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186-086
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,881 9,451 Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 3,810psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Casey Morse Contact Email:Casey.Morse@hilcorp.com Contact Phone:(907) 777-8322 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4/18/2025 11,748'11,748' 4-1/2" 10,287' Hydr packer & SSSV 6,301 (MD) 5,910 (TVD) & 497 (MD) 497 (TVD) Perforation Depth MD (ft): 8,575' - 8,917' 9,482' 7" 7,722 - 7,986' 8,434'9-5/8" 9,482' 20" 13-3/8" 779' 1,900' MD 3,090psi 779' 1,900' 779' 1,900' Length Size Proposed Pools: L-80 & J-55 TVD Burst 8,500 6,330psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018730 187-086 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20391-00-00 Hilcorp Alaska, LLC Trading Bay Unit M-25 AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Other: G/L Completion McArthur River Middle Kenai Gas Same 10,396 8,470 7,642 2,866psi See schematic CO 228A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:41 am, Apr 07, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.04.04 15:22:41 - 08'00' Dan Marlowe (1267) 325-206 A.Dewhurst 08APR25 DSR-4/7/25MGR08APR25 *BOPE pressure test to 3000 psi. Annular to 2500 psi. 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.08 13:20:47 -08'00' 04/08/25 RBDMS JSB 040925 RWO Tubing Swap Well: M-25 Well Name:M-25 API Number:50-733-20391-00-00 Current Status:Gas Producer Leg:Leg #B1(NW corner) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:187-086 First Call Engineer:Casey Morse (603) 205-3780 (c) Second Call Engineer:Eric Dickerman (907) 564-4061 (o) Maximum Expected BHP:3,685 psi @ 8,189’ TVD 0.45psi/ft to deepest perf Max. Potential Surface Pressure: 2866 psi Using 0.1 psi/ft Brief Well Summary M-25 was converted from a shut-in oil well to a Middle Kenai Gas producer in 2024 / 2025 as part of Sundry 324-420 and 325-032. Much of the well’s earlier history is detailed in the sundry package for 324-420. The well was successfully recompleted to the Middle Kenai Gas Pool and was online producing gas with high water rates. During a procedure to shut off the water producing zones with a coiled tubing cement squeeze, TxIA communication was observed. Several limitations in the wellbore prevent conclusive diagnostics, but indications point to a failed packer. The goal of this project is to pull the current completion, recover some of the stuck coil, run a new gas lift completion, re-perf the F3 zone, and add perfs uphole in the Middle Kenai Gas Pool. Pertinent wellbore information: x Max inclination above 9450’ MD: 43 degrees at 8100’ MD x 2024 RWO for Gas Recomplete o Fished stuck ESP / cable down to o Ran CIBP and set at 9,216’.Pressure test 7” casing to 2150 psi for 30 min on 11/17/24 – good. Dump bail cement on top of CIBP. Tag cement at 9,181’. o Run GL completion. Set 7" packer at 6,301’ with 3560 psi hold for 30 minutes on chart. o Perf F9 and F8 sands. High water rates ~2000 bpd, minimal gas. Set expandable plug at 8,960’. Dump bail cement on top. Tag cement at 8,930’. o Perf F7 and F4. Low gas production, low water production (150 mcfd, 50 bwpd). o Prep to shoot F3. Water rates increased to 2000 bpd while prepping guns. Move ahead with perfs. Gas increased to 1.5MMcfd, water stayed at ~2000 bwpd. Run spinner survey looking for water, data inconclusive. o Prep for coil cement job. Tag at 8,926’, fluid pack reel, tag second time at 8,950’ CTM. P/U to 8,945’ and pump 5 bbls 14 ppg cement on top of expandable plug. After 0.9 bbl cement pumped, start POOH and coil pulling heavy. Shut down pump with 1 bbl of cement still in coil, and P/U ~20’ off bottom. Coil parted 135’ from surface. o Begin coil recovery plan.While performing well kill operations, noticed TxIA communication. Able to circulate FIW down tubing, up IA. RWO Tubing Swap Well: M-25 o Tag cement inside coil at 8,470’ SLM. Jet cut coil at 8,338’. Unable to pull free. Jet cut coil at 6,332’ and coil came free. o Swapped orifice – still have TxIA. Changed orifice to dummy valve – IA still tracks down to header pressure with tubing. Run 3 temperature surveys – possible indication of packer failure – data inconclusive. o During diagnostics, identified cut coil was above the X-nipple at 6,315’ instead of 6,332’ per eline. Also identified tight spot in tubing at 2,448’. Unable to pass a 3.81” OD packoff plug without locking plug in the open position. 3.67” OD drifts ok. Unable to set PX plug or packoff to test tubing. Pools: x Top Middle Kenai G Oil Pool: 9,700’ MD / 8,612’ TVD x Top Middle Kenai Gas pool: 1,412’ MD / 1,412’ TVD Pressures: x 2024 drill well M-23 obtained a 12.5ppg FIT at 3714’ TVD x The deepest open / proposed perf in M-25 at 8,620’ MD (7,756’ TVD) o 8.4 ppg * 0.052 * 7,756 ft TVD = 3,388 psi o 0.1 psi/ft * (7,756 ft TVD - 5,000 ft TVD) = 276 psi o 3,388 psi – 276 psi = 3,112 psi (at 5,000 ft TVD) o 3,112 psi / 0.052 / 5,000’ TVD = 12.0ppg x With highest observed pressures of 8.4 ppg in the deepest sands, we can perf up to 5165’ MD (5000’ TVD) in M-25 and stay under the 12.5ppg FIT Cement: x 9-5/8” primary job (1988) o 12-1/4” hole cemented with 1800sxs of 13.0ppg Trinity lightweight cement lead followed by 1000sxs of 15.8ppg class G tail cement o Full returns during cement job. o 9/3/88 CBL shows ToC at 2150’ MD. x 7” Tie back (1989) o Ran to cover up light wall loss in 9-5/8” down deep, and overshot/new 9-5/8” up shallow o Cemented with 1200sxs. o Full returns and saw cement back to surface.ToC at surface in M-25 at 8,620’ MD (7,756’ TVD) RWO Tubing Swap Well: M-25 RWO Procedure: 1. MIRU Hilcorp Rig #404 2. Circulate to kill well: a. Work over fluid will be filtered inlet water FIW (8.4ppg) or heavier b. Ensure any wellbore fluids are fully displaced with KWF via circulation and bullheading c. Tubing volume: 116 bbls d. IA volume from end of tubing: 195 bbls e. Note: live gas lift valves in the top 3 stations 3. Set BPV/TWC, ND tree, NU BOP a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low / 3,000psi High / 2,500psi Annular c. BOP’s will be closed as needed to circulate the well d. Hilcorp’s 13-5/8” RWO BOP stack will be used. This stack has been in service recently with rig #404 RWO’s e. Test to cover 3-1/2” workstring, 2-7/8” workstring, and 4-1/2” tubing 4. BOLDS and unseat hanger 5. POOH with 4-1/2” tubing a. Note: coil may come to surface stuck inside the bottom portion of the tubing tail. 6. PU workstring with OD snipper tool for coil recovery. 7. RIH and fish coil tubing as deep as practical. 8. Tag cement inside 7” to confirm cement depth. 9. MU 7” cleanout assembly (if necessary) and clean 7” tie-back as deep as practical, targeting below the F3 perfs ±8600’ MD. 10. Contingency: RIH and set 7” CIBP to isolate the perfs below the F3 a. Plan to set as deep as possible, either above the F7 (target set depth ±8,850’ MD) or F4 (target set depth ±8,600’ MD) is acceptable based on wellbore conditions. b. May be set on EL or workstring, TBD 11. MU 4-1/2” completion a. SSSV at ±500’ MD b. GLM’s and jewelry as needed c. Live GLV’s will be run d. Packer at ±7,300’ MD e. Tubing Tail ±7,350’ MD 12. RIH and land completion 13. CMIT-TxIA to 2000psi (charted) 14. MIT-T to 2000psi (charted) 15. ND BOP, NU tree and test 16. RDMO rig #404 E-Line Perf procedure 1. MIRU E-line and pressure control equipment RWO Tubing Swap Well: M-25 2. PT lubricator to 250psi low / 3000psi high 3. Perforate Middle Kenai Gas Pool sands from ±7,350 - ±8,585’ MD (±6,790’ - ±7,730’ TVD) per RE/Geo 4. RDMO EL Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram (no change) 4. RWO BOP Drawing 5. RWO Fluid/Flow Diagrams 6. RWO Sundry Change Form Updated by CDM 03/26/25 SCHEMATIC Steelhead Platform Well: M-25 Last Completed: 01/09/25 PTD: 187-086 API: 50-733-20391-00-00 1 3 2 5 4 12 G HK 13 X 14 A B C PBTD = 8,470’ RKB to TBG Hanger: 72.0’ RKB to MLLW: 163’, RKB to mudline: 346’ TD = 11,881’ WF 10 8 9 X 6 11 X X 7 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20 91.5# X-56 RL-4C Surf 779’ 13 3/8” 61# K-55 BTC 12.515 Surf 1900’ 9 5/8” 43.5# N-80 BTC 8.755 Surf 1,451 9 5/8” 43.5# N-80 BTC 8.755 1,451' 2,941' 9 5/8” 47# N-80 BTC 8.681 2,941' 9,482' 7’ Tie-back 29# N-80 BTC 6.184 Surf 9238’ 7” Liner 29# N-80 BTC 6.184 9238’ 11,748’ Tubing: 4-1/2" 12.6 L-80 IBT Non Mod 3.830 Surf 6,323’ 4-1/2” 12.6 J-55 8rd 3.830 6,323 8,500’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 497’ 497’ 3.830 SSSV 2 1,584' 1,584' ECP 3 6,301’ 5,910’ 3.830 7" x 4-1/2" Hydratrieve Packer 4 6,317’ 5,924’ 3.810 X-Nipple 8,500’ 7,665’ 3.830 Mule Shoe 5 8,960’ 8,019’ - Spiral plug w/ 33 gal cement. Tag @ 8,930’ ELM. Tag @ 8,950’ CTM and spot approx. 4 bbl cement on top 6 9,216’ 8,221’ - CIBP:(TOC) 9181’ ELMD (12/8/24) A 6,315’ 5,922’ 1.594 Top of CT fish B 8,470’ 7,642’ - Tag cement inside CT @ 8470’ SLM C 8,925’ 7,992’ End of 1.75” CT string CURRENT OPEN PERFORATION DETAILS Zone Top Bottom Top Bottom Length Date Status(MD)(MD)(TVD)(TVD) F3 8,575’ 8,585’ 7,722’ 7,729’10’ 1/9/25 Open F4 8,614’ 8,620’ 7,751’ 7,756’6’ 12/30/24 Open F7 8,887’ 8,917’ 7,962’ 7,986’30’ 12/27/24 Open F8a 8,974’ 8,994’ 8,030’ 8,046’20’ 12/20/24 Isolated 12/23/24 F8c 9,033’ 9,049’ 8,077’ 8,089’16’ 12/20/24 Isolated 12/23/24 F8d 9,070’ 9,086’ 8,106’ 8,119’16’ 12/19/24 Isolated 12/23/24 F9a 9,125’ 9,145’ 8,149’ 8,165’20’ 12/11/24 Isolated 12/23/24 F9b 9,161’ 9,175’ 8,178’ 8,189’14’ 12/8/24 Isolated 12/23/24 CEMENT DETAILS 20”26” hole: Cemented with 725sxs 12.5ppg lead cement, followed by 500sxs 15.8ppg class G tail. Performed 400sxs top job on 30” x 20” annulus. ToC assumed to surface 13-3/8" 17-1/2” Hole (underreamed): Cemented with 557sxs 12.5ppg lead-1 cement, followed by 500sxs of 13.5ppg lead-2 cement, finished with 425sxs 15.8ppg tail cement. Saw 130sxs back to surface. ToC at surface. Remedial squeeze activity conducted in 1988 behind 13-3/8”. See file 9-5/8”12-1/4” Hole: Cemented with 1800sxs of 13.0ppg Trinity lightweight cement lead followed by 1000sxs of 15.8ppg class G tail cement. Full returns during cement job. 9/3/88 CBL shows ToC at 2150’ MD. 7” tie back Ran 6/11/89 to cover up light wall loss 9-5/8” down deep, and overshot/new 9-5/8” up shallow. Cemented with 1200sxs. Full returns and cement back to surface. ToC at surface GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,202’ 2,202’ 3.830 BK 16 Dome 773 11/18/24 2 3,704’ 3,703’ 3.830 BK 16 Dome 748 11/18/24 3 5,046’ 4,908’ 3.830 BK 16 Dome 723 11/18/24 4 6,252’ 5,689’ 3.830 Gen 2 Mod 24 Orifice 11/18/24 Updated by CDM 03/26/25 SCHEMATIC Steelhead Platform Well: M-25 Last Completed: 01/09/25 PTD: 187-086 API: 50-733-20391-00-00 ISOLATED PERFORATION DETAILS Zone Top Bottom Top Bottom Length Date Status(MD)(MD)(TVD)(TVD) G-1 9810’ 9859’ 8705 8746 49’ Isolated 11/17/24 G-2 9872’ 9900’ 8757 8780 28’ Isolated 11/17/24 G-3 9960’ 9998’ 8830 8862 38’ Isolated 11/17/24 G-4 10,026’ 10,065’ 8885 8918 39’ Isolated 11/17/24 G-5 10,125’ 10,202’ 8968 9032 77’ Isolated 11/17/24 HB-1 10,365’ 10,395’ 9166 9191 30’ Isolated 11/17/24 HB-2 10,425’10,445’9216 9232 20’ Isolated 11/17/24 HB-3 10,545’10,575’9314 9339 30’ Isolated 11/17/24 HB-4 10,610’10,720’9367 9457 110’ Isolated 11/17/24 HB-5 10,760’10,804’9490 9526 44’ Isolated 11/17/24 West Foreland is Isolated below a bridge plug and 15’ of cement on top Fish/Fill Information: 9,203’ ELM 11/16/24 – Tag TOF (~157’ ESP) 9,451 Ran 2.70” GR in 9/04, could not get through packer at 9451’ due to superbands. +/-17 ESP Superbands dropped in 2001 conversion (1 ¼” wide) 10,835 E-line tag (w/ 2” perf gun) @ 10,835’ in 2/2001. 10,897 Tag Fill or junk w/ S-line @ 10,897' 1996 *Two fishes; (1) Tong Die (2) 14’ 2/18” Enerjet Strip (depth unknown) ABANDONED JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 7 9,218’ 8,223’ 8 9,451’ 8,409' 2.992 Baker 3H (SB-3) Packer w/ Millout Extension 9 9,471’8,425'2.75 Otis “X” Nipple 10 9,504’ 8,452' 2.992 Baker WLEG 11 10,862’ 9,572' N/A Thru-tbg bridge plug w/ 13.7’ of cement on top 12 10,909’ 9,610' 2.992 Baker FB-1 Packer w/ Millout Extension 13 10,928’9,625'2.750 Otis ‘X’ Nipple 14 10,962’ 9,653' 2.992 Baker WLEG Updated by CDM 03/26/25 SCHEMATIC Steelhead Platform Well: M-25 Last Completed: 01/09/25 PTD: 187-086 API: 50-733-20391-00-00 1 3 2 5 4 12 G HK 13 X 14 AB PBTD = 9,181’ RKB to TBG Hanger: 72.0’ RKB to MLLW: 163’, RKB to mudline: 346’ TD = 11,881’ WF 10 8 9 X 6 11 X X 7 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20 91.5# X-56 RL-4C Surf 779’ 13 3/8” 61# K-55 BTC 12.515 Surf 1900’ 9 5/8” 43.5# N-80 BTC 8.755 Surf 1,451 9 5/8” 43.5# N-80 BTC 8.755 1,451' 2,941' 9 5/8” 47# N-80 BTC 8.681 2,941' 9,482' 7’ Tie-back 29# N-80 BTC 6.184 Surf 9238’ 7” Liner 29# N-80 BTC 6.184 9238’ 11,748’ Tubing: 4-1/2" 12.6 L-80 IBT Non Mod 3.830 Surf 6,323’ 4-1/2” 12.6 J-55 8rd 3.830 6,323 8,500’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 ±500’ ±500’ SSSV 2 1,584' 1,584' ECP 3 ±7,300’ 7" x 4-1/2" Packer 4 ±7,305’ X-Nipple ±7,350’ Mule Shoe 5 8,960’ 8,019’ Spiral plug w/ 33 gal cement. Tag @ 8,930’ ELM. Tag @ 8,950’ CTM and spot approx. 4 bbl cement on top 6 9,216’ 8,221’ CIBP: ToC at 9181’ ELMD (12/8/24) A ±8,600’ 1.594 Top of CT fish B TBD TBD - Tag cement inside 7” casing PERFORATION DETAILS Zone Top Bottom Top Bottom Length Date Status(MD)(MD)(TVD)(TVD) ±7,350 ±8,585 ±6,790 ±7,730 Proposed F3 8,575’ 8,585’ 7,722’ 7,729’10’ 1/9/25 Open F4 8,614’ 8,620’ 7,751’ 7,756’6’ 12/30/24 Open F7 8,887’ 8,917’ 7,962’ 7,986’30’ 12/27/24 Open F8a 8,974’ 8,994’ 8,030’ 8,046’20’ 12/20/24 Isolated 12/23/24 F8c 9,033’ 9,049’ 8,077’ 8,089’16’ 12/20/24 Isolated 12/23/24 F8d 9,070’ 9,086’ 8,106’ 8,119’16’ 12/19/24 Isolated 12/23/24 F9a 9,125’ 9,145’ 8,149’ 8,165’20’ 12/11/24 Isolated 12/23/24 F9b 9,161’ 9,175’ 8,178’ 8,189’14’ 12/8/24 Isolated 12/23/24 CEMENT DETAILS 20”26” hole: Cemented with 725sxs 12.5ppg lead cement, followed by 500sxs 15.8ppg class G tail. Performed 400sxs top job on 30” x 20” annulus. ToC assumed to surface 13-3/8" 17-1/2” Hole (underreamed): Cemented with 557sxs 12.5ppg lead-1 cement, followed by 500sxs of 13.5ppg lead-2 cement, finished with 425sxs 15.8ppg tail cement. Saw 130sxs back to surface. ToC at surface. Remedial squeeze activity conducted in 1988 behind 13-3/8”. See file 9-5/8”12-1/4” Hole: Cemented with 1800sxs of 13.0ppg Trinity lightweight cement lead followed by 1000sxs of 15.8ppg class G tail cement. Full returns during cement job. 9/3/88 CBL shows ToC at 2150’ MD. 7” tie back Ran 6/11/89 to cover up light wall loss 9-5/8” down deep, and overshot/new 9-5/8” up shallow. Cemented with 1200sxs. Full returns and cement back to surface. ToC at surface GAS LIFT MANDRELS - TBD STA MD TVD ID Type Port Valve Psc Date 1 2 3 4 Updated by CDM 03/26/25 SCHEMATIC Steelhead Platform Well: M-25 Last Completed: 01/09/25 PTD: 187-086 API: 50-733-20391-00-00 ISOLATED PERFORATION DETAILS Zone Top Bottom Top Bottom Length Date Status(MD)(MD)(TVD)(TVD) G-1 9810’ 9859’ 8705 8746 49’ Isolated 11/17/24 G-2 9872’ 9900’ 8757 8780 28’ Isolated 11/17/24 G-3 9960’ 9998’ 8830 8862 38’ Isolated 11/17/24 G-4 10,026’ 10,065’ 8885 8918 39’ Isolated 11/17/24 G-5 10,125’ 10,202’ 8968 9032 77’ Isolated 11/17/24 HB-1 10,365’ 10,395’ 9166 9191 30’ Isolated 11/17/24 HB-2 10,425’10,445’9216 9232 20’ Isolated 11/17/24 HB-3 10,545’10,575’9314 9339 30’ Isolated 11/17/24 HB-4 10,610’10,720’9367 9457 110’ Isolated 11/17/24 HB-5 10,760’10,804’9490 9526 44’ Isolated 11/17/24 West Foreland is Isolated below a bridge plug and 15’ of cement on top Fish/Fill Information: 9,203’ ELM 11/16/24 – Tag TOF (~157’ ESP) 9,451 Ran 2.70” GR in 9/04, could not get through packer at 9451’ due to superbands. +/-17 ESP Superbands dropped in 2001 conversion (1 ¼” wide) 10,835 E-line tag (w/ 2” perf gun) @ 10,835’ in 2/2001. 10,897 Tag Fill or junk w/ S-line @ 10,897' 1996 *Two fishes; (1) Tong Die (2) 14’ 2/18” Enerjet Strip (depth unknown) ABANDONED JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 7 9,218’ 8,223’ 8 9,451’ 8,409' 2.992 Baker 3H (SB-3) Packer w/ Millout Extension 9 9,471’8,425'2.75 Otis “X” Nipple 10 9,504’ 8,452' 2.992 Baker WLEG 11 10,862’ 9,572' N/A Thru-tbg bridge plug w/ 13.7’ of cement on top 12 10,909’ 9,610' 2.992 Baker FB-1 Packer w/ Millout Extension 13 10,928’9,625'2.750 Otis ‘X’ Nipple 14 10,962’ 9,653' 2.992 Baker WLEG Steelhead Platform M-25 Wellhead Steelhead Platform M-25 20 x 13 3/8 x 9 5/8 x 7 x 4 1/2 Adapter, Cactus-EN-CCL, 11 5M stdd x 4 1/16 5M, w/ 2- 1'’ npt control line exits Tubing spool, FMC-TC-BG, 11 5M x 11 5M, w/ 2- 2 1/16 5M SSO 13 3/8'’ 7'’ Starting head, Gray CWC, 13 5/8 3M x 133/8'’ SOW, w/ 2- 2 1/16 5M SSO Tubing spool, FMC-TC-BG, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO 4 ½’’ 9 5/8'’ Attachment spool, FMC-TC, 11 5M studded bottom x 11 5M FE top Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim BHTA, Bowen, 4 1/16 5M FE x 7'’ Bowen quick union top Valve, Wing, SSV, WKM-M, 4 1/16 5M FE, w/ Air operator, EE trim Tubing hanger, Cactus-EN- CCL, 11 x 4 ½ EUE 8rd lift and susp, w/ 4'’ type H-BPV profile, 2- ¼npt control line port, 6 ¼ EN Valve, Master, WKM-M, 4 1/16 5M FE, HWO, EE trim Valve, Swab, WKM-M, 4 1/16 5M FE, HWO, EE trim BOP Stack Rig 404 Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.26' Riser 13 5/8 5M FE X 13 5/8 5M FE Spacer spool 13 5/8 5M FE X 11 5M 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 4 1/16 5M EFO 4.30'Hydril GK 13 5/8-5000 DSA 4 X 2DSA 4 X 2Spacer spool 13 5/8 5M X 13 5/8 5M HILCORP ALASKA, LLC SwacoSuperchokeBlooey LineTo Gas BusterInlet Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Trading Bay Unit M-25 (PTD 187-086)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 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. / ~) ~(~_~ Well History File Identifier Organization (done) A Two-Sided RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES' (~ NOTES: ORGANIZED BY:~BREN VINCENT SHERYL MARI~ LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other [] By: Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYI_ MARIA LOWELL DATE: Isl PAGES' ~ A (at the time of scanning) SCANNED BY; ~REN VINCENT SHERYL MARIA LOWELL DATE: ReScanned (done) RESCANNED BY] BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: PAGES: (~ O~ Quality Checked (done) RevlNOTScanned.wpd 7 • ConocoPhillips December 11, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~~~ U~ C: ~ ~ ~Q~f ~~~ ~~.~ Subject: Well Completion Reports for 3N-14 and 3N-14A Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent plug and abandonment of 3N-14 and the sidetrack operations of 3N-14A. If you have any questions regarding this matter, please contact me at 265-6830 or Jason Brink at 265-6419. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ^~ ~k ~~~! c ~-~" ,,~ .: ~~~5~~~ .`~ + .. ~ ~- ni'+G~'iL7twg~a ~ ~ EC~~~rE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~C Z ~ 2a~7 WELL COMPLETION OR RECOMPLETION R~P,~,~~~~J,~n BOG 1a. Well Status: Oil ^ Gas Plugged ~ Abandoned Q Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. W ICI ss: Devel~me~©f Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: September 26, 2007 12. Permit to Drill Number: 186-086 % 307-290 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 27, 1986 13. API Number: 50-029-21589-00 4a. Location of Well (Governmental Section): Surface: 1561' FSL, 80' FEL, Sec. 29, T13N, R9E, UM f 7. Date TD Reached: May 4, 1986 14. Well Name and Number: 3N-14 Top of Productive Horizon: 1299' FSL, 1685' FWL, Sec. 28, T13N, R9E, UM 8. KB (ft above MSL): r0$ /fj~ ~,y , Ground (ft MSL): 'W2' .Field/Pool(s): Kuparuk River Field Total Depth: 1248' FSL, 2029' FWL, Sec. 28, T13N, R9E, UM 9. Plug Back Depth (MD + ND): 6082' MD / 5692' ND Kuparuk Oil Po01 4b. Location of Well (State Base Plane Coordinates): Surface: x- 518321 ~ y- 6013799 ~ Zone- 4 10. Total Depth (MD + ND): , 7460' MD / 6687 TVD 16. Properly Designation: ADL 25520 TPI: x- 520087 y- 6013542 Zone- 4 Total Depth: x- 520430 - 6013491 Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 2556 18. Directional Survey: Yes ^ No Q (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1720' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): no new logs 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 24" 238 sx CS II 10.75" 45.5# K-55 Surf. 2579' Surf. 2579' 13.5" 1150 sx AS III, 150 sx CI G w/ 100 sx CI G top job 7" 26# J-55 Surf. 7440' Surf. 6672' 8.5" 660 sx Class G, 175 sx AS I CIBP @ 6584' CTMD 23. Open to production or injection? Yes ^ No ~ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET none perforations plugged off 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTANDKIND OF MATERIAL USED bridge plug @ 6485' 11.5 bbls CI G 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abaondoned Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (cArr) 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ~ Sidewall Cores Acquired? Yes No r If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. c ~r~-~tA ~.o,-~ ~- ~ _i_. ~r:~,~ ~i NONE t ~~a.:.b Form 10-407 Revised 212007 COT ~ R~ IDE _~ 2D07 /~ ~ j ~ ~Cj.,O r~ ~_ ~ ~,.~' ~~y/~ 28. GEOLOGIC MARKERS (List all formations and mar ers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes 0 No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1720' 1720' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 6955' 6320' Base Kuparuk C 7008' 6359' Top Kuparuk A 7080' 6411' Base Kuparuk A 7235' 6524' N/A Formation at total depth: Kuparuk C 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 265-6419 Printed Name.. ~ Th mas Title: Drillino Team Leader l2 ~ ((t~®' Signature ~ - Phone ~~rG-~, 3~ Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. ~3N-14 Plu ged and Abandoned Summa 9 DATE Summary 9/21/07 Tagged @ 6616' SLM. Measured BHP @ 6613' SLM. 4084 psi. In progress. 9/22/07 PULLED DV FROM 6485' RKB. DRIFTED TBG WITH 2.29" BAR-BELL ASS'Y. 9/22/07 SET BAKER #028 CIBP MID ELEMENT AT 6610' RKB. OVERPULL SEEN AT 6635' AND DRAG TO 6620' RKB. PUNCHED TUBING WITH "SMALL" TUBING PUNCHER LOADED 4 SPF FROM 6602-6604' RKB. 9/23/07 DISPLACED AND RECOVERED APPROXIMATELY 150 BBL 12.2 BRINE. PERFORMED CMIT. PRESSURE TESTED TUBING TO 2400 PSI, 2500 PSI IA, AND 620 PSI. AFTER 15 MINUTES 1800 PSI TUBING, 1850 IA, 580 PSI OA. 9/26/07 Perform P&A cementjob, RIH to CIBP tag of 6584 CTMD, PU 10 ft, pump 11.5 bbls Class ~ G cement, PUH to 6485 CMD, Pump 20 biozan, PUH, F/P well, Turned over to S/L. 9/27/07 DRIFT TO 6105' SLM WITH 2.305" GAUGE RING.OBTAIN SAMPLE OF CEMENT WITH 1.75" SAMPLE BAILER.000LD NOT DRAW TBG DOWN BELOW 25 PSI.IA BUILDS 635 PSI IN 15 MIN.PULLED 1" DV FROM STA #6 @ 6107' RKB 9/27/07 STAND-BY FOR TUBING CUT 9/28/07 TUBING CUT AT 6082', 5 FEET BELOW COLLAR OF FIRST FULL JOINT ABOVE GLM #6 AT 6107' Change in procedure for 3N-14• Page 1 of 2 Maunder, Thomas E (DOA From: Greener, Mike R. [Mike.R.Greener@conocophillips.coml Sent: Wednesday, October 03, 2007 8:54 AM To: Maunder, Thomas E (DOA) Subject: RE: Change in procedure for 3N-14 (186-086) ~ ~~,t~~~ NOV '~ ~ 2~~7 3N-14 operations last 24 hrs. We have laid down the tubing and made a scraper run with the 4" DP. We have set the CIBP at 3,569'. They pressured tested everything above the CIBP to 3,000 psi. They are currently placing the lower rams back into the stack. and will perform a full blown test when done. Then we will go set our whipstock and mill our window. -----Original Message----- From: Maunder, Thomas E (DOA) {mailto:tom.maunder@alaska.gov] Sent; Tuesday, October 02, 2007 12:49 PM To: Greener, Mike R. Subject: RE: Change in procedure for 3N-14 {186-086) Mike, Thanks for the update on the change in plans. The Inspector had called me to inform me of the call from the rig. Good luck with the work. Tom Maunder, PE AOGCC From: Greener, Mike R. [mailto:Mike,R.Greener@conocophillips.comJ Sent: Tuesday, October 02, 2007 12:26 PM To: Maunder, Thomas E (DOA) Subject: Change in procedure for 3N-14 After tree on the 3N-14 was ND it was noted that the well head was 2.5' higher than what is normally rigged up on. The Rig bridge crane could not pick high enough to set the BOPS on the 7.0625 - Sk tubing flange as it is configured. The CPAI Co Rep called and informed the AOGCC of the problem. He explained the problem and asked if he could go ahead and drop out the bottom set of rams and use a DSA to make up to the tubing head. The well was in a work over condition which allowed that BOP configuration. 10/3/2007 Change in procedure for 3N-1 : Page 2 of 2 After picking up the tubing to confirm the cut the complete well was displaced with 131 KWM and the well is static. A 28 sx cement plug was placed on top of the tubing stub at +/- 6,082' MD. The tubing will be pulled from the well and laid down. The 4" AP will be picked up and RIH with a casing scraper and then stood back in the derrick. A CIBP will be run and set at +/- 3,550'. The tubing spool will then be replaced and the lower rams reinstalled in the BOP stack. A test plug will be run and the entire configuration will be retested. Mike Greener «Greener, Mike R..vcf» 10/3!2007 3N-14 P & A followup Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, September 27,20074:21 PM To: 'Schwartz, Guy L' Subject: RE: 3N-14 (186-086) P & A followup Guy, Adding the additional cement as you propose is prudent. Doing to tubing cut deep as planned allows the new cement to spotted in proximity to what has already been pumped. Call or message with any questions. Tom Maunder, PE AOGCC ---~-_._- From: Schwartz, Guy L [mailto:Guy.L.Schwartz@conocophillips.com] Sent: Thursday, September 27,20073:56 PM To: Maunder, Thomas E (DOA) Subject: 3N-14 P & A followup Tom, As per our conversation, if we do not get a positive pressure test on the IA & tubing cement plugs on 3N-14 we are planning on cutting the tubing with Eline and then circulating the well over to KWF. When the ST rig arrives we will then pull tubing up a stand and pump a balanced cement plug on top of the tubing stub. This will then be tested and a CIBP set above this for the whipstock kickoff. Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.l.schwartz@conocophillips.com SCANNED SEP 2 8 2007 ..~~.,..t.,....._L:'J...,.....a... 9/27/2007 . ~1f 1Ã\ 1fŒ (ffi ~ 1Ã\ ~1Ã\ ~ æ1Ã\ . A.I~SK& OIL A1Q) GAS CONSBRVATlON COMMISSION SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Guy Schwartz Wells Group Engineer ConocoLPhillips Alaska, Inc. PO Box 100360 Anchorage, AI{ 99510 ~ ~- O~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-14 Sundry Number: 307-290 Dear Mr. Schwartz: SCANNED SEP 232007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Dan T. Seamount Commissoner DATED this '21 day of September, 2007 Encl. . 1. Type of Request: Abandon 0/ Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 186-086 / 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21589-00 / 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 3N-14 - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25520,"ALK 2556 Kuparuk River Field I Kuparuk Oil Pool ./ RKB 68' / 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7460' ,/ 6687' 6659' 6105' 6615' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 110' 110' SUR. CASING 2537' 9-5/8" 2579' 2579' PROD. CASING 7405' 7" 7440' 6672' Perforation Depth MD ( 7104',7106', Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7108',7128'-7148',7155',7168'-7202' 6429',6430',6432',6446'-6461',6466',6475'-6499' 2-7/8" J-55 6929' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BROWN 'HB' pkr= 6859' Baker 'FVL' SSSV= 1790' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 - Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: September 15, 2007 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name Guv Schwartz. -£.... ß Title: Wells Group Engineer Signature ~~ 'y. .C¿(' Phone 265-6958 Date £-30-·0r ( / - ...... Commission Use Only Conditions of approval: N~fy Commission so that a representative may witness Sundry Number: /lXJ7' ;:;¡ C,D Plug Integrity ~ BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: 3,5,()()~\ ~O"?-\-éS~~ S"booq"em F"m Req";~ ø RBDMS 8Ft ? ,i 2007 App,,,,,ed bru f /7 APPROVED BY Date: l' ~1 COMMISSIONER THE COMMISSION Fo~'U~ ..ð("Revl ¥c:L.e6í2006 SUbm'¡1 DUR icate . . RECEIVED STATE OF ALASKA r _ _ ALASKA OILAND GAS CONSERVATION COMMISSION ~I)-\ SEP 1 1 2007 APPLICATION FOR SUNDRY APPROV ~kka Oil & Gas Cons, Cummíuion 20 MC 25 280 nRIGINAI qø~JJJ(!, ((flCP~:>GAJVf'//.Ó7 , ~~7 . . 3N-14 P & A Outline September 10, 2007 Summary: .¿ 3N -14 is a Kuparuk well with a long history of solids production. Several attempts have been made to FCO (fill cleanout) the well with poor results. Currently, there are rocks and sand filling the 7" casing and up into the 27/8" tubing which will not allow pumping cement into the existing perforations. Coil tubing has not been able to remove the solids below the current depth of 6652' md- rkb. The Plug and Abandon procedure will result in a CIBP set in the tubing just above the current fill level in the 2 7/8" tubing. The tubing will then be perforated and cement pumped into the tubing and IA leaving 100' of cement above the CIBP and packer annulus. The Sidetrack rig will then move in, pull tubing and repair an IC leak. Eline will then set a 7" CIBP at 3700'. A whipstock will 'be set on top of CIBP to sidetrack the well. ./ I co..cvr ~I c/h'¡ ';;l¡;- ~~ ~~ 1. RU SL and pull DV at 6485' .Drift tubing. Leave pocket 0IJ~J.1' Circ around to Mð I SW. - ~-\ ~~ 2. RU Eline. RIH and set 27/8" CIBP at 6630' md. V Cè <c~~~~\o" 3. Perform aCMIT against bridge plug. s~« ~\,,~R.. ~r- 4. Perforate tubing at 6600' with Eline 'ng puncher. 5. RU CT and lay in cement fr top ofCIBP to 6500' md. Open IA valve at surface and pump additional ce into backside for annular plug (4 bbls = 110'). Leave 100' of cement on top 0 P and POOH with Coil tubing. Pre-ri2 Wellwork: 6. Eline and cut tubing at 6300' Get cutter). Ri2 Work P & A comnonent: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MI/RU Doyon 141. Install blanking plug on top of the back pressure valve. 2. NU and test the II"x 5K BOPE to 250# 13500#. 3. Engage the 3-112" tubing with a spear. LID the tubing hanger and pull all 3-1/2" tubing. . . 4. Set storm packer. 5. N/D BOP's. Remove FMC Gen II tubing head and replace it with a II"x 3M x II"x 5M spool. 6. NU Bop's to the 11",5000 psi flange on the FMC Gen II system & test 250 psi & 3500 psi. 7. PU mill, casing scraper, and 4" DP and RIH to top of tubing stub. POOH. 8. RU wireline set a CIBP inside the 7" casing at +/- 3,700' MD based on casing collar depth. (Note: CIBP must be ~ 2.0' above a casing collar and ~ 20' below a casing ^ -< '-J ~ collar) POOH, RD SWS. Test 7" casing and CIBP to 3000 psi and hold for 15 min. "', ~ ~O- Test okay. ") ';:)<r5 (Ifnot contact Engineer- discuss will have to get packer and RIH and attempt to v-.~" find hole in casing.) 1 9. PU and RIH with Baker's "WindowMaster" whipstock system & window mill, bottom trip anchor, MWD, and UBHO on drill pipe from the derrick. Whipstock to be set on top ofCIBP set at 3,700' MD. r _..,.____,._.~~M__·_ _ Message . . Page 1 of2 Maunder, Thomas E (DOA) From: Schwartz, Guy L [Guy.L.Schwartz@conocophillips.com] Sent: Friday, September 21,200712:51 PM To: Maunder, Thomas E (DOA) Subject: RE: 3N-14 (186-086) P&A Tom, You are correct the PBay cheat sheet I was using had a 2 7/8"X 7" annular volume listed at .0379 bbl/ft. It should be .0303 bbllft. I will increase the cement pumped to get us to a 6400' TOC. (ie 14 bbls in the annulus) Thanks for catching that!!! I'll forward a copy later.... it has been around a long time!! Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.l.schwartz@conocophillips.com -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder®alaska.gov] Sent: Friday, September 21,200712:22 PM To: Schwartz, Guy L Subject: RE: 3N-14 (186-086) P&A Guy, I am reviewing the sundry for this well. Based on having cement up to a minimum of 6400' in IA after swap, it appears that about 14 bbls of cement should be pumped into the annulus rather than the 10 bbls proposed in step 9. This still leaves 6 bbls of cement to lay in the tubing which is 4 bbls more than the calculated capacity from the BP to 6400'. Please check your calculations and get back to me. Regards, Tom Maunder, PE AOGCC From: Schwartz, Guy L [mailto:Guy.L.Schwartz@conocophillips.com] Sent: Thursday, September 20,200711:24 AM To: Maunder, Thomas E (DOA) SUbject: RE: 3N-14 (186-086) P&A Tom, Decided to pump a bit more cement in order to get plenty in both the tubing and annulus. We can't pump into the fill so will be setting a plug in the tubing and circulating cement into the IA. and also leaving a cement cap on the plug, This procedure doesn't include the Drilling rig part of the P & A .(CIBP set and whipstock) See you later... have a good vacation. Guy 9/21/2007 Message . . Page 2 of2 Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.l.schwartz@conocophillips.com -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, September 20, 2007 8:04 AM To: Schwartz, Guy L Cc: Regg, James B (DOA) Subject: 3N-14 (186-086) P&A Guy, I am back from vacation. While I was gone, Jim indicated he had talked to you regarding the procedure for the P&A. As I understand the actual procedure is still in development. Do you have anything further regarding the procedure or the questions that Jim might have posed? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 9/21/2007 . . 3N-14 P & A Procedure 9-16-07 Background Information: This procedure documents the pre-rig work needed to P & A the original wellbore prior to the Sidetrack rig moving onto location. 3N-14 is a Kuparuk well with a long history of solids production. Several attempts have been made to FCO (fill cleanout) the well with poor results. Currently, there are rocks and sand filling the 7" casing and up into the 2 7/8" tubing which will not allow pumping cement into the existing perforations. Coil tubing has not been able to remove the solids below the current depth of 6652' md- rkb. The Plug and Abandon procedure will result in a clap set in the tubing just above the current fiJllevel in the 2 7/8" tubing. The tubing will then be perforated and cement pumped into the tubing and IA leaving 100' of cement above the clap and packer annulus. The Sidetrack rig will then move in, pull tubing and repair an IC leak. E-line will then set a 7" CIBP at 3700'. A whipstock will be set on top of clap to sidetrack the well. Operational Objectives: 1) Test wellhead packoffsl cycle LOS's 2) Set CIBP at 6650'md 3) CMIT 4) Lay in cement plug on top of plug and into IA (200' cement) 5) Cut tubing at 6200' md. (jet cut) API Number: Permit number: AFC Number: Wells Network #: 50-029-21589-00 P & A sundry XXXXX XXXXXXX Contacts: Guy Schwartz Marie McConnell Nelson/ Max Urish Wells Group Engineer DHD Engineer CPF3 Prod Eng. 3N engineer 265-6958 659-7043 659-7871 263- Wellbore: 16" conductor casing @ 110' 9 5/8 " 36# surface casing @ 2579' 7" 26# production casing @7440' 27/8" 6.5# tubing @ 6929' glschwa Page 1 9/21/2007 . . Capacities: 2 7/8" = .0058 bbl/ft 2 7/8" x 7" = .0379 bbllft Wellbore status: Fill in tubing at 6652' rkb (deepest FCO depth) DV pulled at 6485' 12.2 ppg brine in tubing and IA (w diesel cap) OA X IA communication -minor (replace IC packott on rig) T X OA leak (unkown depth - failed TIFL on 11/04) BHP = 4200 psi Procedure: 1. Run Halliburton 2 7/8" CIBP (*set depth approx.6640' md). Use SL deployed Micro-Smart setting tool (ETD) as per HAL rep on location. Drift tubing first to 2.29" and tag TD to verify PBTD. 2. Circulate well to Seawater and perform a CMIT against CIBP to 2500 psi. Circulate in diesel for freeze protection for top 2500'. Jumper at surface and equalize tubing and IA RD SL. 3. RU E-line and perforate tubing using tubing puncher charges just above CIBP at about 6635' md-rkb (5' above CIBP). RD Eline. 4. RU CTU. Notify AOGCC Inspector of date and time of operation. (659-2714 or pager 659-3607). 5. Run hardline from tubing connection to an open-top with an inline choke skid. 6. Rig up CTU and cement unit: Pressure test coil, BOP's and hardline to 3500 psi. 7. RIH with CTU with nozzle. 8. Batch mix 20 bbls of class G with following properties: Class G + 1.0 gps 0600G + 065 + Retarder (0800) to achieve 5 hrs working time. Wt: 15.8 ppg Yield: 1.16 cuftlsk Working Time: 5 hrs (inclusive of 1 hour surface time) glschwa Page 2 9/21/2007 · . ~\ \'-\ 'b~\7 ~Q"e:~\ ~íY'\~t 9. RIH to 6640' and open IA valve at surface. pump~bls cement taking returns 4 \ at surface. SIIA and lay in cement 1: 1 pulling uphole to 6400' md. (cement in backside will swap with packer fluid below the tubing perforations at 6640'md. There is 8.3 bbls IA volume from tbg perfs to top of packer) 10. Swap to biozan at 6400' md and jet out cèment while POOH. Freeze protect the last 2500 ft with diesel. 11. Wait 24 hrs for cement to set. Rig up SL to drift for "powerjet" cutter. Drift tubing to PBTD (TOC) with 2.29" gauge. ( Cement top may have moved from 6400' in tubing depending on V-tubing and swapping variables in the IA). 12. Pressure test cement plug to 1500 psi for 30 min. Record results. Test both IA and tubing. Verify if IA is open or not to the tubing. If not, pull DV at 6107' before Pressure testing and cutting tubing. (Notify AOGCC of the timing of the post cement plug tag and PT). 13. Perform Drawdown test by bleeding any tubing, IA and OA pressure to open-top tank. Tbg and IA should bleed to 0 psi. 14. Rig up E-line and jet cut 2 7/8" tubing at approx. 6200' md (below GLM #6) at 5' from tubing collar for standoff. POOH with E-line , verify the cutter operated properly and rig down E-line unit. (Chemical cutter not needed for this operation) 15. Set BPV and VR plug. Pull wellhouse and prep site for rig. Notify Wells group of well status. glschwa Page 3 9/21/2007 Gas Lift Valve i Gas Lift Valve :1 Gas Lift mAV~I~} 004750) Gas Lift Valve 4 OD4 Gas Lift '".,.,~~~} (3aS Lift M'!'7!-::'~ 'v Gas Lift '" ."yal~)' 004.750) Gas Lift~---~ Valve 8 005500) 'N P8R~ - ~-----~-- 002.875) PKR 006.151 NIP - O(2875) TUBING Parf -~ --- (7104-7104) ~-~-- ---~ - -- Parf ~ ,~ '0' -. ::=-~ = Parf ._.~.. ~-_._- (7155-7155) Perf -~-- ~--,~ (7168-7202) = = ~ Nell T pe. Lasl V 10: ~ Orit¡ - 0: 7480 ftKB us 7104 6429 .. 6429 ~~"'~v Jell! 1106 1106 6431 6431 -- 0 1 711311986 ¡PERF 120 ¡jeg. p",' r~, " "'0 Csa 7108 1108 6432 6432 A..3 1 """i '''R'i n -" _.:, ~--~- .. ~.. ~-, ~-~--~ - . 988 190 ""n !~ mat .. ma, 7168 7202 64 76 .. 8500 A..1 34 1 711311986 ¡PERF : 120 "",,_ P", .. Mlln Mfr VMfr V Type VOl) port 2272 =I 377C era 1 4744 ela ~- 5364 51116 era 0" 57391 5448 En a 61071 5710 era 0_ 64851 5980 Merla BK-2 0_ } 1790 6842 6239 6859 6251 !79 R R rown rown 'HB' .. Nipple NO GO ~- 'S rown NOTE: WAIVEREOWE[L IA v n/i, I NOTE- TUBING _M , r, ,?'\.. Jt71:: I"V STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Repair well Perforate -- 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 1561' FSL, 80' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 1299' FSL, 1685' FWL, Sec. 28, T13N, R9E, UM At effective depth 1258' FSL, 1958' FWL, Sec. 28, T13N, R9E, UM At total depth 1 12. 6. Datum elevation (DF or KB) RKB 68 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-14 9. Permit number/approval number 86-86 10. APl number 5o-029-21589-00 1 1. Field/Pool Kuparuk River Field/Oil Pool 248' FSL, 2029' FWL, Sec. 28, T13N, R9E, UM Present well condition summary Total Depth: measured true vertical 7460 feet 6686 feet Plugs (measured) None feet Effective depth: measured 7356 true vertical 6611 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 2 5 3 7' 9 - 5 / 8" Intermediate Production 7405' 7" Liner Perforation depth: Cemented Measured depth True vertical depth 238 Sx CS II 1 1 0' 1 1 0' 1150 Sx AS Ill & 2579' 2579' 150 Sx Class G w/100 Sx Class G top job 660 Sx Class G & 7440' 6672' 175 Sx AS I measured 71 04',7106',7108',7128'-7148',7155,7168'-7202' true vertical 6429',6430',6432',6446'-6461 ',6466,6475'-6499' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 ABM @ 6929' Packers and SSSV (type and measured depth) Pkr: Brown FH-L @ 6859'; SSSV: Baker FVL @ 1790' 13. Stimulation or cement squeeze summary IntervalsFracture stimulate "A" sands on 6/27/96treated (measured) 71 0 4 ', 71 0 6', 71 0 8', 71 2 8'- 71 4 8', 71 5 5,71 6 8'- 7 2 0 2' ~ask~ 0il & Gas Got6. ~_,~,qtss.ofl Treatment description including volumes used and final pressure Pumped 251.5 MIbs 20/40, 12/18, and 10/14 ceramic proppant into formation, fp was 5855 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 465 313 450 999 164 Subsequent to operation 650 411 493 1018 164 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned '~r ~, (1~-,¢Y-~ Title Wells Superintendent Form 10-404 Rev 0 88 Date ~ -'~--/'7-('t' 7 SUBMIT IN DUPLICATE~,~ .CO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT '~' K1(3N-14(W4-6)) WELL JOB SCOPE JOB NUMBER 3N-14 FRAC, FRAC SUPPORT 0630970535.2 DATE DALLY WORK UNIT NUMBER 07/14/97 PUMP "A" SANDS REFRAC DAY r OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes O NoI (~) Yes O No DS-YOKUM JOHNS FI ELD AFC# CC# DAILY COST AOOUM COST ESTIMATE KD 1071 230DS36N L $1 50,451 $1 56,479 Initial Tbq Press Final Tbcl Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final~)uter Ann 1 044 PSI 1 1 00 PSI 440 PSI 800 PSI 250 PSII 250 PSI DAILY SUMMARY PUMPED 'A' SANDS REFRAC W/251,500# PROPPANT TO 13# PPA 10/14 AT PERFS, EST 1144~ LEFT IN PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., HOT OIL PUMP AND APC VAC. TRUCK. 07:37 HELD JOB SITE SAFETY MEETING. 07:52 PRESSURE TEST TREATING LINE. 08:25 HAD SOME DIFFICULTIES SETTING TREE SAVER, WORKED OUT OK. 09:47 Pt !MPED BREAKDOWN W/79 BBLS 50# GEL AT 25 BPM AND 7851 PSI. 09:5i 09:54 09:57 10:00 11:19 12:43 13:00 13:06 14:13 14:19 ' ;-'~ ',4?bD 1PPA, 20/40 (2011#), 15 BPM AND 7814 PSI. PUMP CONDITION STAGE, 50 BBLS AT 15 BPM AND 5342 PUMPED 2 PPA, 20/40(3860#) , 15 BPM AND 5250 PSI. PUMPED 139 BBLS OF FLUSH AT 15 BPM AND 5228 PSI. SHUTDOWN FOR ISIP 1822 PSI AND PULSE TEST. PUMPED DATA FRAC AND FLUSH W/139 BBLS FLUIDS , 5 TO 15 BPM AND 5777 PSI. SHUT DOWN ISIP 2037 PSI. AND CALCULATE CLOSURE PRESSURE. PUMPED 155 BBLS OF PAD 5TO 15 BPM AND 6184 PSI. PUMPED 7719# oF 20/40 , 2PPA STAGE , 15 BPM AND 6656 PSI. PUMPED 228,500# 12/18 FROM 6 TO 11.5 PPA AT 15 BPM AND 5983 PSI. PUMPED 10,644~ 10/14 AT 13 PPA, 15 BPM AND 5855 PSI. PUMPED FLUSH OF TUBING AND SHUTDOWN. RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $555.00 APC $7,000.00 $7,500.00 DOWELL $141,451.00 $141,451.00 HALLIBURTON $0.00 $4,973.00 LI-FI'LE RED $2,000.00 $2,000.00 TOTAL FIELD ESTIMATE $150,451.00 $156,479.00 ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: Transmitted herewith are the following items. one signed copy of this transmittal. 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 3{-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F.-15 3F-13 3F-15 1B-05 1E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1E-08 3M-18 ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Please acknowledge receipt and return Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 12-03-87 12-18-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 12-04-87 2-02-89 8-27-87 8-27-87 8-25-87 2-20-89 2-19-89 2-20-89 2-21-89 2-21-89 2-20-89 2-20-89 2-19-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' SandBHP 'C' mer da Casing Casing Casing casing Tubing Tubin~,~l( casinL~' casin~ °'~ge ezi,/ls$/b;' 3H-01 3B-13 1E-29 1C-05 3M-17 2Z-20 30-10 31-12 3H-10 Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re Kupaurk Fluid Level Re BHP Report 3ort 2-15-89 Casing 3ort 2-17-89 Casing 3orr 2-15-89 Casing 3ort 2-18-89 Casing/Tubing 3ort 2-16-89 Casing 3orr 2-18-89 Tubing 3ort 2-16-89 Casing 3ort 2-20-89 Tubing 2-13-89 BHP Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M ,_ State of Alaska SAPC Unocal Mobil Chevron _ - 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Ku~aruk Ku~aruk Ku~aruk Ku~aruk Ku::aruk Ku~aruk Ku ~aruk Ku ~aruk Ku ~aruk Ku~aruk Ku ~aruk Ku~aruk Ku3aruk Ku~aruk Kuaaruk Kuaaruk Kuaaruk Ku ~aruk Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Fluid Acknowledged: Level Report Level Report Level Report Level Report Level Report Level Report Level Report Leyel Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re~ort Level Re ~ort Level Re~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level. Re sort Level Re ~ort Level Re sort Level Re ~ort Level Re )orr Level Reaort Level Reoort 9-11-87 12-06-86 9-11-87 10-11-87 9-16-87 4-1 I-88 4-08-88 4-01 -88 3-26-88 1 -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 . 9-10-87 9-10-87 9-12-87 9-08-87 9-0'1 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 .6-08-87 6-09-87 6-25-87 4-17-87 4-18-87 · . 6-17-87 6-20-87 5-07-87 8-24-87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubinc~ Tubinc~ Tubinc~ Tubinc~ Tubinc. Tubinc. Tubinc~ Tubinc_ Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing ~ ~ ,,., m Alaska Oil & Gas Con:. ....... ~C~orage DISTRIBUTION: D&M . State of Alaska - Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATOo 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3F-11 3H-12 30-07 3F-10 3F-06 3F-02 3F-16 3F-16 3F-11 3F-04 3F-05 3F-13 3N-10 3N-10 3N-04 3N-09 30-14 30-14 3M-18 3F-16 3F-13 3Fo13 3F-13 3F-13 3F-08 3F-16 3F-16 3F-13 3F-16 3F-16 3F-16 3F-14 Sub-Surface Pressure Survey Ku2aruk Well Pressure Report Ku 2aruk Ku aaruk Ku 2aruk Ku 2aruk Ku aaruk Ku 2aruk Ku 2aruk Ku 2aruk Ku 2aruk Ku 3aruk Ku 2aruk Ku 2aruk Ku2aruk Kuapruk Ku :)aruk Ku ~aruk Ku2aruk Ku ~aruk Ku aaruk Ku 2aruk Ku2aruk Ku2aruk Kuaaruk Ku2aruk Kuaaruk Ku2aruk Ku2aruk Ku 2aruk Ku2aruk Ku 2aruk 10-06-88 8-29-88 Well Pressure Report I 2- 2 0 - 8 8 Well Pressure Report 8 - 2 9 - 8 7 Well Pressure Report 8 - 2 9 - 8 7 Well Pressure Report 8 - 2 9 - 8 9 Well Pressure Report 8 - 1 7- 8 7 Well Pressure Report 8 - 1 7- 8 7 Well Pressure Report 8 - 2 9 - 8 7 Well Pressure Report 6 - 2 6 - 8 7 Well Pressure Report 1 2- 1 2- 8 8 Well Pressure Report 1 2- 3 1 - 8 8 Well Pressure Report 6- 1 1 - 87 Well Pressure Report 6 - 11 - 8 7 Well Pressure Report 9 - 01 - 8 7 Fluid Level Report 5 - 0 4 - 8 7 Fluid Level Report 2 - 1 3 - 8 9 Fluid Level Report "2- 1 0 - 8 9 Fluid Level Report 2 - 1 0 - 8 9 Fluid Level Report 6 - 0 5 - 8 7 Fluid Level Report 6 - 0 9 - 8 7 Fluid Level Report 6 - 1 8 - 8 7 Fluid Level Report 6 - 1 6 - 8 7 Fluid Level Report 6 - 21 o 8 7 Fluid Level' Report 5 - 0 8 - 8 7 Fluid Level Report 8 - 1 8 - 8 7 Fluid Level Report 8 - 2 4 - 8 7 Fluid Level Report 6 - 0 5 - 8 7 Fluid Level Report 6 - 2/3 - 8 7 Fluid Level Report 8 - 5 - 8 7 Fluid Level Report 6 - 5 - 8 7 Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Casin~"~ ~ ~ ~' ! 1 / ~ ~ Casi~¢' a Oil & fi.~s Conz. Cornmisz,,~;n Gasing ~c~orage Tubing Gasing Gasing STATE OF ALASKA ALAS .... OIL AND GAS CONSERVATION COM; .... oSION REPORT OF SUNDRY W/ELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [Tg' Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360~ Anchorages AK 4. Location of well at surface 1561' FSL, 80' FEL, Seco29, At top of productive interval 1299' FSL, 1685' FWL, Sec. 28, A~.~§~tiVFesC_e, pt~958' FWL, Sec.28, Atl/z~l'dep~, 2029' FWL, Sec.33, 99510 T13N, R9E, UM T13N, R9E, UM T13N, R9E, UM T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 68' 6. Unit or Property name Kuparuk River Unit 7. Well number 3N-14 8. Approval number #86-86 -' 9. APl number so- 029-21589 10 Pool K'Qparuk River 0il Pool Feet 11. Present well condition summary 7460' HD Total depth' measured true vertical 6686' TVD feet feet Effective depth: measured 7356' MD feet true vertical 6611 ' TVD feet None Plugs (measured) Junk (measured) None Casing Structural Conductor Surface X X AO~t~,w~A~ Production xx~km~xxxxx Perforation depth: Length Size Cemented Measured depth True Vertical depth 80' 16" 238 SX CSII 110' 110' 2542' 10-3/4" 1150 SX ASIII 2579' 2579' & 150 SX Class G Top job w/lO0 S× ASI 7440' 7" 660 SX Class G 7440' 6672' & 175 SX ASI : , measured 7104', 7108', 7t44', 7155, 7106', 7134', 7146', 7168'-720'2" MD 7128'-7148' MD true vertical 6429', 6432', 6458', 6466', 6430', 6450', 6459', 6475' -6499' TVI 6447'-6461' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 6929' MD ~a~ck~<Sra~d b~¢¢~'(ty&'PeF~Ld ~-e~U~dl(~'¢)~) MD 12. 13. Stimulation or cement squeeze summary Fracture stimulated the A Sands w/70,600# of proppant. Intervals treated (measured) 7104'-7202' MD Treatment description including volumes used and final pressure IRF~I hhlc nF gellaH H~c~l mnH 7g,lqgIh~ nC 9n/zln m~ch rnDD n+ ............ -Re-p'r~e-n'tat~,~-D~i]y ......... ' ......... p v,,a .... Average Production or Injection Data 27~i1'1~0b1~D ~2~'~;fFPD Watl~r'~D Casi~2P~essure Prior to well operation 1655 BOPD 1078 MCFPD 0 BWPD 1000 Subsequent to operation 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run L] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~'~,-,'%, ,1~ /4~d.~-¢..~)/,¢,(..-1;~¢(2 Form 10-4~)4 Rev. 1~-1-85 " Title Sr. Operations Engineer Submit in Duplicate ARCOAlaska, In~: ~ Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT ~VELL ONTRACTOR I'-1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather lTemP'Report OF Chill Fact°r 1 Vlslblllty°FI mile. IwInd vel' knot. STATE OF ALASKA ALA .... -~ OIL AND GAS CONSERVATION COh.,,~iSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing Time extension ~ Change approved program ~ Plugging Vi Stimulate [] Pull tubing [] Amend order ~ Perforate i2 Other . Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 1561' FSL, 80' FEL. Sec 29 T13N R9E UM At top of productive interval1 ' ' ' ' t299' FSL, 1685' At effective depth 1258' FSL, 1958' At total depth 1248' FSL. 2029' 5. Datum elevation (DF or KB) RKB 68 6. Unit or Property name Kuuaruk River Unit , 7. Well number 3N-14 8. Permit number Permit #86-86 9. APl number 50-- 029-21589 feet FWL, Sec.28, T13N, R9E, UM FWL, Sec. 28, T13N, R9E, UM FWL. Sec. 28: T13N: RgE: UM 11. Present well condition summary Total depth: measured 7460' MD feet true vertical6686, TVD feet 10. Pool Kupar,mk RivPr Oil Pnnl Plugs (measured) None Effective depth: measured 73 ' MD feet true vertical6656 feet 11' TVD Casing Length Size x x x ~6~ ~4~cX~F;~< x x x x Conductor 80' Surface 2542' X X X X0d)exr~RC, i~.t e Production 7440' xxx,4-.~r~'~fxx x x Perforation depth: measured Junk (measured) None Cemented Measured depth True Vertical depth 16" 238 SX CSII 110' MD 110' TVD 10-3/4" 1150 SX ASIII & 2579' MD 2579' TVD 150 SX Class G Top job w/lO0 SX ASI 7" 660 SX Class G & 7440' MD 6672' TVD 175 SX ASI 7104', 7108', 7144', 7155' MD 7106', 7134', 7146', 7168'-7202' MD" true vertical6429. 6432' 6458' 6466' TVD 6430' 6450' 6459' 6475'-6499' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 6929' MD Packers and SSSV (type and measured depth) HB pkr Fa 695g' & FVI ~_~V @ 1790' 12.Attachments Description summary of proposal Convertin.q a producer to a water i n~ect'ion well. 13. Estimated date for commencing operation October 1, 1987 14. If proposal was verbally approved Subsequent ~,¥o]:~.,:. ~eported on - :' -r- DaL_._~_/~,_/_:.~ Name of approver Date approved Alaska Oil & Gas Cons. Commisslor~ Anchorage BOP sketch 15. I hereby certify that the foregoing is true arc, correct to the best of my knowledge ..... · '.~,~ -¢-;"-- Title Signed./~_;.¢~1 ¢~...~/ ¢~{-. ../~ .~ ~,~,¢~"~'.¢~,_~_, - Sr. Operations Engineer Date 9/23/87 Conditions of approval Approved by Form 10-403 Rev 12-1-85 Commission Use Only Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI _,~1~ Mech. anica~. _ . Jr~ :.~r;~.y ~'-~o~.~ ,.,,,. e. .k~--. ~~.-~ Commissioner by order of the commission Date Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 22, 1987 Transmittal #5894 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3N-13 3N-14 3I-9 2X-7 2X-7 CET 5-15-86 6342-7768 CET 5-15-86 5882-7328 CET .5-5-86 7090-8949 CET 1-5-87 5995-7242 CET 1-8-87 5995-7011 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Date: Mobil SAPC Unocal BPAE Chevron ARCO Alaska, Inc, is a Subsidiary of AllanlicRIchfieldCompany NEW PROJECTS ENGINEERING TRANSMITTAL # 1032 TO: John Boyle DATE: Dec. 16, 1986 FROM: H. D. White/P. S. Baxter WELL NAME: 3N-14 TRANSMITTED HEREWITH ARE THE FOLLOWING: One copy of Blueline and Sepia for each: ~'~3N-14 2" Dual Induction SFL-GR ~--~-3N-14 5" Dual Induction SFL-GR ~3N-14 2" Natural Gamma Spectroscopy ~3N-14 5" Natural Gamma Spectroscopy ~3N-14 2" Long Space Sonic GR ~3N-14 5" Long Space Sonic GR 3N-14 2" LDT-CNL-NGT Raw Data b3N--14 5" LDT-CNL-NGT Raw & 25" Hi-Res ~3N-14 2" LDT-CNL-NGT Porosity ~3N-14 5" LDT-CNL-NGT Porosity ~-~N-14 5" Dual Dipmeter GR 3N-14 5" & 25" Electromagnitic Propagation ~3N-14 Cyberlook 5/1/86 run 1 5/1/86 run 1 5/2/86 run 1 5/2/86 run 1 5/1/86 run 1 5/1/86 run 1 5/2/86 run 1 5/2/86 run 1 5/2/86 run 1 5/2/86 run 1 5/2/86 run 1 5/2/86 run 1 5/3/86 run 1 RECEIPT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: P. Susanne Baxter, P O. Box 100360 A~chorage, Ai~~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage; Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 10-20-86 TRANSMITTAL ~ 5801 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: Open Hole Logs: One * of each 2T-9 *These are combination Run #1&3 Logs.' To save space they are listed as Run #3. '"~5" DIL/SFL 07-03-86 Run #3 2668-6360 x~'~2" .DIL/SFL "'°5" Comp.Neu/Form. Den (poro) "-02" Comp.Neu/Form. Den (poro) '"~5" Comp.Neu/Form. Den (raw) "-02" Comp.Neu/Form. Den (raw) ~"'~5" LSS-GR '-.o~, LSS-GR '"~Cyberlook x'~5" Dual Dipmeter-GR "-~RFT Log 2T- 5" D L/SFL-¢R ~-D2" DIL/SFL-GR x'-35" Den/Neu-GR (poro) '"'~2" Den/Neu-GR (poro) "~5" Den/Neu-GR (raw) ~'-a2" Den/Neu-GR (raw) "-,O Cyberlook 07-03-86 Run #3 2668-6360 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2668-6334 07-03-86 Run #3 2680-6354 07-03-86 Run #3 2680x6354 07-03-86 Run #3 5800-6300 07-05-86 Run #3 2680-6364 07-04-86 3112-6056 05-03-86 Run #1 7678-8194 05-03-86 Run #1 7678-8194 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7678-8168 05-03-86 Run #1 7690-8140 3N-~.5" DIL/SFL-GR ~2" DIL/SFL-GR x-._lS" Den/Neu-GR "~2" Den/Neu-GR "05" Den/Neu-GR '"02" Den/Neu-GR '-~Cyberlook (poro) (poro) (raw) (raw) 05-04-86 Run #2 2579-7451 05-04-86 Run #2 2579-7451 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7425 05-04-86 Run #2 6650-7400 / Receipt Acknowledged: ~ NSK Files*bl Rathmell*bl D & M *bl Vault*films t_.../ Alaska u,, & Gau Cunt. Commission Anchorage Drilling*bi L. Johnston*Schl pkg. ARCO Alalkl. Inc. is I Subsidiary of AtlanticRlchlieldComplnY STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION L,,JMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~'( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2.ANRa~-r~e of Operator 7. Permit Number A1 aska, Inc. 86-86 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21589 4. Location of well at surface 9. Unit or Lease Name 1561' FSL, 80' FEL, Sec.29, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1299~ FSL, 1685' FWL, Sec.28, T13N, R9E, UM 3N-14 At Total Depth 11. Field and Pool 1248' FSE, 2029' FWL, Sec.28, T13N, R9E, UN Kuparuk River Field 5.68,ElevationRKB in feet (indicate KB, DF, etc.) I 6.ADLLease25520DesignationALK and2556SeriaI No. Kupaurk River Oil Pool 12. DateSpudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore I16. No. of Completions 04/27/86 05/04/86 08/18/86* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7460 'MD ,6686 'TVD 7356'MD,6611 'TVD YES~ NO []I 1790 feet MD 1700' (approx) 22. Type Electric or Other Logs Run LSS/GR, D I L/SFL, LDT/EPT/CNL/NGT, SHDT,D I L/GR/SP/SFL/CAL, FDC/CNL, CET/GR/CCL, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" hZ.5# H-40 Surt 110' 24" 238 sx CS II lU-3/~" 45.5# J-55 Surf 2579' 13-1/2" 1150 sx AS Ill & 150 sx Class G Top job performed w/lO0 sx Class G /" 26.0# J-55 Surf 7440' 8-1/2" 660 sx Class G & 175 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See Attached 2-7/8" 6929 ' 6859 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached adden, lum, dated 9/02/86, for fracture data N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test HoUrs Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD ~ I OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core data to be submitted when received. , · . . . . ..... -.,;. ._.. ..; ,.~ ;;: · * NOTE: Drilled RR 5/05/86 Perf'd well & ran tubing 7/13/86 WC1/113 Form 10-407 · · Submit. in duplicate/ Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~ · 30. GEOLOGIC MARKERS "FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 6955' 16320' NA Base Kuparuk C 7008' 6359' Top Kuparuk A 7080' 6411' Base Kuparuk A '7235' 6524' 31. LIST OF ATTACHMENTS Addendum (dated 9-02-86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Signed ~-~~ :~~ Title 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- lng 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 WELL COMPLETION OR RECOMPLETION REPORT AND LOG (Cont'd) 3N-14 ITEM 24: MD 7104 7106 7108 7134 7144 7146 7155 7168 - 7202' TVD 642 643 643 645 645 645 646 647 9 0 2 0 8 9 6 5 - 6499 ' All perforated w/1 spf ~ 90° phasing WC1:112c:dmr 9/15/86 ADDENDUM WELL: 5/12/86 5/16/86 8/18/86 8/19/86 3N-14 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak. Rn 6-1/8" gage ring/JB to 7334'. Rn CET f/7334'-5882'. Rn GCT gyro f/7280'-surf. Frac'd Kuparuk "A" sand perfs 7104' 7106' 7108' 7134' 7134', 7144', 7146', 7155' & 7168'- 202' in 7 stages per 8/12/86 procedure using gelled diesel, 100 & 20/04 mesh sand. Press'd ann to 260 psi w/diesel. Tst ins to 8220 psi; OK. Stage 1: Pmp'd 47 bbls gelled diesel pre-pad @ 20 BPM, 6050'-4340 psi Stage 2: 15 bbls gelled diesel w/630#, 1 ppg 100 mesh @ 20.5 BPM, 4340-4520 psi Stage 3: 162 bbls gelled diesel pad @ 20.6 BPM, 4710-4350 psi Stage 4: 18 bbls gelled diesel w/3 ppg, 20/40 @ 20.5 BPM, 4350-4400 psi Stage 5: 39 bbls gelled diesel w/6 ppg, 20/40 @ 20.4 BPM, 4400-4120 psi Stage 6: 37 bbls gelled diesel w/8 ppg 20/40 @ 20.6 BPM, 4120-6370 psi Stage 7: 16 bbls gelled diesel flush @ 20.6-10.8 BPM. Press was 6370 psi @ 20 BPM. Shut down @ 10.8 BPM, 7500 psi. Screened out 28 bbls short. Top of 8 ppg slurry in tbg @ ±2763' (TT @ 6929'). Pmp'd 630# 100 mesh & 16,878# 20/40 in formation leaving 7504# 20/40 above top perf in tbg and in csg. Load to recover 334 bbls of diesel. Job complete @ 1636 hrs, 8/18/86. RU CTU, RIH & pmp 3/4 BPM, 2300 psi w/gelled diesel as circ'g fluid. GIH to 6800', inc rate to 2 BPM, 3400 psi. RIH, tag @ 7150', wsh sand f/7150'-7333', tag PBD @ 7333' CTM. Circ well cln. Displ CT w/clear diesel, POH, displ'g w/diesel. Rn out of diesel @ 6400'. Pmp'd 180 bbls gelled diese, 36 bbls diesel (216 total bbls). Rec'd 210 bbls gelled diesel. Drilling Supervisor 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 BP ALASKA EXPLORATION, INC. WELL 3N-14 KUPARUK RIVER FIELD, FORMATION UGNU CORE ANALYSIS DATA JUNE, 1986 File #70021 ~ ~j~ ~ 4450 WEST 50TH AVENUE ~i~~~~.~ ~,~ ANCHORAGE, ALASKA 99502 June 17, 1986 Mr. Bob Gettka BP Alaska Exploration, Inc. 100 Pine St. 32nd Floor San Francisco, Ca 94111 Re: Core Analysis Data Well 3N-14 - Kuparuk River Field Formation Ugnu File ~70021 Dear Mr. Gettka: Herewith are porosity, air permeability, fluid saturation and apparent sand grain density data, as well as overburden porosity and air perm- eability data on core material recovered from your Ugnu Formation, Kuparuk River Field, Well 3N-14, Alaska. The core was recovered utilizing a 5 1/4" fiberglass core barrel, in the presence of a water base drilling fluid. Core oil gravity was estimated to be 12°API, by visual fluorescence. The core was received at Anchorage, Alaska frozen (and was maintained in a frozen condition). Upon receipt, the core was slabbed, photographed and gamma logged. Samples were cut for routine core analysis (1 per foot) and for the State of Alaska (1 per foot). The routine core analysis samples were wrapped with teflon tape and jacketed in a metal sleeve. The samples were individually extracted with toluene for a minimum of 16 hours, placed in a gang extractor and extracted with chloroform-methanol-azeotrope for 48 hours, followed by an additional 8 hours with fresh azeotrope. The samples were then dried at 150° F. for 8 hours, followed by vacuum drying for 4 additional hours at 150°F., cooled in a desiccator at room temperature and weighed. The porosity was determined by the Archimedes method and air permeabil- ity was determined using a flow tube type permeameter, having a clos- ing pressure of 300 psi. Helium porosity and air permeability were also determined on each sample at 1,000 psi simulated reservoir stress. We sincerely appreciate this opportunity to be of service and trust these data prove beneficial in the development of this reservoir. PTS:rlf Encl. Very truly yours, PETR~LEUM TESTING S]~RVICE, ~/~Pet~r T. Schuyler President INC. COMPANY CORE BARREL MUD TYPE BP Ataska Exptoration Inc. 5 1/4" Fiberglass Sleeve Water Base PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL FIELD COUNTY STATE PAGE 1 FILE No. 70021 DATE June 16, 1986 Ugnu 3N-14 Kuparuk River-Ugnu Alaska ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeability O/W ....................... FEET PERCENT md. RATIO OIL WATER TOTAL CORE NO. 1 (2722 - 2746) : REC. (2722 - 2745.1) 2722.15 36.7 60. ** 0.00 0.0 82.7 2723.05 34.8 47. 0.00 0.0 82.1 2724.1 35.7 60. 0.00 0.0 80.1 2725.15 35.8 65. 0.00 0.0 79.0 2726.05 33.9 38. 0.00 0.0 83.0 2727.05 35.2 32. 0.01 0.8 78.1 2728.05 36.7 193. 0.42 22.6 53.7 2729.05 33.1 126. 0.21 13.6 65.5 2730.05 35.4 11. 0.01 0.8 85.9 2731.05 41.5 312. 1.16 42.6 36.8 82.7 82.1 80.1 79.0 83.0 78.9 76.3 79.1 86.7 79.4 2732.05 41.5 421. 1.70 47.9 28.2 2733.05 43.0 609. 2.06 53.4 25.9 2734.0 SECTION PRESERVED 2735.0 SECTION PRESERVED 2735.05 43.3 875. 2.42 56.4 23.3 APPARENT SAND GRAIN DENSITY gm/cc at SIMULATED RESERVOIR STRESS SIMULATED. - ...................... RESERVOIR Air STRESS POROSITY Permeabilty psi PERCENT md. 2.68 SAMPLE FAILED 2.68 1000 32.6 31 2.68 1000 32.3 41 2.67 1000 32.1 45 2.67 1000 30.2 12 2.67 1000 32.4 26 2.66 1000 32.6 136 2.67 1000 29.9 97 2.61 1000 32.2 4.1 2.68 1000 36.2 244 76.1 2.68 1000 36.8 280 79.3 2.69 1000 38.3 500 79.7 2.67 1000 39.4 743 DESCRIPTION Slst; cly-slt, mod cmtd Slst; cly-slt, mod cmtd Slst; cly-slt, mod cmtd Slst; cly-slt, mod cmtd Slst; c[y-slt, mod cmtd Clst; cly-fsd, well cmtd Sd; cly-fsd, mod cmtd Sd; cly-fsd, mod cmtd Clst; cly-fsd, well cmtd Sd; vfn-fsd, mod cmtd Sd; vfn-fsd, mod cmtd Sd; vfn-fsd, mod cmtd Sd; vfn-fsd, mod cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY BP Alaska Exploration Inc. PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL Ugnu 3N-14 PAGE 2 FILE No. 70021 DATE June 16, 1986 ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeability 0/~ FEET PERCENT mci. RATIO OIL WATER TOTAL CORE NO. 1 (CONTINUED) (2722 - 2746) : REC. (2722 - 2745.1) 2736.05 43.1 881. 2.26 57.3 25.3 82.6 2737.05 43.2 552. 1.77 48.1 27.2 75.3 2738.05 38.7 95. 0.63 31.4 50.2 81.6 2739.05 38.7 103. 0.61 30.5 49.9 80.4 2740.05 37.7 209. 0.98 40.1 41.0 81.1 2741.05 41.3 1180. 2.66 57.8 21.7 79.5 2741.65 SECTION PRESERVED 2742.65 SECTION PRESERVED 2742.7 42.4 1340. 2.71 56.9 21.0 77.9 2743.05 40.7 974. 2.38 57.2 24.0 81.2 2744.1 45.3 912. 2.09 42.8 20.5 2745.05 40.2 1830. 2.74 57.5 21.0 CORE NO. 2 (2746 - 2776) : REC. (2745.1 - 2773.7) 2746.15 28.9 5.0 ** 0.00 0.0 95.8 2747.05 30.0 5.0 ** 0.00 0.0 92.8 2748.35 29.1 1,0 ** 0.00 0.0 88.7 2749.15 26.8 1,3 0.00 0.0 91.7 2750.05 27.1 1.1 0.00 0.0 88,2 2751.0 SECTION PRESERVED at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeab~lty gm/cc psi PERCENT md. 2.67 1000 39.2 716 2.69 1000 38.8 414 2.69 1000 35.~ 80 2.68 1000 35.1 68 2.69 1000 33.8 107 2.68 1000 37.3 986 2.68 1000 37.9 1180 2.67 1000 36.3 766 63.3 2.66 1000 39.9 431 78.5 2.64 1000 35.7 966 95,8 92.8 88,7 91.7 88.2 1.46 1.51 2.66 2.66 2.67 1000 13.8 1000 18.3 1000 26.9 1000 23.5 1000 23.6 3.0** 0.7** 0.2 0.2 DESCRIPTION Sd; vfn-fsd, mod cmtd stst; pr[y cmtd Slst; cly-slt, mod cmtd S[st; slt-vfsd, mod cmtd Slst; slt-vfsd, mod cmtd Sd; vfn-msd, mod cmtd Sd; vfn-msd, mod cmtd Sd; vfn-msd, mod cmtd Sd; vfn-msd, mod cmtd Sd; cly-msd, mod cmtd C; well cmtd C; well cmtd Clst; well cmtd Clst; well cmtd Clst; well cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY BP Alaska Exploration Inc. PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL Ugnu 3N-14 PAGE 3 FILE No. 70021 DATE June 16, 1986 ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeability O/W ....................... FEET PERCENT md. RATIO OIL WATER TOTAL CORE NO. 2 (CONTINUED) (2746 - 2776) : REC. (2745,1 - 2773.7) 2752.0 SECTION PRESERVED 2752.05 31.2 41. 0.12 8.7 75.0 83.7 2753.05 28.4 6.3 0.03 2.4 86.4 88.8 2754.1 37.8 25. ** 0.32 19.6 61.4 81.0 2755.05 28.1 10. 0.00 0.0 91.9 91.9 2756.05 31.7 31. 0.08 6.5 82.1 88.6 2757.05 32.6 11. 0.00 0.0 88.2 88.2 2758.05 29.1 3.1 0.00 0.0 89.0 89.0 2759.05 29.3 3.4 0.02 1.8 89.7 91.5 2760.0 32.4 12. 0.05 4.1 84.6 88.7 2761.05 30.5 8.8 0.06 4.7 82.1 86.8 2762.05 40.7 962. 1.26 44.8 35.6 80.4 2763.05 35.3 164. 0.13 10.1 74.9 85.0 2764.05 47.7 1430. 1.71 48.8 28.6 77.4 2765.05 37.0 67. 0.21 13.7 65.3 79.0 2766.0 45.6 563. 0.94 33.7 35.9 69.6 2767.05 31.3 5.0 ** 0.03 2.8 80.9 83.7 2768.05 46.7 3300. 2.63 52.6 20.0 72.6 2769.05 43.5 745. 0.96 33.6 35.1 68.7 at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeabilty gm/cc psi PERCENT md. 2.68 1000 28.2 19 2.67 1000 26.9 1.3 2.67 SAMPLE FAILED 2.67 1000 26.5 1.2 2.69 1000 28.6 8.2 2.68 1000 28.9 3.2 2.68 1000 27.4 1.2 2.68 1000 27.2 1.3 2.69 1000 28.4 1.6 2.68 1000 28.2 4.0 2.67 1000 35.5 738 2.66 1000 30.8 24 2.68 1000 41.9 957 2.68 1000 34.2 26 2.68 1000 37.8 315 2.70 1000 28.6 3.0** 2.69 1000 40.4 2490 2.69 1000 37.8 372 DESCRIPTION Slst; cly-vfsd, mod cmtd Clst; cly-slt, well cmtd Slst; cly-slt, well cmtd Clst; cly-slt, well cmtd Slst; cly-slt, well cmtd Clst; cly-slt, well cmtd clst; well cmtd Clst; well cmtd Clst; cly-fsd, well cmtd Clst; cly-fsd, well cmtd Sd; slt-fsd, mod cmtd Clst; cly-fsd, mod cmtd Sd; slt-fsd, mod cmtd Slst; cly-slt, mod cmtd Sd; slt-vfsd, mod cmtd Clst; cly-sltt mod cmtd Sd; vfn-fsd, prly cmtd Sd; vfn-fsdt mod cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY COMPANY BP Alaska Exploration Inc. PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL Ugnu 3N-14 PAGE 4 FILE No. 70021 DATE June 16, 1986 ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeability O/W ....................... FEET PERCENT n~d. RATIO OIL WATER TOTAL CORE NO. 2 (CONTINUED) (2746 - 2776) : REC. (2745.1 - 2773.7) 2770.0 SECTION PRESERVED 2771.0 SECTION PRESERVED 2771.05 47.9 1930. 1.95 45.4 23.3 2772.2 52.0 1850. 2.73 43.1 15.8 2773.2 47.0 2210. 2.38 51.5 21.6 CORE NO. 3 (2776 - 2806) : REC. (2776 - 2798.55) 2776.05 46.3 7530. 2.75 54.7 19.9 2777.1 50.0 5440. 2.08 48.5 23.3 2778.1 48.1 8530. 1.36 41.1 30.2 2779.0 45.6 12500. 6.30 64.3 10.2 2780.05 45.5 8580. 7.47 65.7 8.8 2781.0 48.6 2570. 2.88 55.6 19.3 2782.05 48.5 6440. 1.53 46.3 30.3 2783.05 48.8 7640. 3.24 57.1 17.6 2784.05 46.0 11200. 3.14 60.2 19.2 2785.05 47.8 11000. 7.18 65.3 9.1 at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeabilty gm/cc psi PERCENT 68.7 2.66 1000 40.5 1690 58.9 2.66 1000 42.9 902 73.1 2.66 1000 38.9 2020 2786.05 48.2 11800. 6.69 62.2 9.3 2787.05 45.9 11600. 7.02 66.7 9.5 2788.05 49.8 8230. 4.27 56.0 13.1 74.6 2.63 1000 40.1 6160 71.8 2.62 1000 41.7 1640 71.3 2.64 1000 39.8 7530 74.5 2.65 1000 40.3 9750 74.5 2.61 1000 40.9 7080 74.9 2.66 1000 41.2 760 76.6 2.60 1000 40.1 5940 74.7 2.63 1000 41.2 4530 79.4 2.62 1000 39.6 8890 74.4 2.61 1000 40.1 8940 71.5 2.60 1000 39.5 9800 76.2 2.60 1000 39.0 9240 69.1 2.62 1000 41.8 7250 DESCRIPTION Sd; vfn-fsd, prly cmtd Sd; vfn-fsd, prly cmtd Sd; vfn-fsd, prly cmtd Sd; vfn-msd, prly cmtd Sd; vfn-msd, prly cmtd Sd; vfn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; vfn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn, prly cmtd COMPANY BP Alaska Exploration Inc. PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL Ugnu 3N-14 PAGE 5 FILE No. 70021 DATE June 16, 1986 ARCHIMEDES Air SATURATION % PO~E SPACE DEPTH POROSITY Permeability O/W ............... ~ ....... FEET PERCENT md. RATIO OIL WATER TOTAL CORE NO. 3 (CONTINUED) (2776 - 2806) : REC. (2776 - 2798.55) 2789.05 50.5 5570. 1.79 49.5 27.6 77.1 2790.9 50.8 8290. 4.52 52.0 11.5 63.5 2791.05 49.8 8620. 5.06 55.7 11.0 66.7 2792.05 48.8 11900. 2.11 58.1 27.5 85.6 2793.05 49.0 8540. 2.05 57.9 28.2 86.1 2794.05 51.3 7040. 2.75 46.8 17.0 63.8 2795.05 45.4 11400. 1.98 54.0 27.3 81.3 2796.05 49.9 7580. 0.76 28.7 37.7 66.4 2797.1 52.2 9910. 1.33 36.5 27.4 63.9 2798.1 36.3 3430. 0.06 4.7 73.3 78.0 CORE NO. 4 (2806 - 2821) : REC. (2798.55 - 2819.1) 2799.05 40.5 5090. 0.12 8.7 75.6 2800.05 34.9 4320. 0.02 1.7 75.2 2801.05 36.7 3680. 0.04 2.8 74.3 2802.05 41.4 7520. 0.14 8.1 59.0 2803.05 40.2 6810. 0.06 3.0 54.2 2804.05 39.3 6460. 0.17 8.5 48.9 2805.05 33.7 2660. 0.05 3.8 69.4 at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeabilty gm/cc psi PERCENT md. 2.63 1000 44.4 4790 2.63 1000 42.2 7400 2.64 1000 ' 42.3 7540 2.59 1000 41.9 9780 2.64 1000 41.4. 7460 2.58 1000 43.6 5400 2.62 1000 38.3 9130 2.60 1000 40.1 6800 2.61 1000 41.9 8350 2.61 1000 32.9 1810 84.3 2.61 1000 36.2 4290 76.9 2.60 1000 32.4 3510 77.1 2.62 1000 29.8 3280 67.1 2.63 1000 37.7 5600 57.2 2.61 1000 34.2 5690 57.4 2.63 1000 34.6 4850 73.2 2.64 1000 29.3 1660 DESCRIPTION Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; vfn-msd, c, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd-clst; cly-msd, prly cmtd Sd; fn-crssd, prly cmtd Sd; fn-crssd, prly cmtd Sd; fn-crssd, prly cmtd Sd; fn-crssd, prly cmtd Sd; fn-crssd, prly cmtd Sd; fn-crssd, prly cmtd Sd; fn-crssd, prly cmtd COMPANY .BP Alaska Exploration Inc. PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS ~ELL Ugnu 3N-14 PAGE 6 FILE No. 70021 DATE June 16, 1986 ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeability O/g ....................... FEET PERCENT md. RATIO OIL gATER TOTAL CORE NO. 4 (CONTINUED) (2806 - 2821) : REC. (2798.55 - 2819.1) 2806.05 29.8 3240. 0.00 0.0 72.6 72.6 * 2807.05 49.9 1000. ** 0.22 17.6 79.4 97.0 * 2808.05 46.0 1000. ** 0.29 20.4 69.8 90.2 * 2809.05 45.0 1000. ** 0.33 22.0 66.6 88.6 * 2810.05 43.9 1000. ** 0.07 5.9 86.2 92.1 * 2811.05 50.4 1000. ** 0.21 16.9 81.9 98.8 * 2812.05 48.4 1000. ** 0.86 38.6 45.0 83.6 * 2813.05 50.9 1000. ** 0.21 16.1 75.3 91.4 2814.05 53.2 5190. 1.75 40.7 23.3 64.0 * 2815.05 42.7 1000. ** 0.12 9.7 80.9 90.6 * 2816.05 51.9 1000. ** 0.16 13.4 84.9 98.3 2817.15 50.9 4940. 2.10 40.8 19.4 60.2 2818.05 44.9 3090. 1.98 48.5 24.5 73.0 CORE NO. 5 (2821 - 2826) : REC. (2819.1 - 2819.6) 2819. RUBBLED MATERIAL - NO SAMPLE CORE NO. 6 (2830 - 2859) : REC. (2830 - 2860) 2830.05 44.5 11800. 4.37 61.2 14.0 75.2 2831.05 45.4 11300. 3.25 57.6 17.7 75.3 ~* FRACTURED, ESTIMATED AIR PERMEABILITY * CONTAMINATED WITH DRILLING blUD at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeabilty gm/cc psi PERCENT md. 2.60 1000 27.4 1600 2.56 1000 41.8 750** 2.64 1000 33.2 750** 2.66 1000 32.0 750** 2.64 1000 31.9 750** 2.63 1000 35.9 750** 2.64 1000 33.7 750** 2.65 t000 35.6 750** 2.65 1000 41.7 2440 2.64 1000 33.2 750** 2.64 1000 35.4 750** 2.64 1000 40.6 3600 2.64 1000 37.4 2140 2.63 1000 39.3 4560 2.59 1000 41.6 5470 DESCRIPTION Sd; vfn-crssd, prly cmtd Sd-mud; cly-msd, prly cmtd Sd-mud; cly-msd, prly cmtd Sd-mud; c[y-msd, pr[y cmtd Sd-mud; c[y-msd, prly cmtd Sd-mud; cly-msd, prly cmtd Sd-mud; c[y-msd, prly cmtd Sd-mud; c[y-msd, prty cmtd Sd; fn-msd, prly cmtd Sd-mud; c[y-msd, pr[y cmtd Sd-mud; cly-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prty cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd COMPANY BP Alaska Exploration Inc~ PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL Ugnu 3N-14 PAGE 7 FILE No. 70021 DATE June 16, 1986 ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeability O/W ....................... FEET PERCENT md. RATIO OIL WATER TOTAL CORE NO. 6 (CONTINUED) (2830 - 2859) : REC. (2830 - 2860) 2832.05 44.9 11800. 2.18 54.4 24.9 79.3 2833.05 24.8 3.1 0.00 0.0 93.4 93.4 2834.05 44.6 11800. 1.79 50.2 28.1 78.3 2835.05 52.4 5910. 2.28 35.5 15.6 51.1 2836.05 55.7 7860. 3.01 36.7 12.2 48.9 2837.05 51.5 5110. 1.08 37.6 34.9 72.5 2838.05 38.3 245. 0.41 20.2 49.8 70.0 2839.75 26.5 130. 0.09 6.7 72.6 79.3 2840.1 44.0 1770. 2.60 48.7 18.7 67.4 2841.1 50.2 8150. 3.43 49.7 14.5 64.2 2842.05 48.9 6390. 2.74 42.7 15.6 58.3 2843.05 49.0 6180. 3.75 42.7 11.4 54.1 2844.55 46.9 4490. 1.80 40.4 22.4 62.8 2845.05 48.5 8530. 2.76 44.7 16.2 60.9 2846.05 43.8 2760. 1.36 38.7 28.5 67.2 2847.05 52.5 4790. 1.73 33.0 19.1 52.1 2848.05 51.3 7390. 2.91 40.1 13.8 53.9 2849.05 48.7 9490. 2.62 42.5 16.2 58.7 APPARENT SAND GRAIN DENSITY gm/cc at SIMULATED RESERVOIR STRESS SIMULATED ....................... RESERVOIR Air STRESS POROSITY Permeabilty psi PERCENT md. 2.64 1000 39.7 5850 2.68 1000 23.0 0.4 2.64 1000 38.6 7290 2.62 1000 41.2 4460 2.63 1000 50.4 4970 2.65 1000 41.3 3270 2.63 1000 32.5 174 2.67 1000 24.4 53 2.65 1000 37.1 719 2.63 1000 43.3 4100 2.61 1000 40.4 4930 2.63 1000 42.8 2980 2.70 1000 40.5 2520 2.64 1000 40.9 5080 2.67 1000 38.9 1140 2.65 1000 43.6 2330 2.65 1000 46.2 3120 2.64 1000 44.6 4540 DESCRIPTION Sd; fn-msd, prly cmtd Clst; cly-slt, well cmtd Sd; cly-fsd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; cly-fsd, mod cmtd Clst; cly-fsd, mod cmtd Sd; fn-msd, mod cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; vfn-fn, prly cmtd Sd; vfn-fn, prly cmtd COMPANY BP Alaska Exploration Inc. PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL Ugnu 3N-14 PAGE 8 FILE No. 70021 DATE June 16, 1986 ARCHIMEDES Air DEPTH POROSITY Permeability FEET PERCENT md. RATIO SATURATION % PORE SPACE OIL WATER TOTAL CORE NO. 6 (CONTINUED) (2830 - 2859) : REC. (2830 - 2860) 2850.05 48.7 6830. 1.91 38.5 20.2 58.7 2851.55 53.1 8650. 1.62 33.3 20.6 53.9 2852.2 48.7 11000. 2.37 41.2 17.4 58.6 2852.45 SECTION PRESERVED 2853.45 SECTION PRESERVED 2853.5 47.1 7490. 2.31 43.8 19.0 62.8 2854.05 46.9 7050. 2.11 44.1 20.9 65.0 2855.05 47.1 6640. 2.73 45.4 16.6 62.0 2856.05 41.2 1930. 0.57 28.3 49.8 78.1 2857.05 45.5 6630. 2.67 49.1 18.4 67.5 2858.05 44.1 2430. 2.98 52.4 17.6 2859.0 41.3 6640. 2.60 55.6 21.4 CORE NO. 7 (2859 - 2888) : REC. (2868 - 2888) 2868.1 47.9 2260. 0.94 35.9 38.2 2869.05 47.7 6520. 1.22 39.9 32.8 2870.05 46.7 8430. 1.34 45.0 33.5 2871.05 47.2 6920. 1.69 42.1 24.9 2872.15 48.4 5470. 1.44 42.4 29.5 2873.05 45.8 6670. 1.07 43.0 40.2 at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY PermeabiEty gm/cc psi PERCENT md. 2.64 1000 43.0 3270 2.65 1000 46.7 5090 2.64 1000 41.5 6950 2.65 1000 42.7 3500 2.65 1000 42.6 5040 2.64 1000 41.0 4910 2.50 1000 34.1 833 2.63 1000 39.6 4880 70.0 2.64 1000 40.0 1500 77.0 2.60 1000 37.7 2400 74.1 2.68 1000 38.8 1450 72.7 2.64 1000 39.6 2890 78.5 2.65 1000 41.1 4840 67.0 2.64 1000 42.1 4310 71.9 2.67 1000 42.1 4270 83.2 2.65 1000 40.5 4860 DESCRIPTION Sd; fn-msd, prey cmtd Sd; fn-msd, prly cmtd Sd; fn-msd0 prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prey cmtd Sd; vfn-msd, c Eam, mod cmtd Sd; fn-msd, prey cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; cly-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd COMPANY BP Alaska Exploration Inc. PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL Ugnu 3N-14 PAGE 9 FILE.No. 70021 DATE June 16, 1986 ARCHIMEDES Air SATURATION % PoRE SPACE DEPTH POROSITY Permeability O/W ....................... FEET PERCENT md. RATIO OIL WATER TOTAL CORE NO. 7 (CONTINUED) (2859 - 2888) : REC. (2868 - 2888) 2874.05 44.9 4950. 5.03 61.4 12.2 73.6 2875.05 47.4 5710. 2.41 45.3 18.8 64.1 2876.05 46.4 9060. 2.63 48.4 18.4 66.8 2877.05 50.6 5950. 3.97 45.3 11.4 56.7 2878.05 47.'8 8860. 2.57 46.3 18.0 64.3 2879.05 46.1 5190. 2.31 50.4 21.8 72.2 2880.05 50.2 7590. 2.66 44.7 16.8 61.5 2881.05 46.2 7300. 2.56 49.4 19.3 68.7 2882.05 46.3 5750. 2.63 46.9 17.8 64.7 2883.05 44.1 6330. 2.65 54.3 20.5 74.8 2884.05 43.9 4620. 2.44 53.0 21.7 74.7 2884.5 SECTION PRESERVED 2885.5 SECTION PRESERVED 2886.05 43.0 4760. 2.09 55.0 26.3 81.3 2887.05 42.3 3740. 2.47 52.3 21.2 73.5 CORE NO. 8 (2888 - 2913) : REC. (2888 - 2912.65) 2888.05 49.8 6990. 2.30 41.6 18.1 59.7 2889.5 33.9 10. ** 0.00 0.0 86.3 86.3 2890.15 44.7 5830. 2.60 55.1 21.2 76.3 at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeabilty gm/cc psi PERCENT md. 2.64 1000 39.2 4540 2.64 1000 41.3 5190 2.65 1000 39.5 7780 2.65 1000 41.2 2680 2.63 1000 41.9 4400 2.64 1000 39.4 3080 2.64 1000 42.7 4290 2.64 1000 39.6 5440 2.63 1000 39.9 4230 2.65 1000 40.1 4480 2.65 1000 39.0 4180 2.66 1000 39.2 3660 2.65 1000 37.5 3410 2.65 1000 42.5 4540 2.76 1000 30.5 7.0** 2.66 1000 40.7 5080 DESCRIPTION Sd; fn-msd, Sd; fn-msd, Sd; fn-msd, Sd; fn-msd, Sd; fn-msd, Sd; fn-msd, Sd; fn-msd, Sd; fn-msd, Sd; fn-msd, arty cmtd arty cmtd arty cmtd arty cmtd arty cmtd arty cmtd arty cmtd orty cmtd arty cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Clst; well cmtd Sd; fn-msd, prly cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY ' COMPANY BP Alaska Exploration Inc. PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS WELL Ugnu 3N-14 PAGE 10 FILE No. 70021 DATE June 16, 1986 ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeability O/W ....................... FEET PERCENT md. RATIO OIL WATER TOTAL CORE NO. 8 (CONTINUED) (2888 - 2913) : REC. (2888 - 2912.65) 2891.05 46.6 7280. 1.98 45.1 22.8 67.9 2892.05 48.5 5130. 0.95 40.5 42.7 83.2 2893.05 54.1 5730. 0.52 29.4 56.8 86.2 2894.05 50.2 6780. 0.70 36.9 52.7 89.6 2895.05 42.3 3827. 0.89 38.2 43.0 81.2 2896.05 52.8 11700. 1.12 39.7 35.3 75.0 2897.05 8.6 293. 0.00 0.0 30.0 30.0 2898.05 45.0 9220. 0.12 4.4 36.1 40.5 2899.25 40.4 4260. 0.27 11.2 41.5 52.7 2900.05 45.7 6100. 1.98 51.4 26.0 77.4 2901.05 47.4 13100. 3.44 56.8 16.5 73.3 2902.05 46.9 13100. 3.82 53.9 14.1 68.0 2903.05 47.0 11200. 4.84 59.1 12.2 71.3 2903.4 SECTION PRESERVED 2904.4 SECTION PRESERVED 2904.45 45.5 9470. 4.70 64.8 13.8 78.6 2905.05 38.2 3090. 0.21 12.5 58.7 71.2 2906.05 30.9 7.5 0.00 0.0 95.6 95.6 2907.05 32.5 15. 0.00 0.0 87.8 87.8 at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeabilty gm/cc psi PERCENT md. 2.65 1000 43.0 6160 2.66 1000 40.3 4830 2.67 1000 44.4 5650 2.66 1000 42.0 6250 2.67 1000 37.5 3500 2.66 1000 42.1 8010 2.64 1000 8.2 78 2.66 1000 40.0 7670 2.50 1000 35.1 3630 2.62 1000 39.9 5340 2.62 1000 42.8 10100 2.63 1000 42.5 10100 2.63 1000 39.0 9130 2.62 1000 41.4 7770 2.70 1000 33.8 1090 2.73 1000 28.3 2.1 2.73 1000 28.5 1.9 DESCRIPTION Sd; fn-msd, prly cmtd Sd; vfn-fsd, prly cmtd Sd; vfn-fsd, prly cmtd Sd; vfn-fsd, prly cmtd Sd; vfn-fsd, prly cmtd Sd; vfn-fsd, prly cmtd Cht-clst; well cmtd Sd-cbt; fn-msd, prly cmtd Sd; fn-crssd, c, prly cmtd Sd; fn-msd, prly cmtd Sd; fn-msd, prly cmtd Sd; vfn-msd, prly cmtd Sd; vfn-msd, prly cmtd Sd; vfn-msd, prly cmtd Sd; vfn-fsd, prly cmtd Clst; cly-vfsd, well cmtd Clst; well cmtd PETROLEUM TESTING. SERVICEr INC. COMPANY BP Alaska Exploration Inc. WELL Ugnu 3N-14 CORE ANALYSIS ARCHIMEDES Air SATURATION % PORE SPACE DEPTH POROSITY Permeability O/g ....................... FEET PERCENT md. RATIO OIL WATER TOTAL CORE NO. 8 (CONTINUED) (2888 - 2913) : REC. (2888 - 2912.65) 2908.0 32.6 11. 0.00 0.0 87.2 87.2 2908.4 SECTION PRESERVED 2909.4 SECTION PRESERVED 2909.5 34.9 10. ** 0.00 0.0 79.3 79.3 2910.05 34.9 10. ** 0.00 0.0 87.9 87.9 2911.05 32.1 4.1 0.00 0.0 87.2 87.2 2912.2 31.9 8.5 0.00 0.0 75.5 75.5 at SIMULATED RESERVOIR STRESS APPARENT SIMULATED ....................... SAND GRAIN RESERVOIR Air DENSITY STRESS POROSITY Permeabi[ty gm/cc psi PERCENT md. 2.72 1000 28.9 1.4 2.71 1000 30.1 7.0** 2.73 1000 32.9 7.0** 2.72 1000 28.8 0.7 2.70 1000 27.1 1.2 PAGE 11 FILE No. 70021 DATE June 16, 1986 DESCRIPTION Clst; well cmtd Clst; welt cmtd Clst; wet[ cmtd Clst; we[[ cmtd Clst; well cmtd ** FRACTURED, ESTIMATED AIR PERMEABILITY $ UB.$ URFA CE DIRECTIONAL SURVEY ~']UIDANCE ~]ONTINUOUS ~']OOL RE~.~F..JV ED AUG- ! 1986 Oil & Gas Cons, CommJssiq,~ Anchorage Company ARCO ALASKA, INCORPORATED Well Name 3N-14 (1561' FSL, 80' FEL, S29, Field/Location KUPARUK, NORTH SLOPE, ALASKA T13N, R9E~ UM Job Reference No. 71502 Loa{3ed By: SALAZAR Date 2-JUN-86 Computed By: KRUWELL * SCHLUMSERSER ~ GCT DIRECTI]N~L SUR~E¥ C~STOMER LISTINS ARC3 4LASKA, IN:. 3N-].~ KUP&RgK NORTH SLOPE~ALASKA SURVEY DATE: 15-MA¥-85 ENGINEER: S. SALAZ~R METHODS DF C3MPUT*TIO~ TOOL L2CATI]N: TAN2ENTIAL- AVERAGED DEVI&TION AND AZIqUTH INTERPOLATION: LINEAR VERTICAL SECTI2N: tORIZ. DIST. PROJECTED D~TD ~ T~RGET.AZIMUTH OF SOUT~ 82 DE5 52 MIN EAST CO~PUI'ATi 3~' OATE: 1-JJN-85, ARCO ALASKA,, INC. 34-14 K~JPARIJK NORTH SLOPE ~AL~S,KA INTERPOLATED VALUES FOR TRUE SJB-SEA MEASURED VERTICAL VERTICAL lEPTa' DEPT~ DEPTH 0.00 0.00 -68.00 130.00 100.00 32.00 200.00 200.00 132.00 300.00 300.00 232.00 ~00.00 400.00 332.00 500.00 500°00 432.00 500.00 600.00 532.00 700,00 699.99 531.99 800.0~ 799,99 .731'99 930.00 899.99 831.99 1000.00 999.98 931.98 1100.00 1099.98 1031.98 1200.00 1199.98 1131.98 1300.00 1299.98 1231.98 1600.00 1399.98 1331.98 1500.00 1499.38 1631-98 1530.00 1599.)8 1531.98 1700.00 1699.98 1631,98 1800.00 1799.98 1731.98 1900.00 1899.97 1831.97 2000.00 1999.96 1931.96 2100.00 2099.95 2031.95 2200.00. 2199.94 2131.94 2300.30 2299.~3 2231.93 Z¢00.00 2399.91 2331.91 2500.00 2499.30 2631.90 2600.00 2599.88 2531.88 2700.00 2699.86 2631.86 2800.00 2799.85 2731.85 2900.00 2899.~ 2831.84 3000.00 2999.83 2931.83 3130.00 3099.53 3031.83 3200.00 3199.~2 3131.82 3300.00 3299.82 3231.82 3400.03 3399.81 3331.81 3500.00 3499.81 3431.81 3500.00 3599.B1 3531.81 3700.00 3699.~0 3631.80 3800.00 3799.78 3731.78 3900.30 3899.~3 3831.43 EVEN'lO0 FEET COURSE VERTICAL OOGL DEVI~TI3N AZIMUT9 SECTION SEVE .3EG 4IN DEG Mil' FEET DEG/ 0 0 N 0 0 9 S 33 0 10 S 31 0 12 S 19 0 12 $ 63 0 13 S 80 0 17 S 75 0 ~2 S 59 0 31 S 38 0 30 S 2~ 0 E 1~ E 31 E 33 E 1~ E 45 E 41 E 0 19 0 15 0 10 0 7 0 7 0 11 0 t~ 0 18 0 Z6 0 ~B S 12 5 E S 2 27 W S I 28 W S 4 23 W S 15 30 W S 56 33 W $ 80 35 W N 86 20 W N 28 42 W N 9 57 W 0 54 0 ~8 0 ~,B 0 53 0 ~B 1 11 1 3 0 51 0 5O 0 5O N 5 51 W N B 5~ [~ N ? 1 E N 36 27 E N 51 49 E N 58 25 E N 62 13 E N 57 59 E N 70 13 E N 66 58 E 0 ,~6 0 ~1 0 35 0 23 0 31 0 31 0 25 0 37 2 24 6 32 0.00 O.OB 0.28 0.44 0.71 1.06 1.~9 2.04 2.71 3.32 3.71 3.82 3.83 3.85 3.85 3.74 3.39 2.82 2.39 1.94 1.57 1.18 0.82 1.36 2.22 3.57 5.13 5.60 7'82 9.12 10.28 11.37 12.34 13.08 13.81 14.61 15.30 16.06 17.98 25.gB N 65 5 N 55 13 N 67 37 N 7,5 1 N 58 39 N 68 18 N 76 7 S 81 47 S 75 65 OF EG RITY 100 .00 .25 .08 .05 .25 ,27 .17 .21 .27 .lq, .07 .10 .09 .18 .33 ,05 .13 .06 .15 .13 .65 .13 .iq, .17 .07 .12 .05 .13 .06 .09 .63 P&GE I DATE OF SURVEY: 15-M~Y-86 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: S. SALAZAR MEASURED RECTAN~ N3RTH/S FEET 0.0 0.1 0' 3 0.7 0.9 1.0 1.1 1.3 1.9 2.6 DEPTH U'LAR CDORDIYATES' H3~IZ, DEPARTURE OUTH EAST/WEST DIST, AZimUTH FEET FEET' DEG MIN 0 ~ 0.00 E 0.00,, 0 S 0,07 E 0.12 7 S 0.23 E 0.¢~ 0 S 0.36 E 0.78 6 S 0.59 E 1.13 6 S' 0.9~ E 1.~2 2 S 1.36 E 1.76 56 1.89 E 2.32 2 S 2.49. E 3.15 7 S 3.01 E 4.02 3.39 3.90 ¢.26 4.q.8 4.69 4.89 5.07 5.10 4.79 3.65 2.15 0.55 0.83 2.17 3.18 6.15 5.14 5.87 6.35 6.91 S 3.31 E 4.74, S 3.36' E 5.15 S 3.33 E 5.41 S 3.32 E 5.58 S 3.29 E 5.73 S 3.15 E 5.82 S 2-78 E 5.78 S 2.21 E 5.55 S 1.81 E 5.12 S 1.50 E 3.95 N 0 S 36 S 32 S 27 S 31 S 41 S 50 S 54, S 52 0 E 22 E 4 ' 14 27 24 ~ 30 E 23 E 22 E 26 E S 1.31 E 2.52 S 1.12 E 1.25 N 0.93 E 1.25 N 1.6q* E 2.72 N 2.63 E 4.13 N q,.12 E 5.84 N 5. BZ E 7,76 N 7.39 E 9.q.3 N 8.68 E 10.75 N 10.05 E 12.20 S 44, S 4O S 38 S 36 S 35 S 32 S 28 S 23 S 20 S 22 20 44 1 30 2 47 44 23 42 20 7.50 N 11.30 E 13.56 8.03 N 12.46 E 14.82 8.q.7 N 13.~9 E 15,93 8.71 N lq,.27 E 16.72 8.97 N 15.04 i 17.51 9.30 N 15.89 E 18.q,l 9.52 N 15.61 E 13.15 9.70 N 17.40 E 19.93. 9.86 N 19.36 E 21.72 7.84 N 27.17 E 28.28 S 31 S 63 ,q 37 ~ 39 N 48 N 51 N 53 N 55 26 50 14 4 33 47 32 33 48 30 N 56 N 57 N 58 N 59 N 59 ~ 60 N 60 N 63 N 73 24 E 12 E 53 E 35 E 12 E 39 E 11 E 51 E 0 E 56 E COMPUTATI3N DATE: 1-JJN-85 PAGE 2 A~CD ALASKAt I~C. DATE DF SURVEY: 15-M.~¥-86 3N-14 KJPARJK NORTH 5LOPE~ALaSKA <ELLY B~SHIN$ ELEfRTIDN: ENGINEER: S. SAL~ZAR' 58.00 FT"' INTERPOLATED VALUES FOR EVEN 100 FEET' DF. MEASURE3,DEPTfl, TRUE SdB-SEA COdRSE MEASURE3 VERTICAL VERTICAL DEVI&TI3N AZIMUTH 3EPTH DEPT~' DEPTH ~EG MIN DEG MIN VERTICAL DOGLEG RE;TANSULAR COORDINATES H3RIZ. DEPARTURE SECTION' SEVERIT¥,NDRTM/SDUTH EAST/WEST, DIST,' AZIMUTH FEET DE~IIOO FEET: FEET. FEET~ DEG MIN 4000.00 3998.36 3930.36 10 9 4100.00 6096.26 ¢028.26 13 22 4200.00 ~1~2.84 ~12~.84 16 30 4300.00 ~287.87 ~219.87 19 32 4~00.00 ~381.~0 ~313.~0 21 53 4500.00 ~473.~4 6605.44 23 58 4500.00 ~566.19 ~96.19 25 31 ~TO0.O0 6653.96 45~5.96 26 56 4900.00 ~742.11 ~67~.11 29 28 4900.00 6828.20 ~760.20 31 62 S 79 56 E $ 75 58 E S 77 19 E S 78 55 E S 79 45 E S 79 37 E S 79 43 E S 8~ 31 E S 81 35 E 40.41 3.60 60.64 2,58 96.34 3.2.9 117.34 2.69 152.66 2.22 191.69 1.95 233.62 1.06 277.59 1-95 32¢.73 2.55 375.58 4.81 N 41.33 E 41.61 N 83 21 E 0.67 N 61.20 E 61,20 N 89 22 E 5.26 S 86.35 E 86.52 S' 86 31 r 11.$7 S 116.80 E 117.38 S 8~ 17 17.83 S 151.62 E 152,66 S 83 17 ~ 24.~6 S 190.12 E 191.69 S 82 40 E 32,02 S 231.~3 E 233.64 S 82 7 E 39,87 S 27~,77 E 277.6~ S 81 44 E ~8.09 S 321.25 E 32~.83 5 81 29 E 55.99 S 371,50 E 375.59 S' 81 25 E 5000.00 ~911.88 ~8~3.88 34 ~3 51~0.00 ~992.37 ~92~.37 38 14 5200.0~ 5068.70 5000.70 42 4 5300.00 5141.09 5073.09 44 58 5~00.00 5210.73 5142.73 46 11 5500.00 5280.11 5212.11 45 56 5500.00 53¢9.84 5281.84 45 39 5700.00 5~19.95 5351.95 45 15 5830.00 5490.54 5¢22.54 44 55 5900.00 5561.57 5493.57 44 37 S 82 42 E S 82 25 E S 82 22 E S 80 19. E S 80 2 E S 80 29 E S 80 52 E S 81 ,~ E S 81 26 E ¢30.29 3.31 489.60 ~.05 55&.16 3.33 623.09 2.75 69~.77 0,22 766.71 0.~ 838.34 0.43 909,60 0.60 980.40 0.62 0'20 S 81 42 E 1050-77 63.~9 S 425.70 E ~30.~1 S 81 31 E 71.01 S 48¢.53 E ¢89.70 S 81 39 E 79.~5 S 5~8o5~ E 554.27 S 81 45 E 89.90 S 616.70 E 523.22 S 81.42 E 102.29 S 687.39 E 694.96 S 81 32 E 114.~7 S 758.37 E 766.96 $ 81 2~ E 126.~8 5 829.10 E a38.63 5 81'21 E 137.26 S 899.52 E 909.93 S 81 19 E 148.05 S 969.52 E 980.76 S 81 19 E 15~.33 S 1039.16 E 1051.15 S 81 20 E 6330.00 5632.78 556~.78 44 37 6100.00 5703.97 5535.97 44 33 6200.00 5775.19 5707.19 44 3~ 6300.00 5846.~7 5778.47 44 32 6~00-00 5917.B7 58~9.87 44 17 6500.00 5989.51 592[.61 43 55 6600.00 5061.a3 5993.83 43 39 6700.00 6134.29 5065.29 43 25 6800.3~ 6207.11 5139.11 43 9 6900.00 5280.24 5212.24 42 56 S 81 46 E 1120.98 S 81 ~5 E 1191.19 S 81 45 E 1261.38 S 81 48 E 1331.50 S 81 58 E 1~01.50 S 82 6 E 1~71.16 S 82 22 E 1540.33 S 82 22 E 1609.23 S 81 4~ E 1677.77 S 81 S E 17~5.95 0.11 0.19 0.25 0,15 0.33 0.45 0.25 0.51 0.78 0.14 168.~3 S 1108.65 E 1121.37 S 81 21 E 178.~6 S 1178.15 E 1191.59 S 81 23 E 188.51 S 12~7.62 E 1261.78 S 81 24 E 198.52 S 1317.0~ E 1331.92 S 81 25 E 208.~1 S 1386.35 E 1¢01.93 S 81 27 E 218.05 S 1455.35 E 1~71.59 S 81 28 E 227.~0 S 1523.88 E 15~0.76 S 81 30 E 236.51 S 1592.19 E 1509.66 S 81 33 E 245.89 S 1660.09 E 1578.20 S 81 34 E 256.17 S 1727.51 E 1746.~0 S 81 33 E 7000.00 5353.33 5285.33 43 16 7100.90 5425.94 5357.9~ ~3 31 7200.00 5498.35 5430.35 43 ~2 7330.00 5570.54 5502.64 43 37 7~30.00 $6¢3.32 6575.02 43 37 7~60.00 S686.~5 5618.45 ~3 37 S 81 11 E 1816o17 S 81 23 E 1882.90 S 81 42 E 1951.85 S 81 62 E 2020.92 S 81 42 f 2089.91 S 81 ~2 E 2131.31 0.57 0.33 0.20 0.00 0.00 0.03 266.69 S 1796.96 E 1814.65 S 81 32 E 277.16 S 1862.90 E 1883.~0 S 81 32 E 287.25 S 1931.13 E 1952.37 S 81 32 E 297.19 S 1999.50 E 2021.~6 S 81 32 E 307.14 S 2067.78 E 2090.46 S 81 33 E 313.11 S 2108.75 E 2131.87 S 81 33 E CD~PUTATI3~'DATE: 1-JJN-8$ 3 ~RSD ALASKAt ItC. 3~-14 KJPAR~K N~RTH. SLDPE~AL~SKA PAGE DATE DF SURVEY: 15-M,Y-85 KELLY BUS. HING ELE~'ATIDN: ENGINEER: $. SALAZAR INTErPOLaTED VALJES FOR EVEN 100~ FEET Dr MEASURED DEPT TRUE SJB-S~ CD~RSE ME~$URE~ VERTIS~L VERTICAL: )EVI.~TIDN AZIMUTH ~EPTH DEPTH DEPTH ~EG ~IN DEB 0.00 0.00 -SB.O0 0 0 IODO.O3 99g.98 931.98 0 19 2000.00 1999,96 1931.96 0 54 3000.00 2999.~3 2931.83 0 ~6 4000.00 3998.36 3930.36 10 9 5~0.00 ~911.88 ¢843,88 34 ~3 6000.00. 5632.78 556~.78 44 37 7000.00 $353.33 $285.33 43 16 7~.$0.0D ~$86.~5 SSIB.~5 43 37 58.00 FT' VERTICAL DOGLEG RECTANGULAR CODRDINATES H3RIZ.. DEPARTURE SECTION SEVERITY NDRTH/SDUTH EAST/WEST DISTo AZIMUTH FEET DEG/IO0~: FEET FEE'T FEET: DEG N 0 O E 0.00 S 12 5 E 3.71 N 5 51 W 1.57 N 65 5 E 1~.28 S 79 55 E 40.41 S 82 4Z E 430.29 S 81 ~ E I120.98 $ 81 11 E 1B1½.17 S 81 42 i t131,31 O.OO 0.21 3-13 0.17 3.60 3.31 D,11 O.OO 0'00 N 0o00 E 0.00 ~ 0 0 E 3.39 S 3.31' E ~,.74 S 4q. ZO E 2.15 S 1.31 E 2.52 S 31 26 " 7.50 ~ 11.30 E 13,56 ¼ SS 24 4.81 N 61.33 E ~1.61 N 83 al 63.69 S ~25.70 E ~30.61 S 81 31 [' 168.~3 S 1108.65 E 1121.37 S 81 21 E 266.69 S 179&.9~ E 1B1~.65 S 81 32 E 313.11 S 210B.75 E 2131.87 S 81' 33 ~ CDMPUTATIDN DATE: 'l-JJN-86 PAGE 4 ARCO ALAS~A~ INC. DATE 3F SURVEY: 15'M~¥,85 3N-14 KUPARdK ND2TH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: S. SALAZA2 58.00 FT INTEqPOL~TED VALUES FOR ~VEN 100 FEET 0= SUB-SEA DEPTH TRUE SJB-SEA CD,RS~ MEASU'RE3 VERTICAL VERTICAL 2E¥I~TIDN AZIM~'T4 DEPTH DEPT~' DEPTH 3EG VERTICAL DOGLEG RECTANSULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITi NDRTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IOD FEET FEET FEET' DEG MIN' 0.07 0.00 -$B.O0 0 '0 N 0 3 E 58.00 $8.00 0.00 0 8 S 37 2 E 158.00 168.00 100.00 0 10 S 31 51 E ~68.00 268.00 200'00 0 12 S 20 35 E 368.03 368.00 300.00 0 12 S ~9 49 E ~68.00 468.00 400.00 0 12 S 77 7 E 558.00 568.00 500.00 0 14 S 83 3~ E 558.00 668.00 600.00 0 20 S 6~ 7 E 758.01 768.00 700.00 0 31 S ~ 16 E 858.01 868.00 800.00 0 30 S 33 37 E 0.00 O.O0 0.03 3.11 0.21 3.02 0.39 0.25 0.60 0.22 0.94 0.08 1.34 0.08 1.85 0.13 2.49 0.20 3.14 0-17 0.00' N 0.00 0.03 S 0.02 0.29 S 0.18 O. 58 S 0.32' 0.90 S 0.50 1.04 S 0.82 1.10 S l.Z1 1.26 S 1.71 1.70 S 2.30 2.~3 S 2.8~ 0.00 N' 0 0 E 0.04 S 38 31 E 0.34 S 31 57 ~' O. 66 S 28 26 1.03 S 28 48 ~. 1.32 S 38 16 E 1.64 S 47 52 E 2.12 S' 53 33 E 2.86 S 53 30 E 3.75 S 49 44 E 958.02 968.20 900.00 1058.02 1068.00 1000.00 1168.02 1168.00 llOD.O0 1268.02 1268.30 1200.00 1368.02 1368.30 1300'00 1558.02 1468.00 1400'00 1558.02 1568.00 1500.00 1558.02 1668.00 1600.00 1758.02 17~8.00 1700.00 1858.03 1868.00 1BOO.O0 0 26 S 20 ~,B E 0 17 S" Z 4~, E 0 I1 S (, 25 W 0 7 S 4 29 W 0 6 S 10 32 W 0 9 S 39 48 W 0 L5 S 67 2 W 0 20 S 89 5 W 0 lB N ~0 D ~ 0 r, 5 N 12 28 W 3.62 0.45 3.79 0.09 3.83 O.OB 3.85 O.OB 3.85 3.80 3.53 0.22 3.00 0.05 2.53 0.45 2.08 3.19 S 3.;>5 E 3.7~+ S 3.35 E 4.16 S 3.3q.~ E 4.r+l s 3.33 E 4.52 S 3.30 E 4.83 S 3.23 E 5.03 S 2.93 E 5.10 S 2.39 E 4.96 S 1.93 E 4.09 S 1.58 E ~.56 S 45 32 E 5.03 S 41 53 E 5.33 $ 36)45 E 5.53 S' 37 0 E 5.68 S 35 34 E 5.81 S 33 45 E 5.82 S 30 15 E 5.63 S 25 6 E 5.32 S 21 12 E 4.38 S 21 11 E 1958.0~. 1968.00 1900.00 2068.05 2068.00 2003.00 2158.05 1168.00 2100.00 2~58.07 2268.00 2200.00 2358.~B 2368.O0 2309.00 2~$8.10. 2468.00 2403.00 2558.12 2568.30 2509.00 2558.13 2668.00 2603.00 2768.1½ 2768.00 2703.00 2858.15 2868.00 2800.00 0 53 0 55 0 ~8 0 54 0 ~6 1 8 1 5 0 55 0 ~3 0 ~9 N 553W N 7 32 W N B 57 W N 3¢ ~,6 E N 50 5 E N 58 5 E N 59 39 E N 67 32 E N 70 27 E N 57 13 E 1.68 0.17 1.30 0.35 0.90 0.22 1.13 9.16 1.91 0.26 3.06 0.13 4.67 0.60 $.17 0.35 7.44 0.45 B.71 0.23 2.65 S 1.36 E 1.03 S 1.19 E 0.38 N 0.96 E 1.76 N 1.35 E 2.91 N 2.28 E 3.80 ~ 3.56 E 4.86 N 5.31 E 5.58 ~ 6.93 E 6.21 N B.2B E 6.73 ~ 9.62 E 2.98 S 27 14 E 1.57 S' 49 6 E 1.03 N 68 5 E 2.ZZ N 37 38 F 3.70 N 38 7 E 5.21 4 43 8 E 7.20 q ¢7 32 E 8.95 ~4 50 39 E 10.35 N 53 6 E 11.74 4 55 1 E 2958.16 2968.30 2900.00 3068.17 3068.00 3000.00 3158,18 3168.00 3100.00 3258.18 3268.00 3200.00 3358.19 3368.00 3300.00 3558.19 3468.30 3400,00 3558.19 3568.00 3500.00 3558.20 3668.00 3500.00 3758.21 3768.00 3703.00 3858.39 3868.00 3800.00 0 ~5 0 q2 0 35 0 25 0 32 0 31 0 29 1 15 5 25 N 63 55 E N 65 31 E N 65 45 E N 75 SE N 68 5 E N 58 ~,B E N 75 48 E N 78 0 E N Sq. 17 E S 7~ 28 E 9.92 0.31 11.04 0.12 12.06 0.32 12.87 13.56 0.26 14.35 O.O~ 15.OB O.OB 15.77 O.BO 17.02 2.I1 22.71 3.81 7.33. N 10.92 7.87 N 12.11 8.35 N 13.19 8.56 N 16.05 8.86 N 14.77 9.19 N 15.52 9.¢6 N 16.39 9.52 N 17.09 9.91 N' 18.39 E 8.69 N 23.97 E 13.15 N 55 8 E 14.~4 N 55 58 E 15.61 q 57 40 E 15.50 N 58 21 E 17.23 N 59 3 E 18.12 N 59 30 E 18.92 N 59 59 E 19.61 N 60 37 E 20.89 N 61 40 E 25.50 t ?O ~ E COMPUTATI3N DA[E: 1-JJN-86 PAGE 5 ARCO ALAS<A, IqC. 3~-14. N$RTH SLOPE,ALaSKA TRUE SUB-SEA COJRSE MEASURED VERTICAL VERTISAL 3EVI~TI3N AZIMUTH DEPTH DEPT~: DEPTH 3EG DATE DF SURVEY: 15-M~Y-85' KELL¥.BU'SHING ELE~ATION: ENGINEER: S. SALAZAR 58.00 FT' INTERPOLATED VALJES FOR EVEN 100 FEET: OF SUB-SEA DEPTH VERTICAL DOGLEG . RECTANGULAR COORDINATES H3RIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST- A2,IMUTH 3959.21 3968.00 3900.00 9 0 S 78 28 E 4071.01 %068.00 4000.00: 12 21 S 77, 5 E ~174.15 ~168.00 ~100.00 15 %2 S 77 ~ E ~27B,93 ~268.00 ~203.00 18 59 $ 78 31 E ~395.60 ~368.00 ~300.00 21 33 S 80 33 E 4694o05 ~468,00 ~00.00 23 51 S 79 ~7 E ~604.23 6568.00 6500'00 25 33 S' 79 38 E 4715.75 6568.00 6600'00 27 17 S 79 ~ E 4829.83 ~768.00 ¢700.00 30 11 S 80 51 E 69~7.1¢ 6858.00 ~800.00 33 I S 82 0 E FEET DES/lO0 FEET; FEET'., FE:T' DEG MIN 5059.25 ~968.30 ~900.00 37 ~ 5199.05 5058.00 5000.00 42 2 5338.35 5168.00 5103.00 45 ~5 5~82.57 5268.00 5200.00 45 58 5626.~0 5368.00 5300.00 ~5 3~ 5758.11 5~68,00 5400.00 45 ~ 5909.03 5568.00 5500.00 ~4 37 6~9.50 5668.00 5600.00 44 37 6189,91 576B,00 5709,00 ~4 34 6330.22 5868.00 5800.00 44 31 35.2'9 3-63 5~+. 22 ~+.06 79.24 z.g9 110.34~ Z.96 147.39 Z.31 189.28 1.9'7' 235.44, 1.07 28~.75. Z.2D 339.55 2.25 400.82 3.13 S 82 35 E 470.85 S 82 22 E 553.5~ S 80 ~ E 650.40 S' 80 25 E 75~.18 S BO 55 E 856,93 S 81 18 E 957,86 S Bt ~3 E 1057.11 S 81 ~ ~ 1155.7~ S 81 ~5 E 125~.30 S 81 53 E t352.70 5669,g7 5968,00 5903.00 6538.53 6068.00 5003,00 43 37 67~6.33 5168.30 5100.00 43 15 6883.28 5268.00 6203.00 42 56 7020.18 6368.00 ,5300.00 ~3 20 715B,0~ 5468.30 5~00.00 ~3 37 7296,35 5558,30 5533.00 43 37 74.34.51 5668.00 6600.00 4.3 37 7~S0.00 5686. %5 $$18.45 43 37 S 82 G E 1450,30 S 82, 23 E 1565.21 S 82 10 E 16~1,02 S 81 7 E 1734.57 S 81 11 E 1828.02 S 81 36 E 1922.BB S 81 ~2 E 2018.40 S 81 42 E 2113,72 S 81 ~2 E 2131,31 3.7~, 3.3% 1.55 0.35 0.70 0.42 0.1.~ O. 2.3 0.31 0.25 0.57 0.25 3.53 0.19 0.35 0.3¢ 0.00 0.00 O.O0 5,77 N 36,29 E 36,74 N BO 57 E 2,19 N 5%,92 E 5%,96 N 87 42 E 3.57 S 79.39 E 79.~8 S 87 Z1 ~ 10.31 S 109.91 E llO.~O S 84 38 16.97 S 145.41 E 147.39 S 83 23 : 24.03 S 187-75 E 189.28 S 82 42 : 32,35 .S 233.23 E 235.~7 S 82 6 E 41.15 S 281.82 E 2BG.B1 S B1 41 E 50,~8 S 335.88 E 339.65 S 81 Z7 E 59.59 S 395.48 E ~00'94 S 81 27 E 68,55 S 465,95 E ~70'96 S 8'1 37 E 79,37 S 5&7.93 E 553,55 S 81 45 E 9~.'59 S 643.6~ E 550.55 S 81 38 E 112.39 S 746.00 E 75~.~2 S 81 25 E 129.01 S 847,~7 E 857.23 S 81 20 E 144,65 S 947.22 E 958.21 S 81 lB E 159.24 S 1045.43 E 1057,69 S 81 20 E 173.60 S 1143.06 i 1156.14 S 81 22 i 187.~9 $ 1240.&2 E 1254.71 S 81 24 E 201,54 S 1338,03 E 1353,12 S 81 26 E 215.18 S 143~.69 E 1~50.7~ S 81 28 E 228.18 S 1529.7Z E 1545.6~ S 81, 30 E Z40.76 S 1623.69 E 15~1.~ S 81 33 E 254.~0 S 1716.25 E 1735.01 S 81 34 ~ 268.81 S 1808.6~ E 1828,50 S 81 32 283.05 S 1902,45 E 1923.39 S 81 32 E 2~6,83 S 1997,00 E 2~18,94 S 81 32 E 31O,57 S 2091,3~ E 2114.28 S 81 33 E 313,11 S 2108,75 E 2131,87 S 81 33 E COMPUTATION DARE: 1-JJN-B6 P~GE 6 ARCO ALASKAt INC. 3~-14 KgPARJK NO2TH SLDPE~ALASKA MARKER TOP KUPARUK 2 BASE KUPARUK C TOP KUPARUK A BASE KUmARUK A PBTD DATE OF S~RVEY: 15'M&Y-85 KELLY BUSHING. ELEVATION: SBoO0 FT ENGINEER: $o SA:LAZAR INTERPOLATED VAL~ES FOR CHOSEN H2RIZ2NS ~EAS2RED DEPTH BELOW KB SURFACE LOCATION ORIGIn: 1561 FSL., BO FEL SEC Z)) TI)N, R'gE~,UM FROM KB SOB-SE~ NORTH/SDUT~ E~ST/WEST 5955.D0 7008.00 ?080.00 7235.00 7356.D0 7660.00 5320.49 $252.49 251.97 $ 1754°56 E 5359.14 $Z91.14 2~7.53 S 1800,37 E 6411.4~ $~3.~4 275.08 S 18~g.Z~ E 6523.65 5~55.$5 290°73 S 1955.05 E $611.18 5543o18 302.'75 S 2037.73 E 5686.45 $518o45 313.11 S 2108.75 E COMPUTATI3N DATE: 1-JJN-86 P~GE 7 ARCO ALASKA, INC. 3N-14 K~PARDK NORTH SLOPE~AL~SKA MARKER TOP BASE TOP ~ASE TO KUP~RUK C KUPARUK C KUPARUK ~' KUPARUK A MEASURED DEPTH BELOW KB 6955.D0 7008.00 7080.00 7235,00 7356.00 7660o00 DA'TE OF SURVEY: 15-M~Y-85 KELLY BUSHING ELEVATION: $8.00 FT ENGINEER: S. 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J Ji~ ! ! ~ ' i ~ i ~ ~ i i ~ ~-~'"~-~'4'" '-4..-~-;.. -~..-~-~...~-.;~ ~ ~ ~ i ! !' 4'"~'"~'"; "'~' T ~ 't 'T ~ T'T"-%~ %F'~ ~%'T'7 '"T '7"T"~ T-T'"%~ T -T T-T-%f T-T-% ? 7"t FT FT"T '"T"~'"T"~-"?'%'~-'7'"7 ...... ?'T'%'T"t"'T-7'?"; ...... f-'~%'-T"t"%'%T'"r' 'T'":'-'~-'T"T"T'"r"?; .... ?-"r"?-T-'t-'T";-"T"T ...... %'T"?'t"T"T"T"?7 ...... F"r"T"7"f ...... T";"~ ...... T";" T'";" r"T' ?"F'T'- ~'"?+++'+?+--+ ....... ?++'?h'*+?"?'~'~'"??+?',?++'?++'?-?~"+-?~ ...... ~'-+"?*"~"-~'"?;'"'~++"+"?e'+'?'??~ ...... ?"~ ....... ~'","'+'"?'+'"+ ...... ? ....... e-"t".4'"~"',---,'-' ~.?.f-1..~f.1...f..+".h~-.:.~.f..~.~+.?.~..f.+,.f..f...~..~?...f+t.~f..~-hf.~.~...f?.f.1...f..f.4-~f ....... +'"~'"?"fi"'t"'f"f'"~"l"'f -]000 -500 0 500 1000 IS00 2000 2500 ~000 EAST 1 198(; Anchoraoe : .'.q -':q L' ) FIELD' 2 )'2-? 2 13, o .5 _ 8),~ 72 :?. 0 ~' PKS S:~[PLING LIST Page ~ of .__ ,"-/,~/% . o Page DATE: ~..~Z' ~7. oC ~v~ o0, o_<" 0 _~5) 86) _89) 28) 144) STATE OF ALASKA AL/-,,.,&,, OIL AND GAS CONSERVATION CON, M,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ;% Perforate~ Pull tubing Alter Casing ~. Other~ Complete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360 Anchorage: AK 99510 4. Location of well at surface 1561'FSL, 80'FEL, Sec.29, T13N, RgE~ UM At top of productive interval 1299' FSL, 1685'FWL, Sec.28, T13N, R9E, UM At effective depth 1258'FSL, 1958'FWL, Sec.28, T13N, R9E, UN At total depth 1248'FSL, 2029'FWL, Sec.28, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 68 ' 6. Unit or Property name K~p~r,~b I~i,.,er I~n~- 7. Well number 3N-14 8. Approval number 131 9. APl number 50-029-21589 10. Pool Kuparuk River Oil Pool Feet/, 11. Present well condition summary Total depth: measured 7460 true vertical 6686 Effective depth: measured 7356 true vertical 6611 Casing Conductor Surface Length 80' 2542' 7440' Production feet feet feet feet Size 16" 10-3/4" 7" Plugs (measured) None Junk (measured) None Cemented Measured depth 238 sx CS II 1lO'MD 1150 sx AS III & 2579'MD 150 sx Class G Top job w/lO0 sx AS I 660 sx C1 ass G & 7440'MD 175 sx AS I ~ue Vertical depth 110'TVD 2579'TVD 6672'TVD Perforation depth: measured 7104 'MD 7106'MD true vertical 6429 'TVD 6430 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail L~ 6929' Packers and SSSV (type and measured depth) HB pkr @ 6859' & FVL SSSV ¢ 1790' 7108'MD 7144'MD 7155'HD 7134'HD 7146'MD 7168'-7202'MD 6432'TVD 6458'TVD 6466'TVD 6450'TVD 6459'TVD 6475'-6499'TVD RECEIVED 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure AUG- 1 1986 Naska 011 & Gas Cons. Commission Anchorage 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well History w/Addendum, dated 6/9/86) Daily Report of Well Operations~ Copies of Logs and Surveys Run ~ Gyz:o 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer (DAM) SW0/077 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an o~ficial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ~Title AFE AK1215 Nordic 4 Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun J Date Complete I Date and depth as of 8:00 a,m. 7/12/86 thru 7/13/86 Complete record for each day reported Old TD New TD Released rig Date North Slope Borough ADL Completion Accounting cost center code State API 56.24% 7/12/86 Alaska I otal number of wells (active or inactive) on this DSt center prior to plugging and bandonment of this well our l Prior status if a W.O, 2300 hrs. 7" @ 7440' 7356' PBTD, RR Diesel Accept rig @ 2300 hrs, 7/12/86. ND tree, NU & tst BOPE. RU DA, perf f/7182'-7202' 7168'-7182', 7146', 7155', 7134', 7144', 7104', 7106' & ;108' w/4" guns, 120° phasing, RD DA. Rn 2-7/8" CA & ind. Set pkr, tst tbg to 2500 psi. Tst SSSV. ND BOPE, NU & tst tree. Displ well to diesel. RR @ 2400 hrs, 7/13/86. (Note: SSSV @ 1790', HB pkr @ 6859', TT @ 6929'.) RECEIVED AUG- I 1986 Alaska 0ii & Gas Cons. Commission Anchorage PB Depth Kind of rig 7356' PBTD 2400 hrs. 7/13/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official rese~oir name(s) Flowing .Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date . ITitle Drilling Supervisor ADDENDUM WELL: 5/12/86 5/16/86 3N-14 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak. Rn 6-1/8" gage ring/JB to 7334'. Rn CET f/7334'-5882'. Rn GCT gyro f/7280'-surf. RECEIVED AUG-1 1986 Alaska 011 & Gas Cons. CommJssjc,:; Anchorage Drilling Supervisor Date BP Alaska Exploration. Inc. 100 Pine Street, San Francisco, California 94111 . 'Telephone (415) 951-4200 July 15, 1986 AOGCC 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Fran Jones Dear Ms. Jones, Please find attached a report detailing the core analysis from the Ugnu formation in well 3N-14. BP Alaska Exploration have assumed ARCo's reporting duties for their core operations in this well as per ARCo's letter to your Mr. Chatterton of April 18, 1986. Should you require any further information regarding the above do not hesitate to contact me. Yours sincerely, P. Roberts Manager Petroleum Engineering PR:DMO:nfe c.c.: Well File 3N-14 DAILY IN"-~NTORY TRANSACTION FQRH ,----r-- /.,?. 1/ j, --, -, · ' '" "'~ '" ///:-Z7 ,-' / REQUESTED Bf___~_O_-~.~._.__~_~5_--L_/~/ .... '~"- DATE .......... CORP,ID. CARRIER REC,DATE ___/ .... / .... !,NTERV~. If~ER, VAL QTY QTY QTY PTS ,,~-qjSE NL~BER FROH TO F/M FROM TO O/H F'LT QTY LOCATION PTS ,.~-JJSE NLrMBER DEsrG.'IPTioN ! . STA~JS ____ INTEEq. N~L !Ni'ERk.~L QTY FROM TO F/M FROM QTY TO QTY O/H PLT QTY ___RECEIVED __SHIPMENT _~DELIVERY ___TRANSFER ___PICK-UP TRANSACTION DATE -7 - ~ 4/, ':.'>~1' __~_t_/__: 1~%_~ EXPIRATION DATE TRANSACTION DATE LOCATION DESCRIPTION STATUS ___/ .... /___ EYBIRATION DATE PTS HC4JSE NUMAR !NTE~JAL FRO~ !NTE,~.JAL QTY QTY QTY F'LT TO F!M FROM TO O/H QTY TRANSACTION DATE LOCATION [ESC$;IPTIrjN' STATUS .... / .... / .... EXPIRATION DATE PTS HO~ ~.~E INTERVAL FRO~ !,NTERVAL QTY QTY QTY PLF TO FiM ~OM TO O/H QTY TRANSACTION. DATE LOCATION Il ~, r,~- UESrJ.Ir, ION STATL~ .... / .... /___ EXPIRATION DATE RECE!-'-.ED BY~, [EL!VERED BY; , / WHITE: Data Processing CANARY: Main Billing File PINK: Sample GOLD: Lab File ...... STATE OF ALASKA AL~-. , .... OIL AND GAS CONSERVATION CO,.,,vi,$SlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~- Suspend ~ Operation Shutdown ~ Re-enter suspended well - Alter casing '-' Time extension ~ Change approved program ~ Plugging C Stimulate © Pull tubing- Amend order-' Perforate-- Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0 · Bo× ] 00360 Anchor'aoe . AK 4. Location of well at surface 5. Datum elevation (DF or KB) 68' RKB . KU 7. 1561'FSL, 79'FEL, Sec.29, T13N, RgE, UM ~N At top of productive interval 8. 1327'FSL, 1792'FWL, Sec.28, T13N, RgE, UM (approx.) 86 At effective depth 9. APl number 1327'FSL, 1958'FWL, Sec.28, T13N, R9E, UM (approx.) 50429-21589 At total depth 10. Pool 1318'FSL, 2030'FWL, Sec.28, T13N, R9E, UM (approx.) Kuparuk River Oil Unit or Property name p~rub Riv~- Ilnit Well number -14 Permit number -86 Pool 11. Present well condition summary Total depth: measured 7460 true vertical 6687 Effective depth: Casing Conductor measured true vertical 7356 6612 Length 80' Surface 2542' feet Plugs (measured) None feet feet Junk (measured) feet N o n e Size Cemented Measured depth 16" 238 sx CS II 110'MD 1 0-3/4" 7" Production Perforation depth: 7440' measured N o n e true vertical N o n e Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) Non e 1150 sx AS I I I & 2579'MD 150 sx Class G Top job w/lO0 sx AS I 660 sx Class G 7440'MD RECEIVED MAY 2 8 ]986 Alaska 0ii & Gas Cons, Commission Anchorage True Vertical depth 110'TVD 2579'TVD 6673'TVD 12.Attachments Well Hi story Descrilbtion summary of proposal [] Detailed operations program ~ BOP sketch .,_% 13. Estimated date for commencing operation July, 1986 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 J~ F/~r~ ~ Title Associate Engineer Commission Use Only ( DAM ) SA/042 Conditions of approval Approved by Notify commission so representative may witness II Approval No. /~/ Q Plug integrity [] BOP Test [] Location clearance . '" i;~,~_ Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate and Gas COmpany ,~,~ Well History-Initial Report-Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District i County. parish or borough Alaska ILease North Slope Borough Field or Unit Kuparuk River ADL 25520 Auth. or W.O. no. Tit e AFE AKi215 Drill IState Doyon 9 API 50-029-21589 Operator ARCO W.I. ARCO Alaska, Inc. Spudded or W.O. begun IOate IHour Pr or status if a W.O. Spudded I 4/27/86 I 1645 hrs. Date and depth as of 8:00 a.m. 4/27/86 thru 4/28/86 4/30/86 Alaska Well no. 3N-14 5/ol/86 5/02/86 56.24% Complete record for each day reported 16" @ 110' 1191', (1081'), Drlg Wt. 9.7, PV 15, YP 18, PR~9, WL 14.4 Accept rig @ 1415 hfs, 4/27/86. NU diverter sys. Spud well @ 1645 hrs, 4/27/86. Drl 13½" hole to 1191'. 499', .5°, S64.8E, 499 TVD, 2.07 VS, .93S, 1.94E 1014', .5°, S 5.7E, 1013.98 TVD, 5.12 V$, 4.62S, 4.58E 10-3/4" @ 2579' 2600', (1409'), Perform top Job Wt. 9.4, PV 18, YP 16; PM 9, WL 13.6, Sol 8 Drl & surv surf hole to 2600', short trip, C&C, POOR. RU & rn 62 Jts, 10-3/4", 45.5#, K-55 BTC csg w/FC @ 2496', FS @ 2579'. Cmt w/llS0 sx AS III, followed by 150 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. ND divert,r, perform 100 sx AS I top Job. 1518' 1° S58 3W, 1517 97 TVD, 4.26 VS, 6.97S, 3.42E ~e , · · 2021' .9° , , N 4.4W, 2020.95 TVD, .13 VS, 4.98S, .49W 2600' .9° N64E, 2599 88 TVD, 3.64 VS, 2.91N, 4.03E , 9 · 10-3/4" @ 2579' 2806', (206'), TIR w/core bbl Wt. 8.6, PV 6, YP 4, PR 9.5, WL 6.0, Sol 2 NU & tst BOPE. TIE, tst csg to 2000 psi. DO cmt & flt equip + 10' new hole. Conduct formation tst to 11.5 ppg EMW. Drl to core pt @ 2722', CBU, POOH. PU core bbl, cut core #1 f/2722'-2746'. Core #2, 2746'-2776'. Core #3, 2776'-2806'. RIH w/core #4. 10-3/4" @ 2579' 2911', (105'), POOH w/core #8 Wt. 8.6, PV 11, YP 4, PR 9.0, WL 4.8, Sol 3 Core #4 f/2806'-2821', rec'd 15'. Core #5, 2821'-2826', packed off, rec'd 6". Drl to 2829'. Core #6, 2829'-2857', rec'd 28'. Core #7, 2857'-2886', rec'd 29'. Core #8, 2886'-2911', rec'd 25'. 10-3/4" @ 2579' 3692', (781'), Logging West Sak Wt. 8.8, PV 8, YP 3, PH 9.0, WL 5.8, Sol 3 Drl 9-7/8" hole f/2911'-3692', short trip, C&C, POOH. RU Schl, rn LSS f/3652'-2580' GR f/2580'-1400',,DIL/SFL f/3670'-2579', LDT/EPT/CNL~NGT The above is correct ~ t',l Signat e For fo~ I~epa~mn and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate / I Title Drilling Supervisor ARCO Oil and Gas Company 4} Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District lCounty or Parish Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ITitle AFE AK1215 Doyon 9 Operator I AR.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~Oate Spudded I 4/27/86 2200 hrs. 5/03/86 thru 5/05/86 Date and depth as of 8:00 a.m. Old TD Complete record for each day reported North Slope Borough Released rig Classifications (oil, gas, etc.) Oil Producing method Flowing Accounting cost center code State Alaska ADL 25520 Drill API 50-029-21589 Well no. 3N-14 I otal number of wells (active or inactive) on this cst center prior to plugging and I bandonment of this well I our ~Prior status if a W.O. 1645 hrs. I 7" @ 7440' 7460' TD, 7356' PBTD, RR 9.9 ppg Brine R/D Schlumberger Drld 8½" hole to 7460'. Ran DIL/GR/SP/SFL/GR f/7459'-6650', FDC/CNL f/7459'-6650'. R/D. Chg top rams to 7" & tst. RU & rn 182 its, 7", 26#, J-55 BTC csg w/FC @ 7357', FS @ 7440'. Cmt w/460 sx 50/50 C1 "C" w/8% D-20, .5% D-65, .2% D-46 & .5% D-112. Tail in w/200 sx C1 "G" w/3% KC1, .9% D-27, .3% D-13 & .2% D-46. Displ w/9.9 ppg brine wtr, bump plug. ND BOPE, instl pack-off & tbg head. Tst flange to 3000 psi. RR @ 2200 hfs, 5/5/86. 3064, .8°, N76.3E, 3063.83 TVD, 9.78 VS, 5.24N, 10.51E 3676-, .6°, N18.1N, 3675.78 TVD, 12.58 VS, 11.77N, 14.45E 3863, 4.7°, 572.0E, 3862.58 TVD, 17.88 VS, 17.89N, 20.26E 4051, 11.2°, 578.9E, 4048.77 TVD, 43.66 VS, 11.36N, 45.43E 4240, 17.4°, 578.7E, 4231.91TVD, 90.23 VS, 2.29N, 91.22E 5179, 41.2°, 584.3E, 5055.52 TVD, 529.47 VS, 57.30S, 526.43E 5304, 44.7°, 580.9E, 5147.01TVD, 614.64 VS, 68.27S, 610.89E 5678, 45.5°, 584.0E, 5411.01TVD, 879.55 VS, 103.08S, 873.51E 6251, 44.5°, 583.2E, 5816.18 TVD, 1284.24 VS, 148.24S, 1276.18E 6566, 43.7°, 84.0E, 6042.29 TVD, 1503.88 VS, 172.68S, 1494.01E 7074, 43 8°, 84.3E, 6409.35 TVD, 1855.08 VS, 208.98S, 1843.47E 7460, 44.1°, 80.9E, 6687.25 TVD, 2122.97 VS, 242.98S, 2109.13E INew TD Date PB Depth 7460' TD I Kind of r~g 5/5/86 , Single Officialrese~oirname(s) &i~L~i{~ (~ii ~: i.~;;} {?.}:i~. ~0~l~lSS~(~i: Kuparuk Sands ~"¥;!';f~f2{l¢ Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. i Water % GOR Gravity Allowable Effective date corrected _. The above is correct For form preparation and distribution, see Procedures Manual, Section Drilling, Pages 86 and 87. Drilling Supervisor ARCO Alaska. inc. Post Office Box 100360 Ancl~orage. Alaska 99510-0360 Telephone 907 276 1215 DATE 05-13-86 TRANSMITTAL # 5658 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tapes Plus Listings: Schl: One of each Please note: These tapes are both labeled as EDIT LIS Tapes--According to Schl. they are regular Open Hole tapes since we have received no previous tapes. 3N-12 04-20-86 Run #1 1689.0-8131.f~o~~-3--d~~3- I g~-- F/J/ This tape is a standard Open Hole LIS plus listing. Re ceipt Ac3~nowie dged: State ~_of AK Da~e: PKS SAP~LING LIST Page 'g.of 1 ) ~_T, ~ Lo ,<O.~ '37) 73) _109 ..,--,. ~, ,..0.~'- 38) 74) ._110) ..3) 2 %'$ %', ~ 39) 75).. . 4).2_~% 9,,/~-- 40) 76) .... 5)~ O, O~ 41) . 77) 113) , ~)~ %?I, ~ 42) 78) . , _ - gl, 43) vg) . . s~": e o~ 44), so) }]~, / ~ /, . . ~o)~ '~,% ~ 46) :.~2) . ~]s) · 13) ~.- .... ~6) ~ ? 0~,-0/ .~2.). .. ~s) ~2~).. ~" ~0~ .56), ~ 92) .Zl)~9:.~. d ~ 57) 93) ~.~ .. . ~ b 58) , .941 . .~'o, 59) 95.) _ 28) -I 64) lOOl~ t '.. l~ " 136) .. t~O) 66) ] . 31) 67) 103) ]3q/ , 32) 68) , , 104) _ ~3) 69) .... 1055 1415 3~) 70) , 106) L 142) [35) " _71). '.I 107) 143) . ~3~) I 72) ~' 108) .144) :,~z:TO 0~ -1 pETb(UL, P-,U£'i lt'.,b.L.L:,t-, ob. ..... FKS S>2;~LiNG LIST --t~"----- 975~ o ","'7'g ,0~ oK- i 74),2777, 75).~,0. 7 ~ "~/, _77) ,.2 "'"}f ~t~..; 78),g % o l., o s'~ 79)..:' ?. O~ .: ,.. ,~ , :.' _ 81).2'.5o"/ cc> -L ~'o 9, o5--' Page DATE ,-,. :.,,: ! ?. April 25, 198g Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3N-14 ARCO Alaska, Inc. Permit Mo. 86-86 Sur. Loc. 1561'FSL, 79'FEL, Sec. 29, T13N, R9E, UM. Btmhole Loc. 1295'FSL, 2047'FInaL, Sec. 28, T13b!, R9E, U~.~. Dear Mr. Kewin: 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 pe_rmits required by law from other governmental 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. I~here a diverter system is required, -=~ 24 hours prior to commencing please also notify this oJ.~._ equipment installation so that the Cor~nission may witness testing before drilling below the shoe of the conductor pipe. · Ver~z tru~y-~zpnrs. ~ C. V. ~tt~rtOn: Cha i~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE CO~-!ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery April 18, 1986 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: 20 AAC 25.071 Geologic Data and Logs Dear Mr. Chatterton' ARCO Alaska, Inc. plans to core the Ugnu in Kuparuk Well 3N-14 for BP Alaska Exploration and Standard Alaska Production Company. Under this arrangement, ARCO as operator, would perform the coring and immediately give the recovered core to BP. BP and Standard would own the core and be responsible for all costs and liabilities associated with collecting it. in 20 ACC 25.071, the operator is required to file certain core data with the Commission. in this case, however, the core data would not be available to ARCO. As a result, ARCO and BP jointly request permission for BP to assume ARCO's reporting duties for the Ugnu core in Well 3N-14. Please advise Hal Blacker (263-4299) with ARCO, or John Miller (258-7200) with BP, if this reporting procedure meets your approval. Either may be contacted if you have any questions. Sincerely, J. C. Havard Engineering Manager New Projects Engineering ARCO Alaska, Inc. Area Manager BP Alaska Exploration JCH' PSW-cph 0020 cc' H. Kugler AOGCC L. Smith AOGCC RECEIVED APR 2 1 198 Alaska Oil & Gas Cons. Commission Anchora.qe April 18, 1986 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE' 20 AAC 25.071 Geologic Data and Logs Dear Mr. Chatterton' ARCO Alaska, inc. plans to core the Ugnu in Kuparuk Well 3N-14 for BP Alaska Exploration and Standard Alaska Production Company. Under this arrangement, ARCO as operator, would perform the coring and immediately give the recovered core to BP. BP and Standard would own the core and be responsible for all costs and liabilities associated with collecting it. In 20 ACC 25.071, the operator is required to file certain core data with the Commission. in this case, however, the core data would not be available to ARCO, As a result, ANCO and BP jointly request permission for BP to assume ARCO's reporting duties for the Ugnu core in Well 3N-14. Please advise Hal Blacker (263-4299) with ARCO, or John Miller (258-7200) with BP, if this reporting procedure meets your approval. Either may be contacted if you have any questions. Sincerely, J. C. Havard Engineering Manager New Projects Engineering ARCO Alaska, Inc. Area Manager BP Alaska Exploration JCH- PSW.cph 0020 cc: H. Kugler AOGCC L. Smith AOGCC RECEIVED APR 2. ,**' 198 Alaska Oil & Gas Cons. Commission /~,nchorafie STATE OF ALASKA ALASKA L__ AND GAS CONSERVATION CL,,v, MISSION PERMIT TO DRILL 2O AAC 25.OO5 I la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test © Development Oil Re-Entry ~ Deepen []1 Service [] Developement Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ~.RCO Alaska, Inc. RKB 68', PAD 34' feet Kuparuk River- Field 3. Address 6. Property Designation Kuparuk River Oil Pool ~.0. Box 100360 Anchorage, AK 99510 ADL 25520 ALK 2556 4. Location of well at surface 7. Unit or property Name 11. Type Bond lsee 20 AAC 25.025) 561 'FSL, 79'FEL, Sec.29, T13N, R9E, UM Kuparuk River Unit ~tatewide At top of productive interval 8. Well nu .mber Number 327'FSL, 1792'FWL, Sec.28, T13N, RgE, UN 3N-14 ¢8088-26-27 At total depth 9. Approximate spud date Amount 295'FSL, 2047'FWL, Sec.28, T13N, RgE, UM 04/30/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(Me and TVD) property line 7475 'MD 79' ~ surface feet 3N-13 2_5'¢ S__ouC. FA¢Efeet 2560 (6650'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure ise~ 2o AAC 25.035 (e)(2)) Kickoff depth3780 feet Maximum hole angle46 0 Maximum surface 2919 psig At total depth El-VD) 3352 psig 18. Casing programl Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2~.'' 6" ~2.5~ H-~n w~d ~n, ~;, ~;, ~, ~, -~nn c¢ 1~,-1/?" f')-'~//~" :l.~,.c,~ I-R~, RTC' ?r~ ~ ~,~;' ~,~ ?~,¢,R~ ?RC, R~ 11'~CI ~ AC:; I I I HF-ER~/ 1~0 sx Class G hlepd 8~" " ~-6.0# J-55 BTC 7441 ' 34' 134' 7675' 66~0' $00 ~ ~la~ G + HF-ER¥ -~ " 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 Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ DiverterSketch ,~ Drilling program YE Drilling fluid program~Time vs depth plot [] Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements 21. I hereby cert, j,f,'y'~at the foregoing is true and correct to the best of my knowledge Signed ' · .X,.,,C,t~ Title Regional Drilling Engineer Dat X Commission Use Only (HRE) PD/PD253 / I AP' number I Approval date I See cover letter Permit Number ~.~ L-. 50-- ~ ' ~,¢.~ ~) 04/2.5/86 for other requirements Conditions of approval Samples required [] Yes ,¢~No Mud log required ~ Yes ~ No Hydrogen sulfide measures ~..~ [] No Directi6nal survey required ~Yes ~ No Required working~sure~o,p~OPE// ..,~2M; ~53,~1; ~ SM;~ '~, 10M; [] 15M Other: / /~')2/ /~f e Z~~,~ . - by order of Approvedby ~,,~,.,,.~ ~,~,~,,~ Commissioner thecommission Dat Form 10-401 Rev. 12-1-85 / , Su~ :riplicate STATE OF ALASKA ALASKA L AND GAS CONSERVATION C IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill ~J lb. Type of well. Exploratory g Stratigraphic Test ~ Development Oil Re-Entry ~ Deepen~J Service ~, Developement Gas ~ Single Zone ~ Multiple Zone - 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ~,RCO Alaska, Inc. RKB 68', PAD 34' feet (uparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool ~.0. Box 100360 Anchorage, AK 99510 ADL 25520 ALK 2556 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 561 'FSL, 79'FEL, 5ec.29, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu .mber Number 327'FSL, 1792'FWL, Sec.28, T13N, R9E, UM 3N-14 #8088-26-27 At total depth 9. Approximate spud date Amount 295'FSL, 2047'FWL, Sec.28, T13N, RgE, UN 04/30/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 7475 ' MD 79' ~ surface feet )N-13 2.5'~ 5_U.~?A~E'.feet ;~;60 (6650'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth3780 feet Maximum hole angle46 0 Uaximurnsurface 2919 psig At total depth (-rVD) 3352 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) HF-ER~ lC~0 sx £1 ass 8:~" 7" 26.0# J-55 BTC 7441 ' ~4' 34' 7475' 6650' 300 sx Class G H F - E R I~ ~: -~., ' 19. To be completed for Redrill, Re-entry, and Deepen Operations. j? ~ . .-v ' 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 Production Liner Perforation depth: measured true vertical 20. Attachments Filin¢] fee !~ Property plat iq BOP Sketch ~ Diverter Sketch ~ Drilling program ~ Drilling fluid program ~;~ Time vs depth plot ~ Refraction analysis Iq Seabed report r= 20 AAC 25.050 requirements 21. I hereby cert, i,C'F-~at the foregoing is true and correct to the best of my knowledge / / 1, .'~~ ' _... Regional Dri,,i.~ En§ineer ey,/,~/~ Signed "- //~~,c~ ,,,..~/,,). ~../~4~'/'~ ,,,lO Dat / "' ~'[/'/ ' " Commission Use Only (HRE) PD/PD253 / / ~/' '"': Permit Number / I APl number I Approval date I See cover letter 86-86 I 5o- 029-2'1.589 I 04/25/86I for other requirements Conditions of approval Samples required .,~ Yes I~ No Mud log required .'_% Yes ._%. No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~ Yes ,~ No Required ' .'., · , 3M; ~ 5M; ~ 10M; ~ 15M Other: ;~~~ ~ ----- by order of Approved Commissioner the commission Date Form 10-401 Rev. 12-1-85 // Su~ triplicate / .... S- 82. DE O 52i-_ IttN...E _.-_ .... "-:'._ -~ ~'._ .' :~. 9:42_ (TO- T_-;-Ai~'OET) _ i'800 .600 !i soo. . I' ',~ :'400_-. ; ,300.._ i , I ! ; i : ~.' . i... :. i 200 1477 ....... :! / :3208 ~. - 20'0 :. 300 4'00 I : I I : : i , 5OO ,.. ,600 ~ , ; I , 700 I _ i , : '.j. / · ": ' I~ ~ ' . .i' i ' i ' ........ ~ '",, , / . .. , . ~ , ' , · · . ,, ":. : ~ ', '~'~./. :i:' .i '.~., ~: : ' J':' .' ".~ · ~- ~-m ~"-~- - L _:" _ , ~'' ' '~ .'. t' " ~ , ~ ~ ~-- '; "---- '~~-- , ' ' ~ ~ / ~-- , . ~I~ ~ ~ ~ ~ ~ '~ ..... . ~,~ , ~ ~ : J 0~ ~ ~ ~ · ~ ' .... ~I ........ ; ............. ~'N'- '; ....... :' ~ '"1 ...... ~ ........ ~ ~ 4~ ....... I ...... ;. . . ' ..... ,":"2' X~ .: ., ,, ~ ...... :..,... .... Xl ~.2..- } X ............. : ....... :" ' , , , - .. " '~";"' x'"; 7~' i' ",' ' ' x': ........~ · . . . . ., .......... ( ............. , ..... , ..... .... ~-f-'-~4--,-[~-,... ~'t-~-;-'~--. ......... :"~ ~"-X' "i .......... ~ : .... ; I ' t ' , ~' ~ ' '~ ', ' 200~ " 100 0 100 200, ~ 300 400 16' - ~ soo 600 ~00 KU'PARUK R I'VER UNIT 20" DIVERTER SCHEMATIC DE S CR I PT I ON I.. 16' C~TOR. 2. TANI(O. STARTER H[AD. 3. TANKO SAVER SUB. 4. TANKO LOWER OU!CK-C~CT ASSY. 5. TAt~I(O UPPER QU! CK-C~CT ASSY. 6. 20' 2000 PSI DRILLING SPOOL W/I0' OUTLETS. ?. I0' HCR BALL VALVES W/lO' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF AhI~IJLAR PREVENTER. 8. 20' 2000 PSI Aha'~IJLAR PREVENTF_.R. MAINTENANCE 8, OPERATION ! . I. UPON INITIAL INSTALLATIOt% CLOSE PREVENTER AND VERIFY THAT VALVES -HAVE OPENED PROPERLY. 2. CLOSE AhINULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE A~NULAR PREVENTER I N THE EVENT THAT AN Ih~LUX OF WELLBORE FLUIDS OR GAS IS DETECTED, IF NECESSARY, MAhaJALLY OVERRIDE Ah[:) CLOSE APPROPRIATE VALVE TO ACHIEVE ~IND DIVERSION. DO NOT SHUT IN ~LL UhDER ANY CIRCUMSTANCES. 7 · 6 f 5 4 3 > > . !. 16' - 2CE]O PSI TAJ~CO STARTING PF_AD 2. 11' - 30(20 PSI CASING ~ 3. Ii' - ~ ~l X 1~8' - ~ ~I ~A~ ~ 4. 1~8' - ~ ~I PI~ ~ 5. 1~8' - ~ ~I ~I~I~ ~ W/~ ~ KI~ LI~ 6. )~8' - ~ ~I ~E ~ ~/PI~ ~ ~ T~. ACO,2vU_ATOR CAPAC)TY TEST t 13-5/8" BOP STACK TEST FILL BCP STAC~ AhO C~ MANIFQ.D WITH ARCTIC DI~. ~ ~T ~ L~ ~ ~ IN ~~ ~Y ~RA~. ~T ~ ~ IN WI~ ~I~ ~ ~ ~ IN L~ S~. LI~ V~vES ~ TO ~ STA~ ~ ~ 4. ~ ~ TO ~~~ F~ lO MIN. I~ ~ ~~ T~~ ~ ~ F~ m O~IN. ~ ~~ TO O ~I~ 5. ~ ~ ~~ ~ ~~ KI~ ~ ~ LI~ VALVES. ~ T~ PI~ ~ ~ ~ VALVES 6. TEST TO 2~ PSZ ~~E~ ~ ZN S~ 4. ?. ¢~ TESTZ~ ALL V~WES, LZ~, ~ ~S W~ A ~ PS~ L~ ~ ~ PS~ H~. TEST AS ~I~ TEST ~S ~T ~ ~ ~Y ~ T~ PI~ R~ ~ ~ ~~ PI~ ~. ~ ~I~ ~ ~ TEST TO.~ ~I ~ PSI. ~ ~I~ R~ ~ ~I~E'TEST ~. ~.~ ~F~ ~ LI~S ~ ~L ~ ~I~ ~UID. ~ A~ VALVES IN ~I~I~ P~ITI~. ~ST ST~I~ V~VES, K~Y, ~Y ~S, PI~ ~E~ VALVE, ~ I~I~ ~ TO ~ PSI ~ PSI. 13. ~~ TEST I~~TI~ ~ ~~ ~~ TE~ F~, SI~, A~ ~ TO ~ILLI~ ~I~. 14. P~~ ~ B~ ~ST ~ N[~ ~ ~Y T~~~ ~I~LY ~~ ~ 510084001 REV. 2 ~AY 15o GENERAL DRILLING PROCEDUR~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3... Drill 13½" hole tol 10-3/4'' surface casing point according to directional plan. 4, Run and cement 10-3/4" casing. · 5% Install and'test blow out'preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 9-7/8" hole to Ugnu core point. Core Ugnu interval with water base core fluid. 8. After coring,drill 8½" hole according to directional plan and provide 100' between plug back total depth and bottom of Kuparuk sands. Run open hole logs. 9. Run and cement 7" casing. Pressure test to 3500 psig. 10, Downsqueeze Arctic Pack and cement in 7" x 10-3/4" annulus. 11. Nipple down blow out preventer and install temporary Xmas tree. 12. Secure well and release rig. 13o Run cased hole logs. 14. Move in workover rig. Nipple up blow out preventer. 15. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 16. Perforate and run completion assembly. 17. Nipple down blow out preventer and install Xmas tree. 18o Change over to diesel and set packer. 19. Flow well to tanks. Shut in. 20. Secure well and release rig° 21. Fracture stimulate. ~ LPAD/3N-14 ih ! 1- J; .i *- STIR ' CENTR I F U~,F_] mud 5¥$T:r~ .5CMEr~RTIC DRILLING FLUID PROGRAM Spud to 10-3/4" Surface Casing Density 9.6-9.8 PV 15-30 Drill out to Weight Up 8.7-9.2 5-15 Weight Up to TD 10.3 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 Initial Gel 5-15 35-40 2-4 35 -45 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 % Solids 10+ 9.5-10.5 4-7 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. In 3N-14 the Ugnu interval will be cored with a water based fluid. LPAD/3N-14a ih ARCO Alaska, Inc. Post Office ~ux 100360 Anchorage, Alaska 995!0~0360 Telephone 907:276 I~215 April 24, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3N-14 Dear Mr. Chatterton' Enclosed is a Permit to Drill application for Kuparuk 3N-14. We estimate spudding this well on April 30, 1986. We propose to drill this well using the attached diverter diagram. We are therefore requesting a variance for this Kuparuk well. A modification has been planned and should be completed in approximately I week. The modified system will be operationally equivalent to the new requirements. If you have any questions, please call me at 263-4970. ~Regional Drilling Engineer JBK/HRE/tw PD/L06 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRJchfJeldCompany ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 / Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3N Pad (Wells 1- 18) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L45 Enclosure If k. Y : ] ¥ L. L-" ARCO Alaska. Inc. is a Subsidiary o! AtlanticRichfieldCompany ~ 2©~21 .OCATED IN PROTRACTED SEC', 28 ~ .,~J, TISN, R9E,U.M. ii 29 LOCATED IN PROTRACTED LOCATED SEC.~9, TISN~ RgE~ U.~. SEC.~9, TI~N,RgE, U.~. 1 - Y ' 6,013,799.67 L~T. 70~6'S~.9615" 10 - Y ~ ~ ~17,94~. I~ LON6.149~S1' 12.938" X 454' FEL, 1562' FSL DG - 28.2 PAD - 33.7 179' FEL, 1561' FSL 0G - 28.5 PAD : 34.0 2 - Y - 6,013,799.65 LAT. 70026'55.9606" 11 - Y = 6,013,799.32 LAT. 70~26'55.9508'' X : 517,971.21 LONG.149°51'12.203'' X · 518,246.03 LONG.149°51'04.132" 429' FEL, 1562' FSL 0G - 28.2 PAD : 33.8 !55' FEL, !561' FSL 0G - 28.5 PAD = 33.8 3 - Y ~ 6,013,799.54 LAT. 70~26'55.9590'' 12 - Y ~ 6,013,799.45 LAT. 70°26'55.9515'' X - 517,996.25 LONG.149°51'11.468'' X : 518,270.89 LONG.149o51'03.403" 404' FEL, 1562' FSL OG - 28.4 PAD : 33.9 130' FEL, 1561' FSL 0G - 28.5 PAD = 34.0 4 - Y : 6,013,799.50 LAT. 70°26'55.9580'' 13 - Y = 6,013,799.41 ~T. 70026'55.9505'' X - 518,021.16 LONG. 149°51'10.736'' X = 518,295.97 LONG.149~51'02.666" 379' FEL, 1562' FSL OG : 28.4 PAD : 33 7 : 105' FEL, 1561' FSL OG - 28.5 PAD - 34.1 5 Y - 6,013,799.~ LAT. 70o26'55.9572" - ~ 14 - Y ' 6,013,799.33 LAT. 70~26'55.9491" X = 518,046.18 LONG. 149~51' 10.002" '~ X : 518,320.91 LONG. 149~51'01.934'' 354' FEL, 1562' FSL 0G : 28.5 PAD : 33.7 ~ ~ 80' FEL, 1561' FSL OG = 28.5 PAD o X ' 518,071.24 LONG.149051'09.266'' ~ X : 518,345.77 LONG.149°51'01-204'' - ~ ~ 55 FEL, 1561' FSL 0G ~ 28.5 PAD = 34.0 7 Y : 6,013,799 44 LAT. 70026'55.9556'' ~ ~ ~ ~ - · o 16- Y = 6,013.799.25 LAT. 70~26'55.9471'' X = 518,096.21 LONG'149°51'08'533" ~ O ~ ~ X : 518,370.74 LONG.149°51'00.470" 304' FEL, 1561' FSL 0G = 28.5 PAD = 33.9 U ~ ~ ~ 30 FEL, 156i FSL 0G : 28.5 PAD = 34.1 8 - Y : 6,013,799.45 LAT. 70~26'55.9551'' X 518,121.15 LONG.149o51 07.800" ~ ~ ~ 17 - Y = 6,013,799.26 LAT. 70°26'55.9466'' = ' X = 518,395.63 LONG. 149~50' 59.739" 279' FEL, 1561' FSL 0G : 28.6 PAD = 33.9 ~ ~ ~ 5' FEL, 1561' FSL 0G = 28.5 PAD = 34.1 9 - y : 6,013,799 42 LAT. 70°26'55.9542" . X = 518,146.15 LONG.149°51'07.066'' ~ SEC. 28,TI3N, RgE, U.M. 254' FEL, 1561' FSL 0G : 28.6 PAD = 34.D ~ 18 - Y = 6,013,799.15 LAT. 70°26'55.9449'' X = 518,420.80 LONG. !49:50' 59.000" NOTES ~0' F~L, ~6~~ FSL 0G: ~.SP~D: ]~.0 I. ALL COORDINATES ARE A.S.P.,ZONE4. ~.SECTION LINE DISTANCES ARE TRUE. 3. HORIZONTAL POSITIONS BASED ON ON-PAD PILING CONTROL PER LHD 4. VERTICAL POSITIONS BASED ON MODULE PILES 5JOI -8 ~ 3J01-4. 5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-3090 rev. . CERTIFICATE OF SURVEYOR: ~ .EREBY CERt i~Y THAT I AM P~OPERLY TH'.S PL~T ~E~ESE~TS ~ ~OC~T~ON SURVEY ~~. : ,,::~ ~oo~R~ .5,~ AS-BUILT LOCATIONS .......................... IIDw6. NO. NSK 86-3 iiJob ~ CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE / 'l ~ ~.5' ~'~ (1) Fee ,. (2 thru 8) (4) Cas ~; ~.~.~. ~o.~o"-~; (14 thru 22) (23 thru 28) (29 thru 31) Company YES 1. Is the permit fee attached .......................................... ,.~.~.__ 2. Is well to be located in a defined pool ............................. i_7~-~ 3. Is well located proper distance from property line .................. ~ · .eeeee®elleelleeeell ~,.-'~- 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 ................................. Z~-- 8. Can permit be approved before ten-day wait .......................... ~ Lease & Well No. NO 14. 15. 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................ ; .................. Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 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 abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. Is a diverter system required ................................... '... /~ 24 Is the drilling fluid program, schematic and list of equipment adequate ~_~ 25~ Are necessary diagrams and descriptions of diverter and BOPE attached. 26. Does BOPE have sufficient pressure rating - Test to .~O~)~) psig .. ~ 27. Does the choke manifold comply w/API RP-53 (Feb.78) .................. 28. Is the presence of H2S 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 ............................................. RENARKS Geology: Engineering: WVA ~ rev: 04/03/86 6.011 POOL INITIAL CLASS STATUS GEO. AREA UNIT I ON/OFF No. I Additional Remarks: ,3N-1,7, ~ 5 ~ reC - 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. LIS'TAPE' VERIFICA?.'[~O~'LIST[NG .VP 010.H02 VERIFICATION LISTIN~ P&2E 1 :4 REEL HEADER ¢~ ;ERVICE NAME :EDIT ~ATE :85/05/ 8 iRISIN : ',EEL NAME :1~9394 ',ONT!NJ~TIDN ~ :01 'REVIOJS REEL : ',OMMENTS :LIBRARY TAPE ,~ TAPE HE~DER ;ERVICE NAME :EDIT IATE :85/05! 8 tRI$IN :0000 'APE NAME ',ONTINUATION 'REVIOUS TAPE : 'O,MMENTS :LIBRARY TAPE FILE HE&DER ~* :ILE NAME :EDIT ;ERV'ICE NAME : fERSION e : ~ATE : IAXIMUM, LENGTH : :ILE TYPE : ~RE¥IOUS FILE : INFORMATION' RECORDS INEM CO~TENTS 4NEM CONTENTS >RES: E COMMENTS UNIT', . TYPE 000 000 000 000. 000 000., 000 O00 000 TYPE 000 CATE DO0 DO0 DO0 O00 000 000 DO0 gO0 300 S ~ mE 000 SIZE 018 O05 OOB 002 00~+ 00'2 012 005 003 St Z E 001 CODE O65 065 065 065 065 065 0~5 O65 O&5 CODE 065 .VD OIO.H02 VERIFIC,&TI3N LISTINg PAGE 2 SCHLUMBERGER ALASKA COMPUTIN~ CENTER ;OMPANY = ARC~ ALASKA INC IELL : 3N-1¢ :IELD : KUP~RUK iOdNTY = NORTH SLOPE 50ROUGH iTATE = ALASKA lOB NUMBER AT ACC: 71¢53 IUN JZ, DATE LOGGED: .DP: RICK KRUWELL 'ASING : 10-75" @ 2579' -' BIT SIZE :' 8.3" T3 7~50' 'YPE FLUID = LSND POLYMER )ENSITY = 9.9 LB/S RM = 4.32 2 75 DF rISCOSITY = 35 S RMF = 3o85:~ 73 DF ;H. = 9 RMC =' 3.5B @ 53 DF =LJID LOSS = ~o4 C3 RM ~T BHT = 2.377 ~ '1~2 DF IA'TRIX SANDSTONE ~~ THIS DATA HAS NOT,BEE~'DEPTH SHIFTED - OVERLAYS FIELD PRINTS ,VP OlO.H02 VERIFICATIO~ LISTIN3 P~$E 3 SCHLUMBERSER LOGS INCLUDED WITH TflIS MAGNETIC TAPE: DdAL INDU:TIDN'SPtERICALLY F3CUSED LOG COIL) DATA AVAILABLE: 7451' TD 2579' F2RMAT'IDN DENSITY COMPENSATED LOG (FDN) ~ C3MP~NSATED NEUTRON LOG CFDN) ~ DATA AVAILABLEt 7~25° TO 5550' ~ DATA FORMAT RECORD ~' ~NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 ! 66 0 ~ 1 66 B ~ 73 60 g' 4 65 .lIN 16 I 66, ~ 1, 66 0 )ATOM SPECIFICATZON BLOCKS tNEM'SERVICE SERVICE U~IT AP1, API. API. A~I. FILE SIZE SPL REPR PROCESS iD ORDER '~ LOG ~"YPE CLA:SS' ~OO, ~O. 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ILD 83.0898 GR O.OZS9: NRAT 21.31;5000 FC~L Z9.0830. 56.2617 GR 0.0303 NRAT 2403.5000 FCNL 3.3~7~ ILO S8°4023 0.0.361 NR~T: 2139.50,00 FC.~L 4.5085 ILD. 92.5898 GR -0,0186 NRAT 2591.5000~ FCNL! 1.3301 ILD 11Z.2148 GR 0.026~ NR~'T' 2.8909 101.95~8 2.9163 653.3~25 3.8557 97.8398 2.89~8 674.3125 2.~56 104.2148 3.4299 5~0.8125 7..8~06 83.0898 2.9280 702.3125 26.4111 56.2617 2.9709 753.3125 4"3250 88.,~Z3 2.9963 700'8125 3.77,95 92.5898 3.0508 877.3'125 1-9571 11 Z - 2148 3.5237 1 1 1 1 1 1 1 1 1 l 1 1 $B $B 6B 68 68 68 68 68 ILM CALI RNRA IL4 CALI RNRA ILM RNRA ILM CALI RNR~ ILM CALI RNR~ CALl R:NR~ CAL[ RNR~ C.ALI RNR~ 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000000 0000000 000 000 000 000 000 000 000 000 000 000 000 000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 2.8499 8.5020 3.0334 3.9241 8.91 60 3.1292 2.5256 9.6035 3.6331 7.8523 9.0098 3.0334 24.8018 8.93'95 3.18'97 4.2078 9. 3066 '3- 1,370 4.1296 9.0098 2.9534 1.8887 8.8691. 3.5002 ,VP OlO.H02 VERtFIC~TID~ LISTIN3 PAGE 5 )PHI 43.O66¢ )EPT 5700.0000 SFLJ :P -17o4951 ER IH3B 2.3574 DR9g IPHi 48.3398 NCNL IEPT 6500.0000 SFLJ ;P -17.4951 GR IH3~ -999.2500 DRHg IPHI -999.2500 NCNL, IEPT 6500.0000 SFLJ ;P -17.9325 GR IHDB -999.2500 DRM2 IPgI -999.2500 NCNL )EPT 6400.0000 SFLg ;P -18.0576 GR iHD~ -999,2500 DRH2 IPHI -~9~.2500 NCNL )EPT 6300.0000 SFLU ;P' -17.4170 GR :HSB -999.2500 DR~g IPHI -999.2500 NC~:L tEPT 6200-0000 ;P -16..6514 )HDB -999'2500 IPMI -999.2500 IE PT ;P ',HOB IPHI )EPT ;P ~HDB IPHI )EPt ;P ~H3B iPHI tE PT ;P 'HOB IPMI ~E PT ;P 6100'0000 -19'5107 -999.2500 -999.2,50:0 6000,0000 -18-2920 -999.2~00 -999,2500 '$900'0000 -17.2507 -999-2500 $$00.0000 -999.2500 -999.2500 ~700'0000 '-18.776& SFLJ GR D,R~ NCNL SFLd GR DRH2 NCNC SFL ~ GR NCNL SFL~ GR DR~g' NCNL!i SFLd GR DR~2 NCNL SFLd GR 1595.6B75 FCNL 2.1194 118.4023 GR 0.0474 NR~T 1654.6875 FCNL 2.5T06 ILD 137.1875 GR -999.2500 NR~T -9}9,.2500 FCNL 2.7327 ILD 215.1975 GR -9~9.2500 NR~T -999.2500 FCNL 3,8557 ILD 11~.2773 GR -999.2500 NR%T -9~9.2500 FCNL 1.6436 1~$o1523 GR -999.2500 NR~? -999.2500 FC~L 2.7600 129.3125 -999.2500 -999.250,0 1.7'960 105-8398 -999.2500 -999'2500 ILD GR NRAT FCNL ILD GR NR~T ~CNL 2.4436 ILO 86°71~8 GR -939.2500 NRAT -999,2500 FC~L 2.5491 120'1523 -999.2~00 2,1252 '79.71~8 -999.2500 -999.2500 1~2,.7773 GR NRAT FC~.L ILO GR. 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GR NC~.J~ S:FLJ GR NC~'L SFLJ OR'~g NCNL SFLJ" GR NCN'L! GR' DRHO, NCNL-:, SFL'UI, -999.2500 NR~T -999.2500 FCNL 2.3362 iLD 1Z1.96~8 GR -999.2500 NRAT -9~9.2500 FCNL 2.9690 ILD 108.6023 GR -999.2~00 NR~T' -999.2500 FCNL 2.,~514 ILD 106. 7773 GR -999.2500 NRAT -999.2500 FC~L 3.3713 ILO 138.6023 GR -999.2500 NRAT" -999.2500 FCNL 90.0273 -999.2500 -999,2500 GR FCNL 3.8108 ILD 100.6523 GR -999.2500 NRRT' -999.2500 FC~L 3.3679 98.5273 -999,2500 -999.2500 2-8284 112o0273 -999°2500 -999.2500 2.3596 95'0B98 -979.2500 -999.2500 78.5273 -999°2.500 -999'2500 2.3010 ILD NR~T FCNL GR NR'AT FCNL" I L D GR NRAT FCNL ILD GR' NR~ T FC~L -999.2500 -999.2500 2.3381 -999.2500 -999.2500 -999.2500 3.1~57 -999.2500 -999,2500 -999.2500 2.5979 -999.2700 -9~9.2500 -999.2500 3.7288 -999.2500 -999.2500 -999.2500 ~.1765 -999.2500 -999.2500 -999.2500 6.0789 -999.2~00 -99912500 -999oZ500 3°&553 -999.2500 -9~9.2500 -999.2500 2'9749 -999.2500 -999.2500 -999'2500 2°6~&8 -999.2500 -999.2500 -999.2500 2,756.1 -999.2500 .-999,2500 RNR~ CALI RNR& CALl RNRa ILM CALI RNR~ CALI RNRA ILM CALt RNR ~ ILM CALl RNR:& ILM CALI 'RNR~ I L M' CALI R'NR ~ ILM: C,ALI RNRA ILM CALI RNR~ IL4' -9~9.2500 2.3792 -999.2500 -999.2500 3.1292 -999.2500 -999.2500 2.5311 -999.2500 -999.2500 3.5823 -999.2500 -999.2500 6.2312 -999o2500 -999.2500 4-0828 -999.2500 -999.2500 3.¢983 -999.2500 -999,2500 2-9963 -999-2500 -999.2500 2.6370 -999.2500 -999-2500 2..72~9 -999.2500 -999,2500 ,Vm OlO.H02 VERIFICATIO~ LISTIN~ PAGE 7 P 'H2B ~PHI ~EPT ,P IPHI ~EPT ;P :HDB IPHI ~EPT ',HOB ,P :H ~ B ~EPT ;P ~EPT ;P IEPT IPM I ~EPT ',HOB IPHI iEPT ;P :HOB tPHI IEPT iP ',HOB IPHI -19.9325 GR -999.2500 DRH3 -999.2500 NCNL 6500.0000 SFLd -19.1357 GR -999.2500 DRH3 -999.2500 NCNL 6¢00.0000 SFLJ' -18.5201 GR -999.2500 DRH3 -999.2500 NCYL: 4300.0000 SFLJ -18.9795 SR -999.2500 DRff3 -999.2500 NC~C,: 4200.0000 SFLJ -19.1982 ER -999.2500 DRY3 -999.2500 NCNL. 4100.0000 SFL~ -20.7295 GR -999'2500 DRH3 -999.2500 NCN'L:i ~000'000'0 SFLU': -19.6570 GR -999.2500 DRHD -999'2500 NCNL 3900. 0000 SFL'J: -20'2295 GR -999.2500 DRMO, - 9 g 9, .250.0 NC N L 3BO0'OOO0 -21.3701 -999.2500 -999.2500 3700'0000 -I9.Z764 -999.2'500 -999.2~00 3500,0000 -19.5~20 -999.2500 -999.2500 S~LU" GR" DRH,3; NCN,~.~ S F L 'U GR' DRH 2 NCNL ,S F'L U' DR~3' NC:4 109.9648 GR -9~9.2500 NRAT -999.2500 FCNL 2.Z26B IL2 13~.0273 GR -999.2500 NRAT' -999.2500 FC~L 2.5632 ILD 104.5523 GR -999o2500 NR&T -999.2500 FC4L 2. '49z~4 99. 2773 -999.2500 -9~9.2500 ILD GR NR~T FCNL 2.7717 ILD 99.3398 GR -999.2500 NRAT -999.2500 FC,N'L 2.2327 87,5273 -999.2500 -999.2500 3.6516 Bg. 95,~8 -999.2.500 -9~9.2'500 3. 097'9 88'9023 -999-2500 -999. 2500 1.2S~0 92.~023 -999.2500 -999. 2500 2. 564.:7 93-9023 -9~9.250:0 -9 ~9- 2500 2.3909 93.089B -999.25'00 -999.2500 ILO GR NR~T FCNL' ILD~ GR NRAT, FCNL~; ILD NR~T FCNL ILD GR NRAT FCNL ILD ,NR~? FC NL ILD GR NR~T FC.:NL -999.2500 -999.2500 -999.2500 2.267~ -999.2500 -999.2500 -999.2500 2.6155 -999.2500 -999o2S00 -999.2500 2.5920 -999.2500 -999.2500 -999.2500 2.B$35 -999.2500 -999.2500 -999.2500 2.5582 -999.2500 -999.Z500 -999.2500 3.1506 -999.2500 -999.2500 -999.2500 3- 2 952 -999- 2500 -999.2500 -999.25'00 1'8956 -99'9.2500 '999.2500 -999.2500 2.~213 -999.2500 -999.2500 -999.2500 2.9'729 -999.2500 -999.2500 -999.2500 CALl RN2A ILM CALl RNRA ILM CALl RNRA ILM CALI RNRA ILM CALI RNR~ ILM CALI RNRA LM RNRA ILM. C r~ L :I RNR~ CALl RNR,~ C,ALI RNR~ ILM' CALt RNRA -999.2500 -999.2500 2.2756 -999.2500 -999.2500 2.6038 -999.2500 -999.2500 2.5823 -999.2500 -999.2500 2.B479 -999.2500 -999.2500 2.6721 -999.2500 -999.2500 3.1877 -999.2500 -999.2500 3 - 2 6 g 8 -999. 2500 -999. 2500 1.8399 -999.,2500 -999.2500 -999.250,0 -999.2500 2-8699 -999'2500 -999.2500 VP 010oH02 VERIFICATIO~ EPT 3500.0000 SFLJ P -20.2764 GR H3B -999.2500 DRH3 IPMI -999.2500 NC~'L IEPT 3600.0000 SFLJ P -16.8857 SR H3B -999.2500 DRHD IPHI -999.2500 NCNL ~EPT 3300.0000 SFLJ ,P -18.1357 GR :HOB -999.2500 DRH3 IPHI -999.2500 NC~L iEPT 3200.0000 SFLJ ;P -25.1045 GR IH95 -999.2500 DRH3 tPHI -999.2500 NCNL IEPT 31.00.0000 SFLU ;P -18.8857 GR :HDB -999.2500 DRH3 IPHI -999.2500 NC~'L ~EPT 3000.0000 ;P -29.7139 IHDB -999.2500 iPHI -999.2500 ~EPT 2900'0000 :P -2B.SZ32 :HDB -9'99.2500 IPNI -999.2500 IEPT 2BO0.O000 ,P -22-7507 :HOB -999.2500 tPHI -999.2,500 ,EPT 2700.0000 ,P -27-6982 HOB -999.2500 IPHI -999'2500 IEPT 2600'0000 .P -29,6982 :HDB -999.2500 IPHI -999.2500 ~EPT 2557. 5000 ,P. -30.2139 :HSB -999.2,500 IPH'i -999. 2500 SFLU GR. DR~D NCN L SFL2 GR NCNL SFLd GR DRH'3 NCNL SFL'J' $R DRN3, NCq'Li: SFL~:' GR NCNL S F L d GR :DRH3 NC NL LISTINS 4.0085 IL2 76.B398 GR -9g9.2500 NRAT -999.2500 FCNL 3.1897 ILO 76.1523 GR -999.2500 NRAT -999.2500 FCNL 5.0515 iL~ 92.6023 GR -999.2500 NR~T -999.2500 FCNL 4.7351 ILO 71.7773 GR -999.2500 NRAT -999.2500 FCflL 7°4656 ILD 56.5898 GR -999.2500 NRAT -999.2500 FCNL 5.7781 ILD 57.5367 GE -999.2500 NR~T, -999.2500 FCNL~ 9.2910 70.0273~ -999.2500 -999.2500 19~.0525 25.692~ -999.2500 -999.2500 11-587'9'i 55.3242 '-999.2500 -999.2500: ?.4031 58.6523 -99'9.2500 -999.2500 5.9B90 39.5430 -999.250:0 -999.2500 ILD, GR N.RAT. FC~L ILD OR NRA'T FC~L ILD GR NR~T FC~'L ILO GR NR ~ T F C N :L GR FC~L 4.7390 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 5.5281 -999.2500 -999.2500 -999.2500 5.3289 -999.2500 -999.2500 -999.2500 8.6270 -999.2500 -999.2500 -999.2500 5.5637 -999.2.500 -999.2500 -999.250'0 10.7910 -999.250O -999.2500 -999.2500 217.0525 -9'99.2500 -999.2500 -999.2500 11.38a8 -999.2500 -99'9.2500 -999.2500 9.8926 -999.2500 -999.2500 -939.2500 ,56.0[17 -999-2500 -999.2500 -9'99.2500 ILM CALI RNR A ILM CALI RNR~ ILM CALI RNRA ILM CALI RNRA ILM CALI RNRA CAL[ RN2.~ CALI RNRA CALI RNRA ILM: CALi RNR~ iLM CALI RNRA CALi RNRA PAGE 4.4460 -999.2500 -999.2500 4.36~0 -999.2500 -999.2500 5.1335 -999.2500 -999.2500 4.8523 -999.2500 -999.2500 7.9148 -999.2500 -999.2500 4.9655 -999.2500 -999.2500 9.7676 -99'9.2500 -999.2500 83.5273 -999.2500 -999.2500 10.7B32 -999.2500 -999.2:5:00 8. 9238 - 999.25 O0 -999.2500 2000.6875 -999.2500 -999.2500 V~ 010.H02 VERIFICATION LISTIN~ PAGE ,~ =ILE TR&ILER ILE NAME :EDIT .001 ERVICE NAME : ERSION ~ ATE : AXIMUM LENGTH : I024 ILE TYPE : EXT FILE NAME : ~ TAPE TRAiLER.~ ERVICE NAME :EDIT ATE :85/05/ 8 RI$IN :0000 APE NAME ONTIN~ATION # EX'T' TAPE NAME : DMMENT$':LIBRARY,TAPE :~ REEL'TRAILER ERVICE NAME :EDIT: ATE :8S/05/ 8 RI$IN : EEL~N~ME :149394 D~TINU~TI~N # :0~. EXT REEL. NAME :,, DMMENT$ :LIBRARY T'~PE ~#~,~ EOF
