6170. 1 1630. 9 528. 9 5555 7 200 6 2700 9 2 7 9'7 4 4801 3 68. 9 5315, 8 1920. 8 948. 8 -, O. 0 200. 0 O. 1 173. 3 O. 0 ,:o'~g: 14. 4 174, 5 .... 7s. 8 ].9/. l C; o a797 2 "' -" 0 0 4799.4 42. 9 99. 0 O. 0 3099. '7 14. 3 125. 6 . . "4 '-' . '"' 205. ~' 1300. 5 0 0 i,_0.,.;. 0 3 ,=: ,=. 800.6 0.0 800.0 1.7 173.4 '" "'::00 O "~ ,5 i 500. e, , '.. 0 I ........... (>. (7 1300. 0 S. 4 199 9 (Dummy slot) ,-' ¢0,=.. 9 - 1 a ,' O. ~ 7217. 6 1142. 2 5619. 7 '"'-' ~ = 6799. 7 801. 8 9856. 4 815. 6 3057. 4 wh i c h ~.: o'fi'ii::; ~.:. 'c".i o s e ,=: t t c, Search Radius= 1000 For proposed well' P-38 COURSE LINE [32- 9-11-I 7] 20-MAY-87 Time' 08'29'37 Tc, p 270410 O0 5970820. Bottom 274228. i4 5970190. Note' All depths in ~eet Belom Kellg Bushing (2KB) WELL. IDENT Closest Approach /PROPOSED\ TVD DEPART TVD /NEARBY\ DEPART CLOSEST DISTANCE Vertical /PROPOSED\ .TVD DEPART Intersection /NEARBY\ VERTICAL TVD DEPART DISTANCE 999999999 SI~32 A000-0000025 SI -25 A000-0000086 SI -26 A000-0000028 SI -28 AO00-O00004,~ S I - 49. ;.?.:. :~'¥ ' . . A029-2028000 SI-DI I A029-2028001 SI-DI2 A029-21 56900 SI-~35 A029-2158600 S I -M33 A029-2 ! 62400 51-029 A029-~ 164000 SI -T34 A029-~ 164001 Cl-M35~, ..... 9-~_ t 64 500 SI -N32 A029--2166800 ~I-K37¢ An° qi67800 SI -N29 A"]29--'~ 169200 S! -P27 A029-2 ! 70100 SI -L36 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0,0 0.0 0.0 0.0 0.0 .,. '-, :-~ (y.. . 6005.'.8 233. 1 6161. 0 5623. 9 200. 6 2700.9 2797.4 4801.3 rolO1 6 1300. 5 800. 6 1500. 6 1300. 7 1000.6 O. '0 210, 2 202. 7 109. 6 69. 4 (Pt~mm_ ~y slot) . . 1'75. 4 1624. I 513. 1 87. 1 5336. 6 1943. 8 946. 1 .. · . O. 0 200. 0 '0'.~'1 173. 3 0.0 2699.9 O. 0 2797.2 77. 8 197. I O. 0 4799.4 42.9 99.0 O. 0 3099.7 14_ 3 125. 6 3. 2 205. 2 1.7 173. 4 2. 5 284. 8_4 199.9 0.0 1.300.0 O. 0 800. 0 O. 0 i 500. 0 0.0 t300.0 0.0 1000.0 4, 3 172.6 The '~,el i which comes c J osest to ~'-he- AO00---O00 O0'-;°=. ,¢ '=,., i --- T34 pT'c',i,)c:sed me!' is' POOl_ ARCTIC ALASKA RIG NO. 7 Mud Tank/Trip Tank Monitoring-Recording TOTCO, PITOMETER UNIT L-8 (PNEUMATIC) DRILLING RECORDER' SYSTEM TOTCO, MODEL DR8WPT (E) RS (2) F DRILLER'S CONSOLE TOTCO "COMMAND ENDICOTT MUD PROGRAM SATELLITE DRILLING ISLAND WELL 4-42/P-38 Interval Mud Weight Viscosity Lggg)_ (sec/qt) Fluid Loss (ml/30min) pH 0-2500 8.8-9.8 100-200 20-15 2,500- 10,976 10,976- 11,879 Mud Type/ Components 8.5-9.0 Generic Mud #5 Seawater Fresh water Gel Soda Ash Set 13-3/8" casing 9.2-10.2 40-45 15-16 9.5-10..0 Generic Mud #7 Set 9-5/8" casing Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite 9.6-10.2 4045 6-8 9.0-10..0 Generic Mud #7 Hang 7" Liner Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite POOL ARCTIC ALASKA RIG NO. 7 MUD AND SOLIDS CONTROL EQUIPMENT Equipment Manufacturer Model Nominal Capacity Shaker Brandt Dual Double 1000 gpm Desanders Tri Flow/Pioneer Mann-Design 2 each - TFI-126 screens 4 each - Pioneer 12" Economaster Cones 1000 gpm (each) Mudcleaners Brandt Double 8 each - 4" Cones 400 gpm (each) Centrifuge Oiltools Decanting, Type S-3-0 160 gpm Degasser SWACO Vacuum 1000 gpm Agitators Brandt 7 each - 5 h.p., 32" Impellers Hoppers Geosource 2 each - 1000 gpm S-800 Sidewinders The trip tank and mud tank sections each have one vertical pit level float indicator which are connected to the drilling recorder system that contains visual and audio warning devices located in the driller's console. MISC44:00027 ---] -,.- 9 il L~V~L ~- PIT~ I~TION ONLY ;~o ee, L. t t PIT i UP I1 FOR INFORMATION ONLY TESTING THE B.O.P. STACK WITH THE 13-1/8" x 4%" IF BOX X BOX, (THRU-BORE) , TEST PLUG (FIG. 7) 1.) Make up the 13-1/8" x 4½" IF test plug to a stand of drill pipe. (Illustration 9) NOTE: Sometimes it is helpful to make a stand of heavy wall up to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the lest plug through the B.O.P. stack until it lands on the low6r load shoulder of the. split unihead unit. 3.) Run in at least two of the lower set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if need to energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/8" X 4-1/2" IF BOX X BOX (THRU-BORE) TEST PLUG TI-IlS END UP L FMC P.N. 48-261-082 REQ'D PART NO. DESCRIPTION 1 48-261-268 Test Plug 1 48-261-083 Body , , 1 48-261-673 Compression Ring 4 79-040-074 Set Screws 1 48-081-529 Packing ,, , - , 1 51-092-001 2" Ball Check Figure #7 (Part number 48-261-082 continued on next page) FMC P.N. 48-261-082 continued REQ'D. PART NO. DESCRIPTION 1 19-505-663 Coil Spring 1 25-411-356 Retaining Plate 1 25-411-357 Circ.-O-Lox Ring 2 48-180-027 Pipe Plug ., 1 52-304-013 Drlg. Pipe Sub. ILLUSTRATION 9 B.O.P. STACK 3-5/8" 5000 WP 3-5/8" 3000 WP TESTING THE B.O.P. STACK WIT}{ THE 13½" X 4½" IF BOX X BOX, (UPPER) , TEST PLUG (FIG. 19) 1.) Make up the 13½" x 4%" IF test plug (upper) to a stand of drill pipe. (Illustration 13) NOTE: Sometimes it is helpful to make a stand of heavy wall 6p to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the split unihead unit. 3.) Run in at least two of the upper set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if you need to · energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/2" X 4-1/2" IF BOX X BOX (UPPER) TEST PLUG S END UP FMC P.N. 49-261-068 ~EQ'D PART NO. DESCRIPTION ,, 1 48-261-067 Body 1 48-261-671 Compression Ring 4 79-040-074 Set Screw 1 82-741-117 Packing 1 51-092-001 2" Ball Check ,. 1 19-505-663 Coil Spring 1 25-411-356 Retaining Plate ,.. 1 25-411-357 Circ.-O-Lox Ring 2 48-180-027 Pipe Plug Figure #19 ILLUSTRATION# 13 STACK ~'13-5/8" 5000 WP 13-5/8" 3000 WP TESTING THE B.O.P. STACK WIT}{ THE 10" X 4-1/2" IF BOX X BOX (COMBINATION) , TEST PLUG (FIG. 22A) 1.) Make up the 10" x 4%" IF test plug (combination) to a stand of drill pipe. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the tubing/casing head. 3.) Rin in at least two of the upper set of lockdown screws 180" opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. 4.) Test the B.O.P. stack. 5.) Back out all the lockdown scres which have been run in. 6.) Remove the test plug. 10" CO.~4BINATION 'rEST PLUG AND BOWL PROTECTOR RUNN I NG / RETR ~. EV I NG TOOL THIS END UP FMC PART NO. 48-261-503 REQ'D. PART NO. DESCRIPTION 1 48-261-504 BODY --. 1 48-085-833 BELT PACKING 1 48-180-025 PLUG, 1¼ L.P. -- , ,, ·.. 1 48-180-025 .... PLUG, 1¼ L.P. 4 ~ 48-180-015 PLUG, ½ L.P. 1 48-010-009 WRENCH (Figure #22A) STACK 5000 WP 13-5/8" 3000 -"- B.O.P. STACK _ 11" 5000 WP 13-5/8" 3000 WP ^ ~/ CHECK LIST FOR NEW W~.~. PERMITS (1) Fee f--~ o7 ? 1. (2) Loc z~f 7-2~7 (2a=u 8) (3) ~-- ~V-~7 9. (9 thru 13) 10. 13. (4) Casg ~,~ C-~-S? (14 thru 22) ('5) BOPE .... (23 tbzu 28) (6) OTHER (29 ~th~'31)' (6) Add: , , Geology: ': 01/28/87 '1 Is the permit fee attached REMARKS -- 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance frcm property line .................. ~ 4. Is well located proper distance from other wells .................... ~ 5. Is sufficient undedicated acreage available in this pool ............ '~ 6. Is well to be deviated and is wellbore plat included ................ ~ 7. Is operator the only affected party ................................. 8. Can penmit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needad ...................................... IS admdnistrative approval-needed ................................... IS the lease r~ber appropriate ............... Does the well have a unique name ~l'g'~-'.[..:... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. IS conductor string provided ........................................ Will surface casing protect fresh water zones ....................... IS enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............ Is old wellbore abandomrmmt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required Is the drilling fluid program sch~tic and list of equipment adequate Are necessary diagr~m~ and descriptions of ~ Does BOPE have sufficient pressure ratinE - Test to ~ psig Does the choke ~4*old comply w/API RP-53 fMay 84) ................ Is the presence of H25 gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32 Additional requirements . · ee®®eeeeee®eeeeeeeee®®eeeee eeee®e®eeee®eee®ee INiTiAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA. NO. SHORE ,,, '7o OU , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. 4- 42 / P- 38 ENDICOTT Run 1: 08 - FEB - 1996 PDK-1001GR Cased Hole WESTERN ATLAS Logging Services 11100 11729 Tape Subfile 2 is type: LIS TAPE HEADER ENDICOTT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSH I P: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 4 - 42 / P - 38 500292173100 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 20-FEB-96 5945.02 D. BARBA J. POWERS 8 liN 17E 2673 628 55.20 54.20 14.50 OPEN HOLE CAS ING DRILLERS CAS ING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 9.625 11057.0 3RD STRING 7.000 11839.0 PRODUCTION STRING 4.500 10871.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 1 18-JUN-87 GEARHART BASELINE DEPTH 11101.5 11118.5 11131.5 11144.0 11154.5 11165.0 11168.0 11173.0 11174.0 11175.0 11176.0 11176.5 11177.5 GRCH 11100.0 11117.5 11130.5 11144.0 11154.5 11164.0 11167.0 11171.5 11172.0 11172.5 11173.0 11173.5 11174.0 EQUIVALENT UNSHIFTED DEPTH 47.00 29.00 12.60 lilSo.o 11205.5 11208.5 11210.0 11216.0 11242.0 11244.5 11245.0 11247.5 11248.0 11255.0 11255.5 11256.0 11257.0 11257.5 '11264.0 11274.0 11274.5 11281.0 11306.5 11309.5 11334.5 11338.5 11339.5 11341.0 11343.5 11344.5 11349.5 11350.5 11358.5 11359.0 11366.5 11367.0 11369.0 11370.0 11378.0 11378.5 11383.5 11384.5 11385.0 11385.5 11386.0 11399.5 11400.0 11402.0 11411.5 11417.0 11418.0 11419.0 11426.0 11427.0 11428.5 11429.5 11443.0 11449.0 11459.0 11460.0 11462.5 11464.5 11465.0 11176.5 11202.5 11205.5 11206.5 11212.5 11239.5 11242.0 11243.0 11245.5 11246.5 11253.5 11254.5 11255.0 11255.5 11256.0 11261.5 11271.5 11272.5 11279.0 11305.0 11308.0 11334.0 11338.0 11338.5 11339.5 11342.0 11342.5 11347.5 11348.0 11356.0 11357.0 11364.5 11365.5 11367.5 11368.0 11376.0 11377.0 11382.0 11382.5 11383.0 11384.0 11384.5 11400.5 11401.0 11403.5 11413.0 11419.5 11420.5 11421.0 11428.0 11428.5 11430.0 11430.5 11444.0 11449.0 11459.0 11459.5 11462.0 11464.5 11465.0 11465.5 11466.0 11474.5 11475.0 11476.0 11477.5 11478.0 11486.5 11487.0 11494.0 11498.0 11504.5 11508.0 11508.5 11509.5 11512.5 11513.0 11513.5 11518.5 11519.0 11520.0 11521.0 11524.5 11544.5 11560.5 11565.0 11570.0 11589.0 11590.0 11598.5 11602.5 11603.0 11604.0 11617.0 11618.5 11621.0 11623.0 11626.0 11626.5 11631.5 11632.0 11641.0 11641.5 11651.0 11655.5 11656.0 11657.0 11657.5 11658.5 11664.5 11665.5 11666.5 11667.0 11668.0 11672.5 11678.0 11678.5 11679.5 11683.0 11687.5 11466.0 11466.5 11473.5 11474.0 11474.5 11476.0 11477.0 11485.5 11486.5 11493.5 11498.0 11504.5 11509.0 11509.5 11510.0 11513.0 11513.5 11514.0 11519.0 11520.0 11521.0 11521.5 11525.5 11546.0 11562.5 11566.0 11571.0 11590.0 11590.5 11599.0 11602.5 11603.0 11604.5 11617.5 11619.5 11622.0 11623.5 11626.5 11627.5 11632.5 11633.5 11642.5 11643.5 ,11653.0 11659.0 11659.5 11660.0 11660.5 11661.0 11667.0 11667.5 11668.0 11668.5 11669.0 11673.5 11679.5 11680.0 11680.5 11684.0 11688.0 11689.0 11690.0 11692.5 11693.0 $ REMARKS: 11689.5 11690.0 11692.5 11693.0 PDK-100/GR. LOG TIED INTO CET RUN 23-JUN-87. LOGGING PROGRAM'ORGANIZATION: 1. LOGGED 3 PASSES WITH WELL FLOWING. WELL TEST SUMMARY TEST DATE ELAPSED TIME 19-JAN-96 HOURS 4.0 GROSS FLUID RATE NET OIL RATE NET WATER RATE FORMATION GAS RATE GOR MBPD 4. 942 MBOPD 0.692 MBWPD - MMSCFD - SCF/STB 682 LIFT GAS RATE MMSCFD 3. 291 CASING PRESSURE PSIG - TGOR SCF/STB - TGLR SCF/BBL 95.51 CHOKE OPENING 176 MANIFOLD PRESSURE PSIG 359 MANIFOLD TEMPERATURE DEGF 181 WATER CUT (CALC) PCNT 86 A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR ALL THREE FLOWING PASSES. THE CURVE IS NAMED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8" CASING SIZE = 7" SALINITY = 25,000 PPM A PDK POROSITY CURVE (PHI) WAS ALSO CREATED FOR ALL THREE FLOWING PASSES. SHIFT PROCEDURE AS FOLLOWS: 1. FIRST PASS GAMMA RAY DEPTH MATCHED TO PREVIOUS OPEN HOLE GAMMA RAY. 2. FIRST PASS SGMA DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3. ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4. ALL SUBSEQUENT SGMA (PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SGMA. /??MATCH1A.OUT FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 11028.0 · PDK 11040.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH SGMA 11113.5 11112.5 11114.0 11113.0 11131.5 11129.5 11135.0 11133.0 11153.0 11153.0 11154.5 11154.5 11190.0 11187.5 11209.5 11207.0 11210.0 11208.0 11211.0 11209.0 11212.0 11209.5 11221.0 11218.5 11226.5 11223.5 11234.5 11231.5 11235.5 11232.0 11242.0 11239.5 11242.5 11240.0 11243.5 11240.5 11244.0 11241.5 11244.5 11242.0 11246.5 11244.5 11247.5 11245.5 11248.0 11246.5 11252.0 11251.0 11281.0 11280.0 11306.5 11305.5 11354.5 11353.0 11356.5 11354.5 11361.5 11358.5 11362.0 11359.0 11363.0 11359.5 11363.5 11360.0 11364.0 11361.0 11366.5 11363.5 11367.0 11364.5 11367.5 11365.5 11370.0 11368.0 11384.0 11383.0 11386.0 11385.0 for each pass in separate files. STOP DEPTH 11717.0 11729.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH 11387.0 11400.5 11403.5 11412.0 11412.5 11413.0 11413.5 11425.0 11425.5 11426.5 11427.0 11428.0 11428.5 11429.5 11431.5 11436.5 11482.5 11483.5 11485.0 11504.5 11507.5 11508.0 11508.5 11509.5 11512.5 11513.0 11513.5 11524.5 11544.5 11560.5 11565.0 11570.0 11589.0 11590.0 11606.0 11610.5 11611.0 11611.5 11614.5 11615.5 11616.0 11625.0 11634.5 11635.0 11637.0 11638.0 11641.5 11642.0 11642.5 11643.0 11648.5 11649.0 11651.0 11666.0 11666.5 11667.5 11668.5 11671.5 11672.0 11673.5 11385.5 11400.5 11404.5 11413.0 11414.0 11414.5 11415.5 11428.0 11428.5 11429.0 11429.5 11430.0 11430.5 11431.0 11433.0 11438.0 11481.5 11482.5 11484.5 11504.0 11506.0 11509.0 11509.5 11510.0 11513.0 11513.5 11514.0 11525.5 11546.0 11562.5 11566.0 11571.0 11590.0 11590.5 11606.5 11611.0 11611.5 11612.0 11615.0 11615.5 11616.5 11626.0 11635.5 11636.5 11638.5 11639.0 11642.5 11643.5 11644.0 11645.0 11650.5 11651.5 11653.5 11667.5 11668.0 11668.5 11669.0 11672.0 11673.0 11674.5 11678.0 11678.5 11679.5 11680.5 11681.5 11687.5 11688.5 11692.0 11693.0 11695.0 11712.0 11712.5 11713.5 11716.5 11717.5 11720.0 11720.5 $ REMARKS: 11679.5 11680.0 11680.5 11681.5 11682.0 11688.0 11688.5 11692.0 11692.5 11694.5 11712.5 11713.0 11713.5 11716.5 11717.0 11719.5 11720.0 FLOWING PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN WN FN COUN STAT / ? ?MATCH1B. OUT $ : BP EXPLORATION : 4 - 42 / P - 38 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Name Tool Code Samples Units GRCH PDK 68 1 GAPI BIF PDK 68 1 BKL PDK 68 1 CPS BKS PDK 68 1 CPS CSLS PDK 68 1 CU LS PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 RBOR PDK 68 1 RICS PDK 68 1 RIN PDK 68 1 SGMA PDK 68 1 CU SGMB PDK 68 1 CU SS PDK 68 1 CPS SGNT PDK 68 1 CU API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 16 PHI PDK 68 1 PU-S 4 * DATA RECORD (TYPE# 0 ) Total Data Records: 101 958 BYTES * 4 51 995 99 1 64 Tape File Start Depth = 11025.000000 Tape File End Depth = 11730.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 23988 datums Tape Subfile: 2 490 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 11088.0 11100.0 STOP DEPTH 11717.0 11729.0 (MEASURED DE PTH) files. BASELINE DEPTH GRCH 11094.0 11092.5 11114.0 11113.0 11113.0 11115.0 11113.5 11113.5 11117.0 11115.5 11117.5 11115.0 11118.0 11116.0 11116.0 11120.0 11118.0 11118.0 11121.0 11118.5 11118.5 11121.5 11119.0 11119.0 11125.0 11122.0 11122.0 11126.0 11122.5 11122.5 11134.0 11131.5 11130.0 11142.5 11140.5 11144.0 11140..5 11144.5 11141.5 11151.0 11148.0 11151.5 11149.5 11152.0 11150.0 11153.0 11150.5 11156.0 11153.5 11166.0 11163.0 11169.0 11165.0 11171.0 11168.0 11172.0 11168.5 11179.0 11174.5 11195.5 11191.5 11203.5 11200.0 11200.0 11204.0 11201.0 11201.0 11205.5 11202.5 11202.5 11206.5 11203.0 11203.0 11207.5 11204.0 11204.0 11208.0 11205.0 11205.0 11220.5 11217.5 11217.5 11223.0 11219.5 11219.5 11223.5 11220.0 11220.0 11224.5 11221.5 11221.5 11226.5 11223.5 11223.5 EQUIVALENT UNSHIFTED DEPTH SGMA 11227.5 11234.5 11237.0 11243.0 11243.5 11252.0 11257.5 11258.5 11260.0 11260.5 11263.0 11264.0 11270.5 11275.0 11278.5 11285.0 11286.0 11286.5 11288.5 11289.5 11291.5 11292.0 11292.5 11293.5 11296.5 11301.0 11303.0 11304.0 11314.0 11314.5 11324.5 11325.0 11327.0 11328.0 11334.5 11335.5 11336.0 11336.5 11341.5 11342.5 11343.5 11344.0 11357.0 11358.5 11359.0 11360.0 11368.5 11369.0 11369.5 11391.0 11398.0 11398.5 11402.0 11412.0 11412.5 11415.0 11417.5 11420.0 11420.5 11423.0 11224.0 11231.0 11234.0 11240.0 11241.0 11249.0 11255.0 11255.5 11257.0 11258.0 11260.5 11261.0 11266.5 11271.5 11275.0 11282.0 11282.5 11283.5 11285.5 11286.0 11288.0 11289.0 11289.5 11290.0 11293.0 11299.0 11301.0 11301.5 11311.5 11312.5 11322.5 11323.5 11325.5 11326.0 11332.5 11333.0 11333.5 11334.0 11339.0 11339.5 11340.5 11341.5 11354.5 11355.5 11356.0 11356.5 11365.0 11366.0 11367.0 11388.5 11397.5 11398.0 11402.0 11412.0 11413.0 11415.5 11418.5 11421.0 11422.0 11424.5 11224.0 11231.0 11234.0 11240.0 11241.0 11255.0 11255.5 11257.0 11258.0 11260.5 11261.0 11282.0 11282.5 11283.5 11285.5 11286.0 11288.0 11289.0 11289.5 11290.0 11293.0 11299.0 11301.0 11301.5 11311.5 11312.5 11322.5 11323.5 11325.5 11326.0 11332.5 11333.0 11333.5 11334.0 11339.0 11339.5 11340.5 11341.5 11354.5 11355.5 11356.0 11356.5 11365.0 11366.0 11367.0 11388.5 11397.5 11398.0 11402.0 11412.0 11413.0 11415.5 11418.5 11421.0 11422.0 11424.5 11424.0 11426.0 11439.0 11439.5 11443.5 11444.5 11448.0 11449.0 11456.5 11472.5 11480.5 11481.5 11504.0 11505.5 11506.0 11509.5 11510.0 11513.5 11516.5 11532.0 11532.5 11543.5 11544.0 11545.5 11546.0 11558.5 11559.5 11564.0 11565.5 11566.0 11567.0 11567.5 11593.0 11594.0 11615.5 11616.0 11620.5 11621.0 11630.0 11630.5 11631.5 11632.0 11641.5 11642.0 11652.5 11653.5 11658.5 11659.5 11666.0 11668.0 11669.0 11674.5 11678.0 11678.5 11679.5 11687.5 11688.5 11692.0 11693.0 11702.0 11425.0 11426.0 11439.0 11440.0 11444.0 11444.5 11448.0 11448.5 11456.0 11471.0 11479.0 11479.5 11502.0 11504.0 11505.0 11508.5 11509.5 11513.0 11516.5 11532.0 11533.0 11544.0 11545.0 11546.5 11547.5 11560.0 11560.5 11565.0 11565.5 11566.0 11566.5 11567.0 11592.5 11593.0 11614.5 .11615.5 11620.0 11621.0 11630.0 11631.0 11632.0 11633.0 11642.5 11643.5 11654.0 11655.5 11660.5 11661.0 11667.5 11668.0 11668.5 11674.0 11678.0 11678.5 11679.0 11687.0 11687.5 11691.0 11691.5 11700.5 11425.0 11426.0 11439.0 11440.0 11444.0 11444.5 11448.0 11448.5 11456.0 11471.0 11479.0 11479.5 11502.0 11504.0 11505.0 11508.5 11509.5 11513.0 11516.5 11532.0 11533.0 11544.0 11545.0 11546.5 11547.5 11560.0 11560.5 11565.0 11565.5 11566.0 11566.5 11567.0 11592.5 11593.0 11614.5 11615.5 11620.0 11621.0 11630.0 11631.0 11632.0 11633.0 11642.5 11643.5 11654.0 11655.5 11660.5 11661.0 11667.5 11668.0 11668.5 11674.0 11678.0 11678.5 11679.0 11687.0 11687.5 11691.0 11691.5 11700.5 11712.5 11713.5 11714.5 11716.5 11717.5 11720.0 11720.5 $ REMARKS: 11712.0 11712.0 11713.0 11713.0 11713.5 11713.5 11715.5 11715.5 11716.0 11716.0 11718.5 11718.5 11719.0 11719.0 FLOWING PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT / ? ?MATCH2A. OUT / ? ?MATCH2B. OUT $ : BP EXPLORATION : 4 - 42 / P - 38 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name TooI Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 MSD PDK 68 1 CU 4 8 RATO PDK 68 1 4 9 RBOR PDK 68 1 4 10 RICS PDK 68 1 4 11 RIN PDK 68 1 4 12 SGMA PDK 68 1 CU 4 13 SGMB PDK 68 1 CU 4 14 SS PDK 68 1 CPS 4 15 SGNT PDK 68 1 CU 4 16 PHI PDK 68 1 PU-S 4 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 101 Tape File Start Depth = 11025.000000 Tape File End Depth = 11730.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 3 23988 datums 299 records... Minimum record length: Maximum record length: 62 bytes 958 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 11088.0 PDK 11100.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 11108.5 11116.5 11114.0 11117.5 11114.5 11118.5 11115.5 11133.5 11131.0 11134.5 11140.5 11142.5 11140.0 11143.5 11166.5 11167.5 11175.0 11180.0 11174.0 11190.0 11196.0 11198.0 11194.0 11204.0 11209.5 11204.5 11210.0 11205.5 11219.0 11220.0 11215.5 11228.5 11241.5 11237.5 11244.5 11240.5 11245.0 11245.5 11242.0 11248.5 11245.0 11249.5 11245.5 11251.5 11252.0 11248.0 11252.5 11249.0 11255.5 11252.0 11256.5 11252.5 11257.5 11253.5 11258.5 11262.5 11257.5 11263.0 for each pass in separate files. STOP DEPTH 11717.0 11729.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 11105.5 11130.5 11137.0 11140.0 11163.5 11164.0 11170.0 11185.5 11191.5 11200.0 11215.5 11224.5 11241.0 11242.0 11248.5 11254.5 11255.0 11260.0 11268.5 11278.0 11278.5 11279.0 11280.5 11281.5 11282.0 11282.5 11283.5 11284.0 11286.5 11301.0~ 11303.0 11307.5 11310.0 11313.0 11314.0 11315.0 11315.5 11320.5 11321.5 11324.5 11325.0 11328.0 11329.0 11332.0 11337.0 11338.0 11342.5 11343.5 11344.0 11348.0 11349.0 11350.5 11354.5 11357.5 11360.0 11360.5 11364.0 11365.0 11366.0 11367.5 11378.0 11379.0 11379.5 11385.5 11386.0 11393.5 11394.0 11397.5 11398.5 11402.0 11410.5 11412.0 11412.5 11413.0 11415.5 11416.0 11416.5 11417.0 11273.0 11274.0 11276.0 11276.5 11277.0 11278.0 11279.0 11280.0 11282.5 11299.5 11311.5 11312.5 11317.5 11318.0 11329.5 11334.5 11335.0 11339.5 11340.0 11344.5 11345.0 11356.0 11357.0 11361.5 11362.0 11374.0 11374.5 11375.0 11381.5 11382.0 11397.0 11409.0 11411.0 11414.5 11415.5 11416.0 11265.0 11275.5 11280.0 11298.0 11304.5 11307.0 11310.0 11310.5 11321.0 11322.0 11325.0 11325.5 11341.0 11347.5 11351.5 11354.5 11359.5 11364.5 11376.0 11390.5 11391.5 11395.0 11400.5 11410.5 11411.5 11412.5 11416.5 11417.5 11421.5 11422.0 11422.5 11423.5 11426.0 11427.0 11428.0 11428.5 11429.0 11431.5 11432.0 11432.5 11436.5 11445.0 11445.5 11446.5 11453.0 11454.0 11456.0 11456.5 11457.0 11460.5 11461.5 11462.0 11462.5 11466.5 11472.0 11474.0 11477.5 11478.0 11478.5 11480.5 11481.5 11483.0 '11484.5 11485.0 11486.0 11503.5 11504.5 11505.5 11508.5 11511.0 11512.0 11517.5 11522.5 11524.0 11525.0 11526.0 11526.5 11527.5 11528.5 11529.0 11531.0 11535.0 11535.5 11539.0 11545.5 11546.0 11546.5 11416.5 11426.0 11426.5 11427.0 11428.0 11435.5 11445.0 11454.5 11455.0 11455.5 11459.0 11459.5 11460.0 11461.0 11465.0 11472.0 11475.5 11476.0 11480.5 11484.0 11501.5 11502.0 11506.5 11509.0 11509.5 11515.0 11521.0 11522.5 11523.0 11524.0 11525.0 11526.0 11526.5 11529.5 11531.5 11538.0 11417.5 11421.5 11422.5 11423.0 11423 · 5 11425.0 11430.5 11431.0 11431.5 11444.0 11445.0 11452.5 11453.0 11456.0 11469.5 11475.0 11476.0 11478.5 11479.0 11482.0 11483.0 11501.5 11504.0 11526.0 11526.5 11533.0 11534.0 11544.0 11545.0 11545.5 11547.0 11549.0 11551.0 11552.5 11553.5 11555.5 11556.0 11557.0 11558.0 11562.0 11563.0 11564.0 11564.5 11565.0 11565.5 11567.5 11576.0 11576.5 11577.5 11598.0 11599.0 11599.5 11614.0 11614.5 11617.0 11622.0 11622.5 11623.0 11625.0 11626.0 11626.5 11627.0 11627.5 11628.0 11641.0 11641.5 11642.0 11644.5 11645.0 11650.0 11651.0 11654.0 11656.0 11656.5 11657.0 11659.0 11660.0 11664.0 11664.5 11665.0 11665.5 11666.0 11666.5 11667.5 11668.0 11672.5 11673.0 11674.0 11678.0 11679.0 11548.0 11551.0 11552.5 11553.0 11555.0 11556.0 11557.0 11557.5 11563.5 11564.0 11616.0 11622.0 11624.5 11625.0 11625.5 11626.5 11640.5 11641.0 11643.5 11644.5 11658.5 11659.0 11663.0 11664.0 11664.5 11665.0 11665.5 11666.0 11546.5 11561.5 11562.0 11563.5 11564.0 11566.0 11575.5 11576.0 11576.5 11597.0 11597.5 11598.5 11613.0 11614.0 11621.5 11622.0 11626.5 11627.5 11640.5 11641.5 11650.0 11650.5 11653.5 11655.0 11655.5 11656.0 11664.5 11665.0 11665.5 11670.0 11671.0 11672.0 11676.5 11677.5 11680.0 11687.5 11688.0 11688.5 11689.0 11694.5 11695.5 11696.0 11697.0 11697.5 11699.0 11700.5 11701.0 11711.5 11713.5 11718.5 11719.0 11720.0 11720.5 $ REMARKS: 11678.0 11686.0 11686.0 11686.5 11686.5 11692.0 11692.5 11693.0 11695.0 11696.0 11697.5 11698.5 11699.0 11712.0 11712.0 11719.0 11719.5 11718.5 11719.0 FLOWING PASS 3. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT /? ?MATCH3A. OUT /? ?MATCH3B. OUT $ : BP EXPLORATION : 4 - 42 / P - 38 : ENDICOTT : NORTH SLOPE * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GRCH PDK 68 1 GAPI 4 BIF PDK 68 1 4 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 4 CSLS PDK 68 1 CU 4 LS PDK 68 1 CPS 4 MSD PDK 68 1 CU 4 RATO PDK 68 1 4 RBOR PDK 68 1 4 RICS PDK 68 1 4 RIN PDK 68 1 4 SGMA PDK 68 1 CU 4 SGMB PDK 68 1 CU 4 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 14 SS PDK 68 1 CPS 15 SGNT PDK 68 1 CU 16 PHI PDK 68 1 PU-S * DATA RECORD (TYPE# 0 ) Total Data Records: 101 958 BYTES * 4 51 995 99 4 51 995 99 4 51 995 99 64 Tape File Start Depth = 11025.000000 Tape File End Depth = 11730.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 47976 datums Tape Subfile: 4 371 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited Static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS PDK GRCH $ REMARKS: CN WN FN COUN STAT 1, 2, 3 1 AVERAGED PASS. PASSES 1, 2, & 3 WERE AVERAGED. $ : BP EXPLORATION : 4 - 42 / P - 38 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code SamPles Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PNAV 68 1 GAPI 4 2 BKL PNAV 68 1 CPS 4 3 BKS PNAV 68 1 CPS 4 4 BIF PNAV 68 1 4 5 CSLS PNAV 68 1 CU 4 6 LS PNAV 68 1 CPS 4 7 MSD PNAV 68 1 CU 4 8 RATO PNAV 68 1 4 9 RBOR PNAV 68 1 4 10 RICS PNAV 68 1 4 11 RIN PNAV 68 1 4 12 SGMA PNAV 68 1 CU 4 13 SGMB PNAV 68 1 CU 4 14 SS PNAV 68 1 CPS 4 15 SGNT PNAV 68 1 CU 4 16 PHI PNAV 68 1 PU-S 4 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 101 Tape File Start Depth = 11025.000000 Tape File End Depth = 11730.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 47976 datums Tape Subfile: 5 123 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11023.0 PDK 11035.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 11744.0 11756.0 08-FEB-96 FSYS REV. J001 VER. 1.1 1154 08-FEB-96 11740.0 11740.0 11100.0 11729.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY PDK PDK- 100 $ TOOL NUMBER 2725XA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT): 0.000 11839.0 0.0 BOREHOLE COND I T IONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 300 FAR COUNT RATE HIGH SCALE (CPS): 6300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): REMARKS: FLOWING PASS 1. 0.0 CN WN FN COUN STAT NEAR COUNT RATE HIGH SCALE 120,000. $ : BP EXPLORATION : 4 - 42 / P - 38 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MON PDK 68 1 CPS 4 13 MSD PDK 68 1 CU 4 14 RATO PDK 68 1 4 15 RBOR PDK 68 1 4 16 RICS PDK 68 1 4 17 RIN PDK 68 1 4 18 SGMA PDK 68 1 CU 4 19 SGMB PDK 68 1 CU 4 20 SPD PDK 68 1 F/MN 4 21 SS PDK 68 1 CPS 4 22 TEN PDK 68 1 LB 4 23 SGNT PDK 68 1 CU 4 24 PHI PDK 68 1 PU-S 4 GAPI 4 51 310 01 1 4 51 995 99 1 4 51 391 51 1 4 51 390 51 1 4 51 150 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 01 1 4 51 995 02 1 4 51 391 99 1 4 51 391 99 1 4 51 430 01 1 4 51 995 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 400 01 1 4 51 995 99 1 4 51 636 99 1 4 51 390 99 1 4 51 635 99 1 4 51 995 99 1 4 51 995 99 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 293 Tape File Start Depth = 11025.000000 Tape File End Depth = 11755.000000 Tape File Level Spacing = 0.250000 TaPe File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: ReP Code: 68 121002 datums Tape Subfile: 6 369 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE GR PDK $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): START DEPTH STOP DEPTH 11076.0 11734.5 11088.0 11746.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY PDK PDK- 100 $ BOREHOLE AlqD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S ·CASING DEPTH (FT) : LOGGER' S CASING DEPTH (FT) : 08-FEB-96 FSYS REV. J001 VER. 1.1 1253 08-FEB-96 11740.0 11740.0 11100.0 11729.0 900.0 YES TOOL NUMBER 2725XA 2725XA 0.000 11839.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 300 FAR COUNT RATE HIGH SCALE (CPS): 6300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: FLOWING PASS 2. CN WN FN COUN STAT NEAR COUNT RATE HIGH SCALE 120,000. $ BP EXPLORATION 4 - 42 / P - 38 ENDICOTT NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MON PDK 68 1 CPS 4 13 MSD PDK 68 1 CU 4 14 RATO PDK 68 1 4 15 RBOR PDK 68 1 4 16 RICS PDK 68 1 4 17 RIN PDK 68 1 4 18 SGMA PDK 68 1 CU 4 19 SGMB PDK 68 1 CU 4 20 SPD PDK 68 1 F/MN 4 21 SS PDK 68 1 CPS 4 22 TEN PDK 68 1 LB 4 23 SGNT PDK 68 1 CU 4 24 PHI PDK 68 1 PU-S 4 4 51 310 01 1 4 51 995 99 1 4 51 391 51 1 4 51 390 51 1 4 51 150 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 01 1 4 51 995 02 1 4 51 391 99 1 4 51 391 99 1 4 51 430 01 1 4 51 995 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 1 4 51 400 01 1 4 51 995 99 1 4 51 636 99 1 4 51 390 99 1 4 51 635 99 1 4 51 995 99 1 4 51 995 99 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 269 Tape File Start Depth = 11075.000000 Tape File End Depth = 11745.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: ReP Code: 68 115002 datums Tape Subfile: 7 345 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11077.0 PDK 11089.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY PDK PDK- 100 $ STOP DEPTH 11730.0 11742.0 08-FEB-96 FSYS REV. J001 VER. 1.1 1347 08-FEB-96 11740.0 11740.0 11100.0 11729.0 900.0 YES TOOL NUMBER 2725XA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): LOGGER' S CASING DEPTH (FT) : 0.000 11839.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN 0IL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 300 FAR COUNT RATE HIGH SCALE (CPS): 6300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN) : 0.0 REMARKS: FLOWING PASS 3. NEAR COUNT RATE HIGH SCALE 120,000. $ CN WN FN COUN STAT : BP EXPLORATION : 4 - 42 / P - 38 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 G1 PDK 68 1 CPS 4 9 G2 PDK 68 1 CPS 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MON PDK 68 1 CPS 4 13 MSD PDK 68 1 CU 4 14 RATO PDK 68 1 4 15 RBOR PDK 68 1 4 16 RICS PDK 68 1 4 17 RIN PDK 68 1 4 18 SGMA PDK 68 1 CU 4 19 SGMB PDK 68 1 CU 4 20 SPD PDK 68 1 F/MN 4 21 SS PDK 68 1 CPS 4 22 TEN PDK 68 1 LB 4 23 SGNT PDK 68 1 CU 4 24 PHI PDK 68 1 PU-S 4 4 51 310 01 4 51 995 99 4 51 391 51 4 51 390 51 4 51 150 01 4 51 995 99 4 51 995 99 4 51 995 01 4 51 995 02 4 51 391 99 4 51 391 99 4 51 430 01 4 51 995 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 400 01 4 51 995 99 4 51 636 99 4 51 390 99 4 51 635 99 4 51 995 99 4 51 995 99 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 265 Tape File Start Depth = 11080.000000 Tape File End Depth = 11740.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 187028 datums Tape Subfile: 8 341 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 9 is type: LIS 96/ 2/20 01 **** REEL TRAILER **** 96/ 2/20 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 20 FEB 96 1:36p Elapsed execution time = 4.67 seconds. SYSTEM RETURN CODE = 0 Oat~, ' DIRECT DiGiTAL LOOGING COMPUTER PROCESSED ANALYSIS ALASKA PRODUCT ION COMPANY b.lel 1 4-42dP,-.S2 :=,b API NUM: 50-.029-2t'73i Fi~:ld ENDICOTT Counts~ DATE OF .JOB: 0E,-!8-87 !,l.]lq. FH SLOPE State ALASKA Co un t.r.,:,, USA CL I ENT FORMAT DATA TAPE LOG INFORMATION STANDARD FORMAT ( L , I , ~ ) APi NUM ~ 50- 029-2i 77 t Field: ENDICOTT DATE OF JOB: 06-1,.,'='-""7,=,- T :i me: Page: L.. I, o, TAPE RECORDS REEL. HEADER :~ :+:'+'. :~ HE~DER R E C 0 R D...,c: ~57,'~06,'~2t Origin: .Reel name: 3666~ 0 Service name: ;~,.G5FOi Pravious tape: Date: 87,"06/2i Origin: Tape name: 366610 Continuation ~:: 0'! F'iie nam¢~ (~.,.65F0! , 00'i H.a×imum iength: ! ]"; HE~DER RECORD'*o ar. sion Fiie typm: LO Pr-e.v i ous ¢i Pi i-.4 E M I N F 0 R M A T tr ON REP nRD _ C: Lq N T E Fl T S U N i T T Y P E C A T G S i Z E C.: 0 D E CN WN FN COUN STAT CTRY SECT T 0 i.,i N R~.N6 EK8 EDF EGL PD LHF DMF RUN LOC SON LUN FL LUL ENGi Wi TN DD DL TLi BLi TCS TLAB BHT MRT MT MSS MVIS RM RMF HFSI' HFSS RHC i'iCST H C S S STANDARD ALASKA PRODUCTION COMF'ANY . 4-42/:P-32 SDi APl NUH: 50-029-'2i73i ................ ENDICOTT DATE OF JOB: 06-i 8-87, ............... NORTH SLOPE ALASKA LiSA .................................... ~ 1N ..................................................... 55,180 .................................................. FT 54 , i 80 .................................................. FT 40,680 .................................................. FT ~8 KE~ 3666 i 0 .............................................. 76ii NORTH SLOPE NORTH SLOPE .................................... HUPP .................................... ZARNDT i i839, OOO ............................................... Fi' i i 858, O0 O ............................................... FT i t 058,000 ................................................ FT i i 8=:" , ............................. FT .:.b. O00 ................. ~,..,, i 50 ................................................. 'HF: 4, i20 ..................................................... HR ,.~.~, 000 .................................................. £:'EGF i88, OOO ................................................. DE(iF L I GNO .................................... FL Ob. iL i NE ..................................... 39 000 C:P 1 ; 6'~ I ................................................... OHMH ! , oo5 .................................................... OHi'iH 6..I 400 ................ DEGF' MEAS .............................................. , r ,:~ ~ ................................................... 0 H H i't 6 i . 5 fi 0 ................................................... [:~EGF HEAS ............................................. C 0 M M E N T R E C: 0 R D ~ Thi~ LIS tape wa~ written by ~earhart industries Wireiine Services. All curve and tool mnmmonics usmd are those which most closely match Gearhart curve and tool mnemonics, ~EARN~RT TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT TEN DLLMSF LBS TENS QLLMSF LBS GR DLLMSF GAPI GR DLLMSF GAPI CALl DLLMSF IN CALl DLLMSF iN LLO DLLMSF OHMM LLD DLLMSF OHMM LLS DLLMSF OHMM LLS DL. LMSF OHMM MSFL DLLMSF OHMM MSFL DLLMSF OHMM TENI BHC LBS TENS 8HC LBS GR~ BHC GAPI GR BHC GAP! DTI BHC US?F DT BHC US?F SPHIt BHC PU SPHI BHC PU DRHS2 SLD G/CS DRHO LDT G/CS DPHS2 SLD Pt] DPHi LDT PU GR2 SLD GAPI GR LDT GAPi CALi2 SL,.[) iN CALl LOT iN FFDC2 SLD CPS FFDC LOT CPS NFDC2 SLD CPS NFDC LDT CPS FCNL2 SLD CPS FCNL LOT CPS NCN L;:.: SLD L SF..:~P2 SLD CLtPE2 SLD o~DP2 SLD QUAL2 SLD FSL[:,2 SLD RHOS2 SLD TEN2 SLD .. Lpg_ SLD FIR - "-' LPCT2 SLD ' LCCT2 SLD SC:CT2 'SLD PEF2 SLD NPHS2 '"oLE RAT2 g - ._LB CPS CHAN CPS CHAN CPS LBS CPS CPS CPS CPS 8/EL SSPU NCNL LDT L. SDP LDT CUPE LDT SSDP LDT QUAL LDT FSLD LDT RHO8 LDT TENS LDT NSLD LDT LPCT LOT LCCT LDT SCCT LDT PEF LDT NPHI LDT NRAT LDT CPS CHAN CPS CHAN L:t-' :5 LBS CPS CPS uP.,.. C:P S B?EL PJ DATA ENTRY OIIlIlllIlIllIIIIIIIlSlIlIIIIIIlI1 FORMA T..,'~>PEC I F! CA.~ TYPE SiZE CODE O i 66 ENTRY BLOCK LEGEND TYPE DESCRIPTION O Tmrminator ( no morm mntrims ) DATA FORMA ~*** DATUM SPECiFiCATiON BLOCKS · _,PEC I F I f':AT IONS SERVICE SERVICE APl AP1 APl APl FiLE MNEH ID ORDER # UNIT LOG TYPE CLASS MOD i~ 0 0 0 0 0 0 ~ 0 0 2 0 0 i0 O 0 6 0 0 4 0 0 0 0 0 ~ 0 0 .32 0 0 3 0 0 ~ 0 0 i2 0 O i 0 0 2 0 0 :30 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 i 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -~ 0 0 i 0 0 DEPT 3666 i 0 FT 0 0 TENS DLLMSF 3666i 0 LBS i 1 0 GR DLLMSF 3666i0 GAPi ii 54 CALl DLLMSF ~666t0 IN ii 24 LLD DLLMSF ~GGGiO OHMM ii 220 LLS DLLMSF ~666i0 OHMM ii 220 MSFL DLLHSF 3666i0 OHMM ii i4 T~N~ 8HC 36661 0 LBS 60 0 GR 8HO ~GGG~ 0 GAPI 60 54 DT 8HC J666i 0 US/F 60 8 SPHi 8HC ~666i 0 PU 60 i 2~ DRHO LDT ~66Gi 0 G/C~ 45 i O0 DPHI LOT JGGGi 0 .PU 45 i ~2 GR ',LDT ~G66 i 0 GAP i 45 54 CALl LDT ~6661 0 IN 45 24 FFDC LOT ~G6GJ 0 CPS 45 98 NFDC LDT ~666i 0 CPS 45 98 FCNL LOT 3666~ 0 CPS 45 Y8 NCNL LDT ~66GJ 0 CPS 45 78 LSDP LDT 36661 0 CHAN 45 0 CUPE LDT ~666i 0 CPS 45 0 SSDP LDT ~ ~i 0 CHAN 45 0 QUAL LDT ~i 0 45 0 F:sLL LDT 3666 i 0 UF$ 4~. 0 RHOB LDT 3666i 0 G/C3 45 94 ~ EN~ L. DT ¢~b~J O LB~ 45 0 N.~LL) LDT 3666 i 0 CPS 45 0 LPCT LDT 3666t0 CPS 45 0 LC:CT LDT 3666 i 0 CPS 45 0 5CCT LDT ~61 0 CPS 45 0 PEF LDT 3666i O B/EL 45 0 NPHi LDT ..~,66 ~ 0 PU 45 i 22 NRAT LDT ~6661 0 45 164 PRC J$ SiZE LYL SMPL MU 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 I 68 4 0 i 68 4 0 i 68 4 O i 68 4 0 i 68 4 0 i 68 4 O i 68 4 0 i 68 4 O i 68 4 0 i 68 4 O i ,SS 4 O i 68 4 O i 4 0 i 68 4 0 i 68 4 0 1 68 4 0 i 4 0 i bo"~-' 4 0 t 68 4 O i 68 4 0 i b~"R 4 0 1 68 4 0 'f 68 4 0 i 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Ol'JO000 000000 000000 000000 000000 000000 000000 000000 000000 O00OO0 000000 000000 '000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 UtiUUUU UUUUUU Ut. JUUUtJ 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0000O 000000 000000 000000 000000 DA TA RECnRDo DEPT TENS GR CALi LLD LLS MSFL TENS GP, DT SPH i DRHO DPH i ~]R CALi k ~ L) u . .. E' ~-2 L FSLD NFD~] F ~NL NCNL LSDP CUPE ~ ~ UA RHOB TENS N~L[ LPCT LCCT SCCT PEF NPHi NRAT !879.000 -999.250 -999,250 -999,250 -999,250 -999.'-250 -999.250 299i . 000 0,000 O,OOO -4i',679 -999,250 -999.250 -999.250 -999.250 -999.'250 -999. 250 -999,750 -999,250 -999,250 -999. ~50 -999. ~50 -999. 250 -999. ~50 · -_. ~,~ - 9 0 -999 ~50 -999 ~50 -'~'~ - ......... ~o 0 . 0 -'~'~'~. Zb U L~'~'~ -~_ ~,~bO ii77'.~ .... 000 4118,000 26.500 8.250 S~_, 594 ._,..~ u~.,~ 9Oq,..,glS_ 3894.000 z. 000 I~4 `300 58 995 05i 58 ~72 ~4 342 9 093 0 000 0,000 55.226 i70.822 109.890 4,309 ii2,~i0 ,722 47i09,i87 1,684 4i67,870 ~45i9,922 90i3,400 i5i~0.¢,9~ 2550.i .047 i ,80B 67,206 3,26~ ii679,000 4i25,000 101,800 8,840 13,122 i1 ,803 98,I00 70,800 II,.-4_,94 ,0,~7 2.370 i08,54'? O, 000 i90, t57 ,327,457 I 09.260 .87.'3_'. i I2, i90 2. 606 4282. 255 23484,906 950, 078 ~ 9 i 5. 059 i 5680. 549 I ,792 579, 000 4186, 000 i17,700 9,010 t0, i62 8,590 i03,900 7i,400 it,844 ,i4t .975 ii4,..'300 O, 000 158, 000 277..300 i 09,, 580 ,970 i i2 ,.330 2,630 44i6,000 24774,.223 t 008,000 2i57,000 i7972,000 i, 898 t.3,900 8,966 i, 2.512 i2,503 9,580 i , 006 2,895 3821,000 0.000 95i7,568 23.09i '~82 t 000 0:000 8 ~]$~. ..., 2.59 24,95 0 !i4,. 000 4046 000 92 700 8 ,'0~] i4 i'~'':' i'-~ 97'-" '"'" ""~ .. ...... ,-.. ........ ..---~ , ,~ ..., I 37'42 0 n 0 i05, ,"00 ,-'`3 ,400 i ,..';, ,.,,:,l..s , n.~9. _ ," ,596 i08 ,,:,.':" 67 8 , ~:: ,",'_-.: 0 ,000 0 000 15i '~""" 27 , "' 79 , , ,,..Z," O, no0 i 09,7i0 977 i i2,4i 0 i , 054 oi68.4 2 519 4i65 804 23i 02 090 10~8 '~ .... , - , '" n89 i7 ""'"3 ..... 4..i zg'4~ 84.'3., t6,."~i 590 ~ .... ,',..-, .~ ,950 11379.000 3896,.000 51,500 9,060 20,464 t9.055 i6,672 3669.000 4`3.400 78, i00 't6,867 ,048 6,344 6i ,C°'" , .~.~. 8 894 O.OOO , O 000 i .-.,`3 080 287 ~.s::::, i 09 600 , .-',': ,- i i 2 `340 i O..s7 ._':,.-_,4..-,, 69:,.', 2 54 i 3'~35 4'.' 7 Z2 i 1 .-:', 25 0 41 I 5 ..~o -- .,~ .-,. -- .o ' ~..- 145P 8~5 'ib,,'~¢ 820 ...,'u' 992 ":'S, i .984 DEPT N~- DC RHOB NRAT TENS L) f FCNL TENS SPHi N.L: NL NSLD DA CALl DRHO LSDP LPCT TA RECORDS LLD DPHi CUPE LCCT LLS MSFL CALl MUHL PEF T E N :--; P P L:~ L: F 'S--: L D NF'H i Page 9 ii279,000 98,i00 0,000 2,490 2,I55 3937,000 67.208 126,969 3993.4i2 i35,700 8,696 266,039 26296.703 9.240 .i99 i 09.66 O 04t .87i i i, 668 9.392 · 995 27i8,6i2 9,594 i32.538 ii2.i70 192i0.473 4,i2i 07i 9i 9 0.000 940i.020 30.662 11179,000 47.208 0.000 2,43i i.599 11079,000 i26,700 O,OOO 2,543 2,5.88 3905,000 74,000 263,i82 3981.984 38i0,000 89.800 8i,300 3942,500 57.900 418. i87 20908,590 i37,000 25,637 207,650 22080,590 8,590 ,067 i 09.45 O 847,7i5 i3.590 i 09,400 9i5,500 34,119 i2,976 .766 i 962.3 i 6 8,._7i8 6.i76 ,909 2187,500 28.708 64.0i0 ti2.i70 15127,969 8, .337 i37.450 ii2,200 i6052,500 i7.579 9.i64 i, 0Si i0.000 i3.390 i,023 3.235 36 06. 00 O O: 000 7052. 200 i 7,980 TR~ ! LER RECORDC Fii~ nmm~: ~GSFOi . ~'~a>.'. i mu m l~ngth: t 9ersion ~: Film type: LO Next f i i m: Date: ? a g e :~:~- EOF :,~:~-~ **** FiLE HEADER File name~ &GSF01,002 Maximum !~ngth: 10~4 HEADER RECORDo Version Film t?pm: LO Prmvious ¢ilm: Da'tm: P .-.:a ge__ I NFORMA TiON REPORD o P .'--, g:I e ! 2 MNEM CONT'-NT:~.,"- _ LiNi T TYPE CATG S i ZE :-:ODE CN WN FN COUN STAT CTRY SECT TOWN RANG EK8 P_.L)P EGL PD LMF DHF RUN LOC ..UN L UN FL LLiL LNG I b.II TN [:,D DL TLi 8L! TC S TLAB BHT MRT MT MSS MVIS RM RMF MFST MFSS RMC oT L. ;2, STANDARD ALASKA PRODUCTION COMPANY ................ 4-4~xff-Sz SDi APl HUM: ENDICOTT DATE OF JOB: 06-i~-~¢ ................ NORTH SLOPE .................................... ALASKA I 1N ..................................................... iTL ..................................................... 55, i80 ................... ' ...... FT 54 . i 80 .................................................. FT 40,680 ' FT 3666 i 0 .... 76ii ............................................. NORTH SLOP~ .................................... SLOPE .................................... HUPP Z~RNDT .......... · .......................... ~i8~9,OOO ............................................... FT i1858,000 ............................................... FT iiO58,OO0 ............................................... FT !i856,000 ............................................... FT 2D,iSO .................................................. HR 4,i20 ................................................... HR i88,OOO ................................................. DEGF i88,000 ................................................. obGF LiGNO FLOWL i NE 39, OOO ...... i ,691 ....... i ,585 Bi , 400 ...... MEAS, i .783 ....... 6i , 500 ...... PLEAS. CP OHMM OHMM OHMM DEGF 0 0 40 65 0 0 40 .65 0 0 4 O 65 0 0 20 65 O O 20 ~5 0 0 2 O 65 0 0 2 65 0 0 ~ 65 O O .7 65 0 .3 4 68 0 ~. 4 68 0 3 4 68 0 .'g 2 65 0 3 ' 2 65 0 ~ 2 6.5 0 8 2 79 0 O 2 7' 9 Ct O i O 65 0 0 i 0 6 5 0 O 20 65 0 0 '20 65 0 O 20 65 0 0 2 0 E, 5 0 3 4 68 0 .7 4. 68 0 3 4 68 0 .3 4 6 :.3 0 2 4 68 0 4 4 68 0 i 4 68 O i 4 6:3 0 2 20 0 2 '2 0 6 5 0 '2 4 6 8 0 2 4 6:3 O ':' 4 : 0 2 4 r:'.8 0 2 ! 2 65 0 2 4 68 0 2 4 68 0 '2 'i 2 65 COMMENT RECORDS This LIS tape was written bp Gearhart Industries Wireiine Ail cur',tm and tool mnmmonics usmd arc those which most closely match Gmarhart curve and tool mnemonics. GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UHIT DEPTH FEET DEPT FT TENS OLLMSF LBS TENS PLLMSF LBS GRS OLLMSF GAPI GR PLLMSF GAPI CALLS PLLMSF IN CALl DLLMSF iN LLO~ DLLMSF OHMM LLO DLLMSF OHMM LLSS DLLMSF OHMM LLS DLLMSF OHMM MSFLS QLLMSF OHMM MSFL DLLMSF OHMM GR4 8HC GAP! GR 8HC GAPI PT4 BHC US/F DT 8HC US?F SPHI4 8HC PU SPHi 8HC PU TEN4 BHC LBS 'TENS BHC LBS TEN5 SLD LBS TENS LDT LBS GR5 SLD GAPi GR LDT GAPI CALi5 SLO IN CALl LOT IN FF'DC5 SLD CPS FF'DC LDT CPS NFDC5 SLD CPS NFDC LDT CPS FCNL5 SLD CPS FCNL LDT CPS NCNL5 SLD CPS NCNL LDT CPS · LSDP5 CUPE5 SSDP5 DPHS5 DRHS5 PEF5 FSLD5 NSLD5 LPCT5 LCCT5 SCCT5 RHOS5 RAT5 QUAL5 NPHS5 SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD CHAN CPS CH~N PU B/EL CPS CPS CPS CPS CPS SSPU LSDP LDT CUPE LDT SSDP LDT DPHi LDT DRHO LDT PEF LDT FSLD LDT NSLD LDT 'LPCT LDT LCCT LDT SCCT LDT RHOB LDT NRAT LDT QUAL LDT NPHI LDT CHAN CPS CHAN PU G7C3 B/EL CPS CPS CPS CPS CPS G/CS DATA FORMAT SPEC I F l CAT I ON._~, ~- :*: ~: ~ ENTRY BLOCKS ~+: .~':~ ENTRY T"'," P E S i ZE CODE 0 i 66 P .~g ,e :~:mm ENTRY BLOCK LEGEND mmmm :~. :~ :~:~ :~.:~ ~ :~ :~ :~ .~.~ ~:~. '~ ~ :~. ~ ~ :~ ~ ~. ~: :~:~..~ TYPE DESCRIPTION 0 Terminat. or ( no mor. m entries ) DATA FORMAT ~.**:~ ~,HTUM SPECIFiCATiON 8LOCK~ MNEM SERVICE SERVICE ID ORDER ~ AP1 AP1 AP1 APl FILE UNiT LOG TYPE CLASS MOD ~ DEPT TENS GR CALl LLD LLS MSFL GR DT SPHi TENS TENS GR ,i CALl FFDC NFDC FCNL NCNL · LSDP CUPE SSDP DPHi DRHO PEF FSLD HSLD LPCT LCCT SCCT RHOB NRAT QUAL NPHi DLLMSF 3666i8 DLLMSF 3666i0 DLLMSF 3666t0 DLLMSF ~66G10 DLLMSF JGGGiO DLLMSF J666i0 BHC ~G6610 8HC 366G18 8HC 3666i0 8HC JG6610 LDT ~666i0 LDT ~666i8 LDT 3666i0 LDT 3666i0 L. DT 3666i0 LDT 3GGGiO LDT 366610 LOT $666~0 LDT ~666~0 LOT ~66G~0 LDT ~66,6i0 LDT ~66610 LDT ~66610 LDT $666~0 LDT ~666~0 LDT 366610 LDT 3666i0 LDT 366Gi0 LDT ~666i0 LDT ~666~0 LDT ~666~0 LDT ~666i0 FT 0 0 0 0 0 LBS ii 0 0 O i GAPi ii 54 i 0 i iN ii 24 2 0 i OHMM ii 220 iO 0 OHMM ii 220 6 0 i OHMM ii 14 4 0 1 GAPI 60 54 i 0 i US?F 60 8 '32 O i PU 60 i22 $ O t LBS 60 0 0 0 i LBS 45 0 0 O i GAPI 45 54 i O i IN 45 24 2 0 i CPS 45 98 2 0 i CPS 45 98 i 0 i CPS 45 78 Si 0 i CPS 45 78 30 0 i CHAN 45 O 0 O i CPS 45 0 0 0 i CHAN 45 0 0 0 1 PU 45 i22 i2 O. i G?C3 45 i00 i 0 B/EL 45 0 0 0 i CPS 45 O 0 0 i CPS 45 0 0 0 CPS 45 0 0 0 i CPS 45 O O 0 CPS 45 0 0 0 i G/C3 45 94 i O i 45 i64 i O 45 0 0 0 i PU 45 i22 ¢ PECIFICATIONS PRC ~ SiZE LVL SMPL 4 0 i 68 4 0 i 68 4 0 i 68 4 0 I 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 O i 68 4 0 i 68 4 0 i 68 4 0 'i 68 4 0 i 68 4 0 1 68 4 0 i 68 4 0 i 6,8 4 0 I .'o 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i b~."~ 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i ~o 4 0 i An PROCESS iNDiC'A"FORS 000000 O00OO0 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 O00vuu 000000 O00000 OIjClO00 000000 000000 000000 O00uuu 000000 000000 000000 000000 000000 O00OO0000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 Ij 0000 l'i O01jO00 000000 000000 000000 000000 000000 1'100000 000000 000000 OHO000 000000 OOO000 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00OO0 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOOOO0000000 O00000 000000 000000 000000 P a :..] e i, DEPT DT FCNL FSLD NPHi TENS SPHI NCHL NSLD T E N S L S D P LPCT D A'FA CALl TENS CUPE LCCT RECORDS LLD GR SSDP SCCT LLS CALl DPHi RHOB ~I._F~_ FFDC DRHO NRAT Ni-Qu PEF QUAL Page !6 ii868.500 -999.250 O,O00 ii967.404 1.743 i1768,500 -999.250 47,600 50699,088 6i.780 1i668,500 -999,250 87,300 i0069.305 -999.250 -999.250 0,000 27797.i09 4193,000 -999,250 iSG.iOO 4154,000 -999,250 205.500 23442,270. -999,250 -999,250 iii,600 i666.008 -999,250 iii.840 9494.000 13t ,400 -999,25 0 i11,030 7ti ,000 -999,250 32i5o000 i.533 3420.000 10.5i0 431 3,000 5. 042 i 7752,. OOO 9.2i0 4470,000 ,663 1572.000 -999,250 0.000 i i2, 20265,000 2421,027 35,700 i12,430 24694,000 8.375 i30,600 it2.240 14163.000 -999.250 0.000 -999.250-999.250 1._-:',58.3i4 I1 ,870 68,207 i ~": 7.55i 9,620 -.729 2.659 -999.250 0.000 999. "~- ~ 2. 564 0.000 .008 3.34'9 i2.503 0,000 059 ,442 -9'39.250 0.000 -999.250-999.250 -999.25 0 O, 000 2,4'25 -999.250 0.000 i , '39.' 65 i . J ~ ii568o500 -999.250 i90,500 , ~0,455 24,620 4i64,000 -999,258 334.400 22088,062 10i,300 -999,250 tli,310 1002.000 9,170 4274,000 .965 2i07,000 ii,858 i08,00O ii2.500 i5856,000 ! 0.257 9.520 2.538 2,603 t2, 050 0,000 ,034 i .8i4 O, 000 2, :SOO i , 048 1t468.580 -999,250 93,800 7655.974 34,960 11368,500 --.999,250 315,500 i0423,160 i9.400 4085,000 -999,250 220.000 26853.426 3959,000 -999,250 447,200 22855,94t t05,400 -999,25 0 t11,4i0 8i I , 000 .~6,i00 -999.250 1ii,280 i236,000 9.970 4230.000 .760 225i,000 8.490 3977, O00 i ,205 2!64,000 6;095 i08,500 ii2,600 19649,000 28.379 50.600 ii2,590 i5064,000 5,559 i0,340 1,i29 2,627 24,660 9.OiO i0.205 2.477 5,129 0,000 ;068 2,440 i8.880 0,000 .044 t.464 -99 '9, '2. 5 0 O, 000 2,76.4 ,988 -999.250 0. 00 0 !. 9e'.5 ! , I"j'~ ," DEPT DT FCNL FSLD NPHi TENS SPHi NCNL NSLD GR TENS LSDP LPCT CALl TENS CUPE LCCT TA RECORDS LLD SSDP ~L:L: I LLS I~ALi DPHi RH08 MSFL PP DRHO NRAT -- -- ? ~ F rj C P'hP L-]UAL i i268,500 77,200 ,..,. O, 500 885 i , i 46 17,759 S775.000 i6.i92 5i4,200 27659.i80 i25,000 358i,00O iii.290 1000.000 8.580 3869.000 .970 2650.000 32.211 i28.i00 ii2,530 i7232.000 36,813 9.000 5.853 2.548 8.630 0.000 ,042 i .407 44.200 0.000 3,453 i.08i iii68,500 75,800 i02.700 9204.490 35,820 i 068,50(! 94 ,.300 75,500 9057, 331.430 10968,500 65,200 --999,250 -.999,250 -.-999,250 i 0868,500 80,000 -999,250 .... 999,250 -999.25 0 i 0768,500 i J4, i O0 -999,250 .... 999,25 0 -999,250 3976,000 i5,i42 22i,600 237i3.754 3808. 000 29.010 i94.400 23550,496 -999,250 7,t96 -999,250-999,250 .-999.250 i8.29i -999,250 -999,250 -999,250 58,846 -999,250-.999,250 i26,300 36i6,000 ii0.970 622,000 t12,8:00 3538.000 ii1,000 1093,000 .-999,250 3547,000 -999,250 -999.250 -999,250 3508,000 -999,250 -999,250 -999,250 3479,000 -999,250 -999,250 9.770 4i 52,000 i 465, O00 i2,2t0 383(i, 000 i . 002 2657. 000 -999.250 -999,250 -999,250 -999,250 -.999,25,0 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 7,482 i23,000 112,370 14330,000 i9.907 i37,i00 it2.480 i7i°'~==. , 000 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 -999,250 -999.250 -99'9,250 -999.250 4.898 i0.300 3,458 26.424 i2,490 8,028 2.5i2 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999. 250 -999,250 -999.250 -999,250 -999.250 8.07'2 0.000 .080 2,305 67.920 0,000 -.(ti2 2.642 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999.250 -999.250 ii5.600 0,000 .3,323 ,996 i43.100 O. 000 4,9:35 .999 --999.250 - 9 9 9. '25 0 -. 9"~9,250 i41,900 -999.250 .... 399.250 -999,250 :39. i O0 - 999,250 -999,250 9 g g '" = TA RECORDS Pag~ i 0668,500 -999,250 -999,250 -999,250 -999,250 i~5,000 59,520 ,~4:~0,000 -999,250 -999,250 -999,250 -999,250 -999,250 -999,258 -999,250 -999,250 -999,25r~ -g' , . .'~9 250 -999 250 '.~'.~9 250 -s,,4.,~ 250 999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 --999,250 File nmme: &GSFO~. 00~ Maximum iength: 1024 TRAILER RECORDS V~rsior, ~: File tppm: LO Nmxt ¢iie: EOF *** MICROFILMED DIRECT DIGITAL LOGGING COMPUter PROCESSED ANALYSIS Compan~ '"' _.OMPHNY · :,TANDARD ALASKA PRODUCTION !'"' ..... Well 4-427P-38 SDI AP! NUM: 50-029-21 '731 Field ENDICOTT DATE OF JOB: 06-18-87 Counts~ NORTH SLOPE Statm ~L~._KA Country USA CLI LOG ENT FORMAT DATA TAPE I NFO'RMAT I ON STANDARD FORMAT ( L , I , S . ) W~ t,i .No:: 4-4~,.' P-~ Depths: 1 062S, O0 t.o ~ ~ 8~ 9~ O0 Name ' I ~- ~'-,- AP1 NUM: 50--029-2~-~- Field: ENDICOTT DATE OF ,JOB: 06-18-87 L, I, S, TAPE RECORDS Prmvious rmmi: HEADER Datm: 87/06?29 Origin: Comments: RECORDS P .,-a g e '2 Continuation ~: 0i TAPE HEADER Smrvicm namm: &GSFOi Prmvious tapm: Datm: 87/06/29 Origin: Commmnts: Tapm namm: ~66610 Continuation ~: O1 FiLE HEADER Fiie name: &G5FOi Maximum length: 1024 HEADER RECORDS Service name: Version File tppe: LO Previous ~ile: Date: MNEM CN WN FN COUN STAT CTRY SECT TOWN RANG EK8 EDF EGL PD LMF DMF RUN LCC SON LUN FL LUL ENGi WiTN DD DL TLI BL! TCS TLAB 8HT HRT MT MSS MVIS RM RMF MFST MFSS RHC fiCSl' MCSS I NFORMAT I ON REF:ORDS CONTENTS UNiT T"/PE CATG SIZE CODE STANDARD ALASKA PRODUCTION COMPANY 4-427P-38 SDi ENDICOTT NORTH SLOPE ALASKA USA 08 i?E.,. 55,180 54,18.8 40, .680 MS AP1 NUM: DATE QF 50-029-2t 73! JOB 06-i 8-87, .36661 O ,;~6 i i, NORTH SLOPE NORTH SLOPE HUPP ZARNDT i1839,000. .. i't858,000. ., t!058.000, ,, ~ I856,000 .... 23, I50 ...... 4,i20 ....... 188,000 ..... 188.000 ..... L I GNO FLOWLINE 39,000 ....... i ,69I I . 585 ........ 6i ,4O'O i'iE AS, , i ,78~ ........ ,Si , 5 O0 ........ MEAS. . , 0 O 40 65 0 0 4- O 65 0 O 40 65 0 O 20 65 0 0 20 65 0 0 2 O 6, 5 : 65 O 0 .3 65 0 0 ~ -65 FT O 3 4 68 FT 0 ..'7,, 4 68 FT 0 ~ ,4 68 0 .3 c: 65 O 3 2 65 0 .~ 2 65 0 O '2 79 O 0 '> ~" 0 0 iO A5 0 0 iO 65 0 0 '-"0 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 ..,~ 4 68 FT 0 3 ,4 68 FI' O ..,~ ,4 68 FT 0 3 ,4 68 HR O 2 ,4 a~,"'c, HR 0 4 4 G8 [Eu~ 0 i 4 68 DEGF 8 i 4 68 O c, . ,. ,-_'0 65 0 2 20 65 CP 0 2 4 '.,E, 8 OHMM 0 2 4 68 OHMM 0 2 4 68 DEGF 0 '2 4 68 Oi-tMi'i 0 2 4 68 DEGF' 0 2 4 68 0 2 ~2 65 P a g e COMMENT RECORDS m~ This LIS tapm was writtmn by Gearhart industrims Wireline Services. mm ** All'curve mhd tool mnemonics used are those which most closmlp mmtch ** mm Gearhart curve and tool mnemonics, ~m GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT TEN' DLLMSF LBS ' TENS DLLMSF LBS GR DLLMSF GAPi GR DLLMSF GAPI CALl DLLMSF IN CALl DLLMSF IN LLD DLLMSF OHMH LLD DLLHSF OHHH LLS DLLHSF OHMH LLS DLLMSF OHHM MSFL DLLHSF OHMM HSFL DLLHSF OHHH TEN1 BHC LBS TENS 8HC LBS GRI 8HC GApI GR 8HC GAPI DTi 8HC US?F DT 8HC US?F SPHIi BHC PU SPHi 8HC PU DRHS2 SLD G/CS DRHO LDT G/CS DPHS~ SLD PU DPHI LDT PU GR~ SLD ~APi GR LDT GAP! CALi2 SLD iN CALl LDT FFDC2 SLD CPS FFDC LDT CPS NFDC2 SLD CPS NFDC LOT CPS FCNL2 SLD CPS FCNL LDT CPS NCNL~ LSDP~ CUPE2 SSDP2 QUAL2 FSLD2 RHOS2 TEN2 NSLD2 LPCT2 LCCT2 SCCT2 PEF2 NPHS2 ~AT2 SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD SLD CPS CHAN CPS CHAN CPS G/C3 LBS CPS CPS CPS CPS 8,¢EL SSPU NCNL LDT LSDP LDT CUPE LDT SSDP LDT QUAL LDT FSL. D LDT RHOB LDT TENS LDT NSLD LDT LPCT LDT LCCT LOT SCCT L~T P~F L~T NPHI LBT N~AT L~T CPS CHAN CPS CHAN CPS LBS CPS CPS CPS CPS B/EL PU. ~ATA ENTRY BLOCKS ENTRY FORMA T SPEC 1 F I CAT IONS TYPE S i~.?E CODE 0 1 66 ENTRY BLOCK LEGEND TYPE L. EsL~RIPT!ON 0 Terminator ( no morm entrie~ ) DATA FORMA DATUM SPECiFiCATiON BLOCKS T SPEC I F I CA SERVICE SERVICE AP! AP1 AP1 AP1 FILE HNEH iD ORDER $ UNiT LOG TYPE CLASS HOD $ DEPT 3666i 0 TENS DLLMSF 3666i0 GR DLLMSF 3666i0 CALi DLLMSF 3666i0 LLD DLLMSF 366610 LLS DLLMSF JGGGJO MSFL DLLMSF 3GGGiO TENS OHC 366610 GR BHC ~66610 DT BHC 36GGlO SPHI BHC 366Gi0 DRHO LDT 366610 DPHi LDT ' 3666i0 GR LDT 3GGGlO CALl LDT 366GI.0 FFDC LDT 366G10 NFDC LDT 3GGGiO FCNL LDT 3GGGlO FT 0 0 0 0 0 LBS ii 0 0 0 0 ~APi ii 54 i 0 0 IN ii 24 2 0 0 OHMM ii 220 i0 0 0 OHMM ii 220 6 0 0 OHMM ii i4 4 0 0 LBS 60 0 0 0 O GAPi 60 54 i 0 O PU 60 i22 3 0 0 ~?C3 45 lO0 i 0 0 PU 45 i22 i2 0 O GAPi 45 54 i 0 0 IN 45 24 2 'O 0 CPS 45 98 2 0 0 CPS 45 98 1 0 O CPS 45 7.8 3i 0 0 CPS 45 78 30 0 O CHAN 45 0 0 0 0 CPS 45 0 0 .0 O CHAN 45 0 0 0 0 45 0 0 0 0 CPS 45 0 0 0 0 G/C3 45 94 t 0 0 LBS 45 0 0 0 0 CPS 45 0 0 0 0 C'PS 45 0 0 0 0 CPS 45 0 0 0 0 CPS 45 0 0 0 O B/EL 45 O 0 0 0 PU 45 i22 S 0 0 45 i64 I 0 0 NCNLLDT 3666i0 LSDP LDT 366610 CUPE LDT 3666i0 SSDP LDT 3666i0 QUAL LDT 3666i0 FSLD LDT 366610 RHOB LDT 3666i0 TENS LDT 3666i0 NSLD LDT 3666i0 LPCT LOT 366610 LCCT LDT 366Gi0 SCCT LDT 3666i0 PEF LDT 3666i0 NPHI t. BT 3666i0 NRAT LOT 3666i0 PRE: ~ SiZE LVL SMPL 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 T!ONS ~'!'<UL: ESS iNDiCATORS 000000 UUUUUU 000000 000000 000000 UUUUUU 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 UUUUUU 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 UUUUUU UUUUUU 000000 000000 000000 000000 UUUUUU UUUUUU 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O000nO~ 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 P a g *.:: 7 DATA RECORDS DEPT N F D C RHOB NRAT TENS FCNL TENS GR SPHi NCNL NSLD CALl DRHO LSDP EPCT LLD DPHi CUPE LCCT LLS 55L)p~ S C C: T MSFL CALi ;:,~ U ~ L PEF T E N S l"t- L)U F' S L g tiP'Mi Page 11879,000 0.000 -999,250 -999.250 -999,250 -999,250 O.OOO -999.250-999.250 -999,250 -4i.679 -999,250' -999,250 -999,250 -999,250 -999,250 -99'9,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 -999. 5_,g___ -'YL:¢. L-¢, Z~ U -999.250 -999.250- -999.250 -999.250 O. 000 -999,250 -99'9,250 -999,250 1i779,000 30,800 0,000 1.684 3,263 4ii8.000 t35,200 55.226 4167,870 26,500 59.670 i70.822 34519,922 8.250 ,05i i 09.890 9013.400 323,594 58.372 4..309 i5i50.693 399,025 34,342 ti2,3i0 2550i.047 909,9i .'3_, 9. 093 .722 i .803 3869.000 0,000 47i09.i87 67.206 J1679.000 94,600 0,000 2,606 1.792 4i25.000 7i,i00 i90.t57 4282,255 lOi .800 1i .6i9 327.457 23484.906 8.840 ,037 I 09,26 0 950., 078 13. 122 ,873 I 9i 5. 059 ii .803 i 08,547 i12.190 15680..549 1,3.900 8,966 i, 043 2,5i2 a~oO.O00 0,000 95i7.568 '..23.09i 11579,000 112,800 O,OOO 2,630 i.898 4186,000 72.700 !58.000 4416,000 117,700 i2,819 277.300 ~ '7 · - ~4,', 4 .,.r,"~' 9.0t0 .141 i 09.580 i 008,000 'J O. 't62 .975 ,970 2i57. 000 8.590 it4.300 ii2;330 i7972,000 12,503 9,580 i,006 2.895 3840,000 O,O00 24.950 1479,000. 93, t 00 0,000 2,5t9 t ,950 4046,000 73.000 i51.227 4i65,804 92.700 i3,043 270,000 23102,090 8,700 ,059 109,7i0 0~8,45i i4,i25 7,596 .977 229i.843 I2,972 I 08. 267 i12,4i0 i67i t ,590 22.751 8.878 i.054 2,089 3723.000 O,uuu 8t68.479 i7,783 · 379,000 58,500 O, 000 2,54i I., 984 3896,000 75,200 t53,080 3935,467 51,500 i4,693 287.935 22113.250 9,060 ,048 09,600 41 i .502 20,464 6. 344 .397 1452,835 19,055 6i,022 tt2,340 15747,820 J6.672 8. 894 i. 037 3. 992 3674, 000 O. 000 5543.696 2.3, 057 DATA RECORDS DEPT TENS GR CALl LLD LLS MSFL TENS GR DT SPHi DRHO DPHi GR CALl PPDC NPL~U FCNL NCNL LSDP CUPE ~,~ QUAL FSLD RHOB TENS NSLD LPCT LCCT SCCT ~F NPHI NRAT F'au]e 11279,000 3937,000 135,700 9.240 11.668 9.594 98.i00 67.200 8,696 .i99 9.392 i32.5J8 O,O00 i2G,gG9 266,039 ~09.660 ,995 ~i2,i70 2.490 3993.412 26296,703 i04i.87i 27i8.6i2 i92i0.473 2.t55 4~!2i i,07~ 3.9i9 3664.000 0,000 940i.020 30.662 11179.000 3905,000 57,900 8,590 34.~!~9 28.708 47.200 74.000 i3.793 .067 12,976 64.0i0 0,000 263.i82 418,i87 109,450 ,766 112,170 2,431 3981,984 20908,590 847.715 1962.3i6 15127,969 i.599 i7.579 9,i64 i.08i 3.075 ...b 06. 000 O. 000 7052.200 i7,980 079,000 -_'381 0 , 000 i ._"3,7,000 l 3,590 8 · 318 8 , 337 130. 900 89.80:0 25. 637 , 0.35 6.176 137. 450 O, 000 81 · ~OO 207,650 1 09. 400 · 909 i 12,200 2,54~ 3942,500 22080,590 9t5,500 2~87,500 16052.500 2,588 iO,OOO i3.390 i.023 ~,235 35'91,000 0.000 7855.348 ..S~,~i5 FiLE TRAILER TRAILER RECORDS Film name: &GS'F01.00~ Service name: Version #: [)ate: Maximum length: 1'024 File type: LO Next ~ilm: EOF m~m FiLE HEADER :~-mm · Fiie name: ~u5F01 .002 Maximum lmngth: t024 HEADER REC'ORD~' Service namm: Film type: LO Prmviou$ ~ilm: Datm: i'l I NFORMAT I ON RECORDS P~L].i i MNEM CONTENTS UNiT TYPE CATG SiZE uODE CN WN FN COUN STAT CTRY SECT TOWN RAN~ EKB EDF EGL PD LMF DMF RUN LCC 9,ON LUN FL L. UL EN~I WiTN OD OL TLI 8Li TCS TLA8 8HT MRT MT MSS MViS RM RMF MFST MFSS RMC MCST MCSS STANDARD ALASKA PRODUCTION COMPANY ................ 4-42/P-38 SDi AP1NUM: 50-029-2i73i ................ ENDICOTT DATE OF JO8:06-i8-87 ................ NORTH SLOPE .................................... ALASKA .................................... USA .................................... 81tIIllIIlIIIWIllIIlIIlIrlIrl;,;lllrilllllIllIllIIIIlfI tlN ..... ' ................................................ iTE,,...,.,,..,,.,,,,...,, .... ,.,,, ............... ,,.,,, 55, i80 54,18:0 , ,, 40,680 , MS KB ...... K8 ...... -~GGG 10 ............ 7G i i .......... NORTH SL O~S F-'._ NORTH SLOPE , HUPP Z~RNDT 1 i839,000 ........ i i 858,000 ........ i i'058,000 ....... i i ~56,000 ....... 23, ~50 .......... , 4,i20 ........... 1.88,000 ......... ~, 000 L I GNO FL'OWL. I NE 39,000 .............. i ,691 ............... o.~5 6i , 40.0 .... .............. MEAS ........ · ..... I ,783 ................... 6I ,~ ~'~0.0 ................. , MEAS ............. IIiIIIiliIrlililtIIlIlIlItiIi~iIiIliIiitii IliliiIIIIiiIIWIilllIiliJIllII! FT FT FT FT HR HR DEGF DEGF CP OHMM OHMM DEGF OHMM DEGF 0 0 40 0 0 40 0 0 40 0 0 20 0 0 20 0 0 2 '" 0 0 2 . 0 0 0 0 0 3 4 0 3 4 O ~- 0 3 2 0 3 2 0 ~ '" 0 .0 '2 0 0 0 0 iO 0 0 i 0 0 0 20 0 0 2O 0 O. 20 0 0 20 0 3 0 ~ 0 F~ 0 3 0 2 0 4 0 i --' 0 i 0 '2 '-' 0 ~. 20 0 2 4 · ~ 4 O 2 4 0 '" i '-" 0 '" 4 0 2 i2 65 65 65 65 65 65 65 65 68 68 ~5 65 65 65 6~ 65 65 65 65 68 6~ 68 68 65 68 68 6~ 68 68 65 COMMENT RECORDS This LiS tmpe wms written by Gearhmrt indostrims Wirelinm Servicms. m~ All curvm and tool mnmmonics usmd mre those which most clos¢l,, mmtch mm Gcarhmrt curve mhd tool mommonics, mm MNEM GEARHART TO SCHLUMBERGER SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT TEN3 DLLMSF LBS TENS DLLMSF LBS GA3 DLLMSF GAF' I GR DLLMSF GAF' CALI3 DLLMSF IN CALI DLLMSF IN LL[ ,.~ DLLMoF OHMM LLD DLLMSF OHMM L~ DLLMSF' OHMM LLS DL..LM'~ oF OHMM MSFL~ DLLMSF OHHM MSFL DLLMSF OHMM GR4" BHC ' GAPI GR 8HC GAP! DT4 8HC US?F DT 'SHC US/F SPH~4 BHC PU .~FHI 8HC PU TEN4 8HC LBS TENS 8HC LBS TEN 5 SLD LBS TENS LDT LBS GR5 SLD GAP~ GR LDT GAP CAL I5 SLD iN CALI LDT IN FFDC5 SLD CPS FFDC LDT CPS NFDC5 SLD CP'? · ~, NFDC LDT CPS FCNL5 ~-LD CPS FcNL LOT CPS NCNL5 SLD CPS NCNL LDT CPS LS[~P5 SLD CHAN LSDP LDT CHAN CUPE5 SLD CPS CUPE L. DT CPS SSDP5 SLD CHAN SSDP LOT CHAN DPHS5 SLD PU DPHI LDT PU DRHS5 SLD G?C~ DRHO LDT G?C~ PEF5 SLD B/EL PEF LDT B/EL FSLD5 SLD CPS FSLD LDT CPS NSLD5 SLD CPS NSL. D LOT CPS LPCT5 SLD CPS LPCT LDT CPS LCCT5 SLD CPS LCCT LDT CPS SCCT5 SLD CPS SCCT LDT CP~ RHOS5 SLD G?C3 RHO8 LDT RAT5 SLD NRAT LOT wU~L.~ SLD QUAL LDT ....... NPHS5 SLD SSPU NPHi LDT PU DATA '~:~ :~e ENTRY BLOCKS -'~ · :~ ENTRY FORMA T SPEC I F I CA TYPE SIZE CODE 0 I 66 TION® Pag~ !4 :~.m:~ ENTRY BLOCK LEGEND TYPE DESCRIPTION 0 Terminator ( no morm mntrims ) SERVICE HNEM I D DEPT TENS DLLMSF GR DLLMSF ·CALI DLLMSF LLD DLLMSF LLS DLLMSF MSFL DLLMSF GR BHC DT 8HC SPHI 8HO TENS 8HC TENS LDT GR LDT CALl LDT FFDC. LDT NFDC LDT FCNL LDT NCNL LDT LSDP LDT CUPE LDT SSDP LDT DPHI LDT DRHO LDT PEF LDT FSLD LDT NSLD LDT LPCT LDT LCCT LDT SCCT LDT RHOB LDT NRAT LDT QUAL LDT NPHi LDT DATA FORMAT CiFiCATiON 8LOCKS ,.,m. SERVICE ORDER # AP1 APl AP1 AP1 FILE UNiT LOG TYPE ~S HOD 366610 FT 0 0 0 0 0 3666i0 LBS 11 0 0 0 i 366Gi0 GAPi ii 54 I 0 i 366610 IN ii 24 2 0 i 3666i0' OHMM ii 220 iO 0 i 366Gi0 OHMM ii 220 6 0 i 366Gi0 OHHH ii iA 4 0 i 3666i 0 GAPI 60 54 1 0 i ~66Gi 0 US?F 60 8 32 0 i 3GG61 0 PU GO i 22 7 0 i 366G t 0 LBS 6 0 0 0 0 i 766G10 LB~ 45 0 0 0 i 7GGGiO GAPi 45 54 i 0 i 3GGGiO iN 45 24 ~'~ 0 i ~66G i 0 CPS 45 98 2 0 i 36661 0 CPS 45 98 i 0 i 3GGGiO U~ 45 78 ~GGGiO CPS 45 7'8 366610 CHAN 45 0 0 O 36GGtO CPS 45 0 0 0 ~ 0 0 0 3666i0 PU 45 i22 i2 0 i 366Gi 0 G?C3 45 i O0 i , 0 ~6GGi.O B/EL 45 O O 0 i ~G6G!O CPS 45 0 0 O i ~GGGiO CPS 45 0 0 0 3666i0 CPS 45 O 0 0 3G6GlO CPS 45 0 0 0 i ~66Gi0 CPS 45 0 0 0 ~66Gi0 .G?C~ 45 94 i O i ~666i0 45 i64 ~GGGlO 45 O ~666~8 PU 45 i~ oPECIFICA PRC SiZE LVL SHPL 4 0 i 4 0 i 4 0 i 4 0 4 0 i 4 0 i 4 0 i 4 0 1 4 0 i 4 0 i 4 0 i 4 0 i 4 0 4 0 i 4 0 i 4 0 1 4 0 i 4 0 i 4 0 4 0 4 0 i 4 0 4 0 4 0 i 4 0 i 4 0 i 4 0 i 4 0 1 4 0 i 4 0 i 4 0 4 0 i 4 0 TIONS 68 68 68 68 68 68 68 68 . -- 68 68 68 68 68 68 68 68 68 68 68 68 ~8 PROCESS iNDiCA;uK~ 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O0000O O00OO0 000000 000000 000000 000000 000000 000000 000000 000000 OOO000 000000 O000OO OOO000 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 000000 000000 0~0000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 080000 000000 000000 000000 000000 000000 000000 000000 P .a g e: 'i 5 DA TA RECORDS DEPT TENS GR CALt LLD LLS HSFL GR DT SPHi TENS TENS GR CAL FCNL NCNL LSD.P CUPE FSLD NSLD LPCT LCCT ~.L:T RHOB NRAT QUAL NPH i P~g~ 16 11~' . , , -99 -999.250 -999.250 8~8 500 =999,250 -999,250 -999 250 -999 250 9,250 -999,250 -999.250 -999,°- ~O 3~i~,000 O OOO O 000 0 OOO 0000 0,000 0,000 iii,600 1.533 ii2.i30 -999,250 -999.250 -999,250 ii967,404 27797,i09. i666,000 3420,000 20265,000 -999,250 0.000 -999.250 i.743 11768,500 4193,000 33,000 10,510 242i.027 1.758,314 -999,250 -999,250 -999,250 431.7,000 35,700 1i,870 47,600 156.i00 111,840 5,042 1i2,430 6@,207 50699,008 J3651,109.' 9494,000 17752,000 24694,000 1.522 61,780 2.564 O,OOO .008 _.~49 -999,25 0 0.000 2.425 .7.7'3_8 1668,500 4154,000 131.400 9,2i0 8.375 -999,250 -999. 250 -999. 250 4470,0.00 i 30; 600 87.'300 205,500 11 1 , 0.70 , 663 t i 2 , 240 0069,305 23442,270 7i i , 000 I572. 000 14i6._7. 000 30,530 7,551 9,620 -,729 2.659 i2.503 0.000 .059 2,442 -999.250 0,000 i,965 1.063 1568,500 4i64,000 t01.300 9, I70 ~ ~ ,858 --999.25'0 -999,250 -999,250 4274. 000 i OS. 000 J90,500 334,400 iii .3i0 .965 ii2,500 7870.455 .22080,062 1 002,000 21 07, OOO i 5856. 000 24.620 10,257 9.520 2,538 2.603 12. 050 0.000 ,034 i .8i4 -999.250 O, 000 ,.';. , 5ltU i. 048 11468,500 4085,000 105,400 9.970 6,095 .... 999.250 -999,250 -999,250 4230,000 i08,500 93.800 220,000 lil,4iO ,760 i12,600 7655,974 2685~,426 8Ji,OOO 225i.000 i9649,000 34,960 I 1~68,500 .7959,000 56,100 8,490 --999,250 -999 . 250 -999. 250 3977, 000 3J5,500 447,200 i i i ,280 i ,205 1042;~,i60 22855,941 12:36,000 2i64.000 ~9.400 28 50,600 J i2.590 i 5t¢,4 000 5,559 I0,340 i,i29 2,627 24,660" 9,010 i0,205 2.477 5.129 O.O00 , OE.,8 2,440. 18,880 0.000 .044 i.464 -999.250 0,000 2,764 -999,250 0,000 i,965 i.097 DA TA RECORD'-"' ~M; TENS GR CALl LLD LL.S MSFL GR DT SPH i TENS TENS GR CAL i P P L:~u NFDC FCNL NCNL LSDP CUPE t~ :~ or-' DPH i DRHO ~'~P FSLD NSLD LPCT LCCT ~uC ~ RHOE: NRAT QUAL NPH i Pagm i7 11268.500 7;3.50O 3'70.500 885t.i46 17.759 3775.000 i3.4i8 5i4.200 2;3659.i80 125,000 ;3586.000 11i.290 1000,000 8. 580 ._.,.-i'"'. 211 36 . 813 8 . 630 ;3869. 000 i28. i O0 9. 000 O. 000 ,970 t i 2. 530 5,853 .042 2650. 000 1~'-''~'~, ~.~,;. 000 o_. 548 i . 407 t 03,600 O,OOO 3,45.'3 i, 08i ii168.500 77.280 i02.700 9204.490 35.820 3976,000 16.i92 22i,600 237i3,754 i26,300 9,770 7.482 4,898 8,072 'i27,700 ;3625.000 4i52,000 123,000 i0,300 0,000 0,000 110,970 .643 ii2.370 3,458 .080 5.5z.~ 622.000 i465,000 i4330,000 2.589 2.305 ,996 I 1 068,500 94,300 '75,500 9057, ;3 i ,'3 33.430 38'08.000 29.0i0 i94.400 23550,496 ii2.800 , 3538.O00 iii,OOO i093.000 i2.2i0 i9,907 26,424 3830,000 i37.i00 i2,490 1,002 ii2,480 8,028 2657.000 i7i22,000 2.5i2 ~7,920 O.OOO -.012 2,642 i43. i00 0,000 4,935 ,999 10968.5'00 -999.250 -999.258 -999.250 -999.250 -999.250 -999.250 i63.800 65,200 7,i96 3547,000 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -'~,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 10868.500 80,000 --999.250 .-999,250 -99'9,250 -999,250 -999... .250 -999,.=°50 -999,250 -999. ,250 -999,250 i41 ,gO0 i8 29i 3508 OOO _-q- o 99 25 -999,z~0 -9~9 . ~.~ 50 -999 2~0 - 9 O '- -9~g 250 g" ~9 ~ -99 , .... -.~9 250 , - ,~50 -999,250 9 250 -999,250 -999,250 -999,250 -999~250 -999,250 -999,250 -999,250 -999,250 . --999.250 0768,500 -999,250 -999,250 -999,v-' . ,. . , , -- ._bu -999 250 -999 250 -999 250 b.:'~, i00 ..4 .......... i O0 58 8,46 ..-',479 000 --~. 250 --999 250 ,-999 250 -~'~' ~ ~b'~O -gg'g,~..,O'~:' o=. -'~99 250 9q o 0 ~"' -999,=~,0 -999,250 -999,250 . , -9. . ,~5 -999,250 --~,250 -999,250 -999 250 -999 250 -'a'~g 250 -q~'~ °50 .... 999 , , ~:.,O -999 :~50 -'999 ~0 -'ag9 2.58 -999 DEPT DT FCNL FSLD NPHi TENS SPHi NCNL NSLD GR TENS LSDP LPCT OATA CALl TENS CUPE LCCT RECORDS LLD GR SCCT LLS CALl DPHi RH08 MSFL DRHO HRAT NFDC PEF QUAL P.ag~ i0668.500 -999.250 -999,250 -999.250 59.520 -999.250-999.250 -999.250 3430,000 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -~:~. ~'bO -999. 250 -999.2.50 -999. 250 70,800 -999,250 -999,250 -999,250 ~*** FiLE TRAILER ** :+:~ File name: &GSF01.002 Haximum length: 1024 TRA 1LER RECORDS oervi,ze nam~ File type~ LO Next Version ~ile: Oate: ~9 EOF mm. ** EOF *'**