The URL can be used to link to this page

Home My WebLink About188-011MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3H-22 KUPARUK RIV UNIT 3H-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3H-22 50-103-20097-00-00 188-011-0 W SPT 5979 1880110 1500 2815 2815 2815 2815 340 440 440 440 4YRTST P Austin McLeod 6/1/2025 MITIA. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3H-22 Inspection Date: Tubing OA Packer Depth 830 2000 1950 1945IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250602192050 BBL Pumped:2 BBL Returned:1.8 Thursday, July 24, 2025 Page 1 of 1           MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3H-22 KUPARUK RIV UNIT 3H-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2023 3H-22 50-103-20097-00-00 188-011-0 W SPT 5979 1880110 1500 2244 2245 2245 2245 510 550 550 550 4YRTST P Guy Cook 1/30/2023 Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3H-22 Inspection Date: Tubing OA Packer Depth 870 1700 1650 1635IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230130150243 BBL Pumped:1.1 BBL Returned:0.9 Friday, March 17, 2023 Page 1 of 1          1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Convert to Inj Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10234'feet None feet true vertical 6379' feet None feet Effective Depth measured 10234'feet 9578' feet true vertical 6379' feet 5979' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" x 4-1/2" L-80 9736' MD 6075' TVD Packers and SSSV (type, measured and true vertical depth)9578' MD N/A 5979' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 322-684 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker 587-400 Model F Prod Packer SSSV: None Lynn Aleshire lynn.aleshire@conocophillips.com (907) 265-6525Surveillance Reservoir Engineer 9690-9710', 9716-9736', 9754-9774' 6047-6059', 6063-6075', 6086-6098' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) INJECTOR Gas-Mcf MD ~ Size 115' ~ ~~ ~~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-011 50-103-20097-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025523, ADL0025531 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3H-22 Plugs Junk measured Length Production Liner 10017' Casing 6268'10052' 4313' 115'Conductor Surface Intermediate 16" 9-5/8" 79' 4348' 3127' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 1:46 pm, Feb 21, 2023 3H-22 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/20/23 Choke inspected; removed and sent to valve shop for repair. 01/22/23 DSM installed choke and well BOL. 01/30/23 State witnessed MITIA. PASS Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 9,803.0 3H-22 5/26/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: H2S Update & Correct ICON 3H-22 4/19/2022 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: Bad spot in 7"CSG 8257'-8281'; Max ID=6.45"; Tested to 2600psi w/10 ppg Brine. 4/28/1988 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.0 4,347.6 3,126.8 36.00 J-55 BTC PRODUCTION 7 6.28 35.0 10,052.2 6,267.8 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 35.0 Set Depth 9,586.8 Set Depth 5,984.6 String Ma 3 1/2 Tubing Description Tubing Production Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Mod ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.09 HANGER 6.930 McEvoy Gen III Tubing Hanger, MSDP-1-6.5-MS-3, 7-1/16" x 3-1/2" EUE 8rd Box x Box, 3" H BPVG McEvoy Gen III MSDP-1 -6.5-MS- 3 2.950 3,246.3 2,509.1 56.20 GAS LIFT 5.875 GLM, Camco, 3-1/2" x 1-1/2" MMG with DV, RK Latch, SN: 267AG07 Camco MMG 2.915 5,598.9 3,802.4 58.62 GAS LIFT 5.875 GLM, Camco, 3-1/2" x 1-1/2" MMG with DV, RK Latch, SN: 263AG07 Camco MMG 2.915 7,260.2 4,693.3 58.20 GAS LIFT 5.875 GLM, Camco, 3-1/2" x 1-1/2" MMG with SOV, RKP Latch, SN: 165AG07 Camco MMG 2.915 8,576.8 5,395.5 56.11 GAS LIFT 5.875 GLM, Camco, 3-1/2" x 1-1/2" MMG with DV, RK Latch, SN: 283AG07 Camco MMG 2.915 9,517.3 5,942.4 52.77 GAS LIFT 5.968 GLM, Camco, 3-1/2" x 1-1/2" MMG with DV, RK Latch, SN: 266AG07 Camco MMG 2.915 9,574.2 5,976.9 52.65 LOCATOR 5.240 Locator Sub, GBH-22 (bottom of the locator spaced out 3.83') Baker GBH-22 2.990 9,575.3 5,977.6 52.65 SEAL ASSY 3.730 Seal Assembly, 80-40 Baker 80-40 3.020 Top (ftKB) 9,578.3 Set Depth 9,736.0 Set Depth 6,075.3 String Ma 4 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection STC ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,578.3 5,979.4 52.65 PACKER 5.870 587-400 Model 'F' Production Packer Baker 587-400 Model 'F' 4.000 9,581.6 5,981.4 52.64 SBE 5.030 80-40 Seal Bore Extension (SBE) Baker 80-40 SBE 4.000 9,591.0 5,987.1 52.62 XO Reducing 5.670 Crossover, 4-3/4" Stub Acme Box x 3-1/2" EUE 8rd Pin Baker 2.970 9,639.7 6,016.7 52.57 NIPPLE 3.930 Nipple, HES, 2.813" X, SN: C- 3562596 Halliburt on X' Profile 2.812 9,651.6 6,023.9 52.56 PORTED CROSSOVER 4.500 Ported Crossover, 3-1/2" EUE 8rd Mod Box x 4-1/2" STC Pin Baker 2.992 9,653.4 6,025.0 52.56 PORTED WEARSOX 4.500 Ported Wearsox Joint, 4-1/2", 12.6#, L-80, STC Box x Mule Shoe Baker 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 9,715.0 6,062.5 52.52 WHIPSTOC BAKER 3.5"X4.5" WHIPSTOCK(GENII DELTA). TOWS = 9715, WHIPSTOCK ORIENTATION = 330DEG, CCL TO TOP OF WHIPSTOCK = 14.9', RA TAG @7.35 FROM TOP, WHIPSTOP OAL=12.97 10/6/2016 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,246.3 2,509.1 56.20 1 GAS LIFT DMY RK 1 1/2 0.0 5/26/2017 0.000 5,598.9 3,802.4 58.62 2 GAS LIFT DMY RK 1 1/2 0.0 5/26/2017 0.000 7,260.2 4,693.3 58.20 3 GAS LIFT DMY RK 1 1/2 0.0 3/15/2017 0.000 8,576.8 5,395.5 56.11 4 GAS LIFT DMY RK 1 1/2 0.0 3/19/2016 0.000 9,517.3 5,942.4 52.77 5 GAS LIFT DMY RK 1 1/2 0.0 5/27/2017 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,690.0 9,710.0 6,047.3 6,059.4 A-3, 3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet; 60° ph 9,716.0 9,736.0 6,063.1 6,075.3 A-2, 3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet; 60° ph 9,754.0 9,774.0 6,086.2 6,098.4 A-1, 3H-22 4/25/1988 4.0 IPERF SOS 4.5" Ultra P; 120° ph 3H-22, 2/20/2023 4:42:37 PM Vertical schematic (actual) L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 NIPPLE; 9,639.6 PACKER; 9,578.3 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 42.01 RR Date 2/28/1988 Other Elev 3H-22 ... TD Act Btm (ftKB) 10,234.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009700 Wellbore Status PROD Max Angle & MD Incl (°) 60.15 MD (ftKB) 5,100.00 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 600 Date 11/5/2021 Comment SSSV: None Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS & GLV C/O 3H-22L1 2/9/2017 pproven Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 Liner (Slotted) 2 3/8 1.99 9,812.2 11,751.0 4.70 L-80 ST L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,812.2 6,104.3 79.00 Aluminum Billet 2.700 Aluminum Billet BOT Billet 0.000 3H-22L1, 2/20/2023 4:42:38 PM Vertical schematic (actual) L1 Liner (Slotted); 9,812.2- 11,751.0 PRODUCTION; 35.0-10,052.2 L1-03 Liner; 9,714.0-12,000.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 NIPPLE; 9,639.6 PACKER; 9,578.3 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 42.01 RR Date 2/28/1988 Other Elev 3H-22L1 ... TD Act Btm (ftKB) 11,751.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009760 Wellbore Status PROD Max Angle & MD Incl (°) 99.31 MD (ftKB) 10,800.66 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 600 Date 11/5/2021 Comment SSSV: None Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS & GLV C/O 3H-22L1- 02 2/9/2017 pproven Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-02 Liner 2 3/8 1.99 10,049.7 11,984.0 4.70 L-80 STL Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,049.7 6,124.4 90.38 Aluminum Billet & Anchor 2.630 OH Anchor & Aluminum Billet BOT Billet 1.920 10,632.2 6,113.5 91.14 Deployment Sleeve Shorty Deployment Sleeve 3H-22L1-02, 2/20/2023 4:42:38 PM Vertical schematic (actual) L1-02 Liner; 10,049.7-11,984.0 L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 NIPPLE; 9,639.6 PACKER; 9,578.3 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 42.01 RR Date 2/28/1988 Other Elev 3H-22L1-02 ... TD Act Btm (ftKB) 11,984.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009762 Wellbore Status PROD Max Angle & MD Incl (°) 100.26 MD (ftKB) 10,940.98 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 600 Date 11/5/2021 Comment SSSV: None Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: ADD LATERALS & GLV C/O 3H-22L1- 03 2/9/2017 pproven Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1-03 Liner 2 3/8 1.99 9,714.0 12,000.0 6,138.7 4.60 L-80 ST-L Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,714.0 6,061.9 52.52 Deployment Sleeve 2.625 Shorty Deployment Sleeve Baker Shorty 1.000 3H-22L1-03, 2/20/2023 4:42:39 PM Vertical schematic (actual) L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 NIPPLE; 9,639.6 PACKER; 9,578.3 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 42.01 RR Date 2/28/1988 Other Elev 3H-22L1-03 ... TD Act Btm (ftKB) 12,000.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009763 Wellbore Status PROD Max Angle & MD Incl (°) 101.16 MD (ftKB) 10,170.57 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 600 Date 11/5/2021 Comment SSSV: None 2dC^I0CfxCrt<8\A^\/XxP/Cng8tT^\r #g8>txjC1tTZxX8tC0Cd8Tg5CXX.dCg8tT^\rrRxtAc\ 1xrdC\A/Cng8tC.tRCg1tTZxX8tC/xXX2x<T\P R8\PCddg_zCA/g^Pi8Z /XxPJ^g0CAgTXX/Cng8tC-H/^^X0CC\tCg1xrd5CXXXtCg 8rT\P.tRCg ^\{Cpt^5&-) .dCg8t^g-8ZC xgl\t5CXX X8rr /CgZTtt^!gTXX-xZ<Cg ^\^>^/RTXXTdrX8rW8&\> "dX^g8t^g!FzCX^dZC\t AAjCrr1tg8tTPg8dRT>1CgzT>C /&-xZ<Cg / . ^\>R^g8PC* &IdCng8tT\P 5CXX-8ZC8\A-xZ<Cg 5R8t0CPxX8tT^\^g ^\rCgz8tT^\.gACgP^zCg\rCXXrd8>T\PT\tRTrd^^X 8 5TXXdX8\\CAdCng;T^\rgCfxTgC8rd8>T\PC>CdtT^\ 7Cr -^ /g^dCgw!CrTP\;T^\+C8rC-xZ<Cg #TCXA xgl\t/^^Xr/g^d^rCA/^^Xr 8 50"15*8)6%18)%+$8 50"15*8)6%18)+8..+8 50"15*8)6%18)+8..+8 8 88 !8 2^t8X!CdtR,!M 2^t8X!CdtR24!M"L>tT{C!CdtR,! "L>tT{C!CdtR24!,/1/drT/XxPr,!)x\W,! -^\C-^\C "3)-'8 %-'4(8 )7%8 8 8 52348 .++"03%8 1tgx>txkX ^\Ax>t^g 1xm>C &\tCgZCAT8tC /g^Ax>tT^\ +T\Cg /Cng;T^\!CdtR,!M /Cng;T^\!CdtR24!M 2x<T\P1TC2x<T\P$g8AC2x<T\P,!M 6+ /8>WCgr8\A11142dC/8>WCg8WCg,^ACX#/g^A/8>WCg/8>WCgr8\A1114,!M8\A24!M ,!8\A24! 1114-^\C- tt8>RZC\tr/g^d^r8X1xZZ8g5CXX<^gCr>RCZ8tT> 5CXX X8rr8MCgdg^d^rCA^gW !G8TXCA.dCg;T^\r/g^Pi8Z./1WCt>R"dX^g;^g1tg;TPg8dRT>!FzCX^dZC\t "rtTZ8tCA!;CI^g 5CXX1t8txr8MCgdg^d^rCA^gW ^ZZC\>T\P.dCg;T^\r.&+5&-)5!1/+ 4Cg<8Xddgbz8X!;C$15$$12.0 .$ 0CdlrC\t8tTzC$&-).d1RxtAc\ 'SDhD=?DqUNuS9uuSDK`hDQ`U]QUsuhyD9]BuSDeh`?DByhD9eeh`|DBSDhDU]UYY]`u=DBD|U9uDBKh`[UuS`yuehU`hhUuuD]9eeh`}9Y xtR^gTCA-8ZC8\A ')%!))!!%#* '* * ^\t8>t-8ZC +~\\XCrRTjC 1CgzT>C 1xrdC\ACA 1/+3$ <8\A^\CA !T:Tt8X1T:\;xgCTtR!;C ^\t8>t"Z8TX X{\\ 8XCrRTjC>^\^>^aRTXXTar >^Z ^\t8>t/R^\C xtR^gTCA2TtXC1xgzCTXX8\>C0CrCgz^Tg"\PT\CCg 88!8 ^\ATtT^\r^I8ddgbz8X-^tTO.$ r^tR8t8gCdjCrC\t8tTzCZ8Tt\Crr1x\Ag-xZ<Cg /XxP&\tCPgTt./2Crt ,C>R8\T>8X&\tCPgTt2Crt+^>8tT^\ XC8g8\>C .tRCg /^rt&\TtT8X&\VC>tT^\,&20CfA7Cr -^ 1d8>T\P">CdtT^\0CfxTgCA7Cr -^1x<rCfxC\t#^gZ0CfxTgEA //0.4"!7 ddozCA< .,,&11&.-"0 2%".$ !8vC ^ZZ (@^ZZ 1g/Ct"\P1g/Ct$C^1g0Cr"\P "$ * *(&* * 001.6%$8"00+)#"4).-8 6"+)$8&.188,.-4(38&1.,8$"4%8.&8"001/6"+8 1x<ZTt/!#t^8^P>> dCgZTttT\P8X8rW8 P^z X SFD 12/2/2022VTL 12/16/2022 DSR-12/1/22 X 10-404 GCW 12/16/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.16 09:35:57 -09'00' RBDMS JSB 122222 Oka y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ynn Aleshire Digitally signed by Lynn Aleshire Date: 2021.11.16 17:07:45 -09'00' By Samantha Carlisle at 1:07 pm, Nov 17, 2021 VTL 01/24/2022 DSR-11/17/21 -00 SFD 11/18/2021 RBDMS HEW 11/18/2021 SFD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 9,803.0 5/26/2016 3H-22 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: H2S, GLV C/O 5/28/2017 3H-22 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 4,347.6 Set Depth (TVD) … 3,126.8 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 10,052.2 Set Depth (TVD) … 6,267.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description Tubing – Production String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 35.0 Set Depth (ft… 9,586.8 Set Depth (TVD) (… 5,984.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 35.0 35.0 0.09 HANGER McEvoy Gen III Tubing Hanger, MSDP-1-6.5-MS-3, 7-1/16" x 3- 1/2" EUE 8rd Box x Box, 3" H BPVG 2.950 9,574.2 5,976.9 52.65 LOCATOR Locator Sub, GBH-22 (bottom of the locator spaced out 3.83') 2.990 9,575.3 5,977.6 52.65 SEAL ASSY Seal Assembly, 80-40 3.020 Tubing Description Tubing – Completion Lower String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 9,578.3 Set Depth (ft… 9,736.0 Set Depth (TVD) (… 6,075.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection STC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,578.3 5,979.4 52.65 PACKER 587-400 Model 'F' Production Packer 4.000 9,581.6 5,981.4 52.64 SBE 80-40 Seal Bore Extension (SBE) 4.000 9,591.0 5,987.1 52.62 XO Reducing Crossover, 4-3/4" Stub Acme Box x 3-1/2" EUE 8rd Pin 2.970 9,639.7 6,016.7 52.57 NIPPLE Nipple, HES, 2.813" X, SN: C-3562596 2.812 9,651.6 6,023.9 52.56 PORTED CROSSOVER Ported Crossover, 3-1/2" EUE 8rd Mod Box x 4-1/2" STC Pin 2.992 9,653.4 6,025.0 52.56 PORTED WEARSOX Ported Wearsox Joint, 4-1/2", 12.6#, L-80, STC Box x Mule Shoe 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 9,697.0 6,051.5 52.52 Junk Catcher AVA CATCHER (2.73" x 35") 3/14/2017 0.000 9,715.0 6,062.5 52.52 WHIPSTOC BAKER 3.5"X4.5" WHIPSTOCK(GENII DELTA). TOWS = 9715, WHIPSTOCK ORIENTATION = 330DEG, CCL TO TOP OF WHIPSTOCK = 14.9', RA TAG @7.35 FROM TOP, WHIPSTOP OAL=12.97 10/6/2016 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,690.0 9,710.0 6,047.3 6,059.4 A-3, 3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet; 60° ph 9,716.0 9,736.0 6,063.1 6,075.3 A-2, 3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet; 60° ph 9,754.0 9,774.0 6,086.2 6,098.4 A-1, 3H-22 4/25/1988 4.0 IPERF SOS 4.5" Ultra P; 120° ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,246.3 2,509.1 56.20 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/26/2017 2 5,598.9 3,802.4 58.62 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/26/2017 3 7,260.2 4,693.3 58.20 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/15/2017 4 8,576.8 5,395.5 56.11 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/19/2016 5 9,517.3 5,942.4 52.77 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/27/2017 Notes: General & Safety End Date Annotation 11/2/2010 NOTE: View Schematic w/ Alaska Schematic9.0 4/28/1988 NOTE: Bad spot in 7"CSG 8257'-8281'; Max ID=6.45"; Tested to 2600psi w/10 ppg Brine. 3H-22, 10/20/2021 3:39:04 PM Vertical schematic (actual) L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 Junk Catcher; 9,697.0 PORTED WEARSOX; 9,653.4 PORTED CROSSOVER; 9,651.6 NIPPLE; 9,639.6 XO Reducing ; 9,591.0 SBE ; 9,581.6 SEAL ASSY; 9,575.3 PACKER; 9,578.3 LOCATOR; 9,574.2 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP INJ KB-Grd (ft) 42.01 Rig Release Date 2/28/1988 3H-22 ... TD Act Btm (ftKB) 10,234.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009700 Wellbore Status INJ Max Angle & MD Incl (°) 60.15 MD (ftKB) 5,100.00 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 240 Date 4/30/2017 Comment SSSV: None Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: ADD LATERALS & GLV C/O 2/9/2017 3H-22L1 pproven Casing Strings Casing Description L1 Liner OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 9,812.2 Set Depth (ftKB) 11,751.0 Set Depth (TVD) … Wt/Len (l… 4.70 Grade L-80 Top Thread ST L Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,812.2 6,104.3 79.00 Aluminum Billet Aluminum Billet 0.000 3H-22L1, 10/20/2021 3:39:05 PM Vertical schematic (actual) L1 Liner; 9,812.2-11,751.0 L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 Junk Catcher; 9,697.0 PORTED WEARSOX; 9,653.4 PORTED CROSSOVER; 9,651.6 NIPPLE; 9,639.6 XO Reducing ; 9,591.0 SBE ; 9,581.6 SEAL ASSY; 9,575.3 PACKER; 9,578.3 LOCATOR; 9,574.2 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP INJ KB-Grd (ft) 42.01 Rig Release Date 2/28/1988 3H-22L1 ... TD Act Btm (ftKB) 11,751.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009760 Wellbore Status INJ Max Angle & MD Incl (°) 99.31 MD (ftKB) 10,800.66 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 240 Date 4/30/2017 Comment SSSV: None Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: ADD LATERALS & GLV C/O 2/9/2017 3H-22L1-02 pproven Casing Strings Casing Description L1-02 Liner OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 10,049.7 Set Depth (ftKB) 11,984.0 Set Depth (TVD) … Wt/Len (l… 4.70 Grade L-80 Top Thread STL Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,049.7 6,124.4 90.38 Aluminum Billet & Anchor OH Anchor & Aluminum Billet 1.920 10,632.2 6,113.5 91.14 Deployment Sleeve Shorty Deployment Sleeve 3H-22L1-02, 10/20/2021 3:39:06 PM Vertical schematic (actual) L1-02 Liner; 10,049.7-11,984.0 PRODUCTION; 35.0-10,052.2 L1-03 Liner; 9,714.0-12,000.0 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 Junk Catcher; 9,697.0 PORTED WEARSOX; 9,653.4 PORTED CROSSOVER; 9,651.6 NIPPLE; 9,639.6 XO Reducing ; 9,591.0 SBE ; 9,581.6 SEAL ASSY; 9,575.3 PACKER; 9,578.3 LOCATOR; 9,574.2 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP INJ KB-Grd (ft) 42.01 Rig Release Date 2/28/1988 3H-22L1-02 ... TD Act Btm (ftKB) 11,984.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009762 Wellbore Status INJ Max Angle & MD Incl (°) 100.26 MD (ftKB) 10,940.98 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 240 Date 4/30/2017 Comment SSSV: None Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: ADD LATERALS & GLV C/O 2/9/2017 3H-22L1-03 pproven Casing Strings Casing Description L1-03 Liner OD (in) 2 3/8 ID (in) 1.99 Top (ftKB) 9,714.0 Set Depth (ftKB) 12,000.0 Set Depth (TVD) … 6,138.7 Wt/Len (l… 4.60 Grade L-80 Top Thread ST-L Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,714.0 6,061.9 52.52 Deployment Sleeve Shorty Deployment Sleeve 1.000 3H-22L1-03, 10/20/2021 3:39:06 PM Vertical schematic (actual) L1-03 Liner; 9,714.0-12,000.0 PRODUCTION; 35.0-10,052.2 IPERF; 9,754.0-9,774.0 APERF; 9,716.0-9,736.0 WHIPSTOC; 9,715.0 APERF; 9,690.0-9,710.0 Junk Catcher; 9,697.0 PORTED WEARSOX; 9,653.4 PORTED CROSSOVER; 9,651.6 NIPPLE; 9,639.6 XO Reducing ; 9,591.0 SBE ; 9,581.6 SEAL ASSY; 9,575.3 PACKER; 9,578.3 LOCATOR; 9,574.2 GAS LIFT; 9,517.2 GAS LIFT; 8,576.8 GAS LIFT; 7,260.2 GAS LIFT; 5,598.9 SURFACE; 35.0-4,347.6 GAS LIFT; 3,246.3 CONDUCTOR; 36.0-115.0 HANGER; 35.0 KUP INJ KB-Grd (ft) 42.01 Rig Release Date 2/28/1988 3H-22L1-03 ... TD Act Btm (ftKB) 12,000.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009763 Wellbore Status INJ Max Angle & MD Incl (°) 101.16 MD (ftKB) 10,170.57 WELLNAME WELLBORE3H-22 Annotation Last WO: End Date 3/20/2016 H2S (ppm) 240 Date 4/30/2017 Comment SSSV: None !" #$% &' (! )*)+*%( ,- +*( • • Pr22 18e -on Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Friday,July 07, 2017 3:33 PM To: Loepp,Victoria T(DOA);Wallace, Chris D (DOA) Cc: Quick, Michael J (DOA);Schwartz, Guy L(DOA) Subject: FW: 3H-22 flutes out of conductor: excessive well head movement Follow Up Flag: Follow up Flag Status: Flagged This well was recently converted to injection;curious if they addressed the subsidence and wellhead movement in their application,or if that would make a difference. It did pass the initial MIT(6/24/17) but we do hold injectors to a higher standard of well integrity. I agree with Jeff that CPAI needs to—at a minimum—provide some science behind their decision-making about wells like this. Jim Regg Supervisor, Inspections AOGCC SCANNED FEB 2 7 2018 333 W.7t'Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From:Jones,Jeffery B(DOA) Sent:Thursday,July 6, 2017 1:07 PM To: Regg,James B (DOA)<jim.regg@alaska.gov> Subject: Fwd: 3H-22 flutes out of conductor:excessive well head movement Hi Jim, I went out to KRF well 3H-22 (deficiency report) and met with Roger Winter&associates to discuss subsidence issues. The surface pipe flutes are above the conductor but the OA is cemented. I wrote the deficiency report because when I was there the well was slugging and shaking the production tree. This well is not an egregious example of subsidence and CPAI doesn't want to do anything until the surface pipe landing flutes are 8" out of the conductor. I asked where the 8" came from&they said that's what their engineering staff came up with. They told me CPAI has been studying subsidence issues for years and they said they have lots of data. Including all wells with subsided conductors and OA measurements over several years. Maybe we should request their data& subsided well list so we can do additional surveillance on these wells? Sent from my iPhone Begin forwarded message: 1 • • From: NSK Well Integrity Field Supv<N1927@conocophillips.com> Date: July 6, 2017 at 12:46:35 PM AKDT To: "Jones, Jeffery B (DOA)" <jeffjones@alaska.gov> Cc: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com>, "NSK Well Integrity Supv CPF3 and WNS" <n2549@conocophillips.com>, "NSK Prod Engr Specialist" <n1139&conocophillips.com> Subject: FW: 3H-22 flutes out of conductor : excessive well head movement Jeff, After mtg up on location and confirming very little movement of well head on 3H-22 ConocoPhillips doesn't feel there is a need to extend conductor. We have actively done tree rise walks on our pads and determined that anything under 8"we will not extend the conductor unless there is an issue. Let us know if there is anything else you need. Roger Winter/Roger Mouser Wells Supervisor NSK 69 Wells Group Office 206 F Wing Office#659-7506 Cell#943-1055 From: NSK Prod Engr Specialist Sent:Sunday,June 11, 2017 3:18 PM To:Jones,Jeffery B(DOA)< eff.iones@alaska.gov> Cc: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com>; NSK Well Integrity Supv CPF3 and WNS< 49@ > Subject: RE: 3H-22 flutes out of conductor : excessive well head movement Jeff, Thanks again for your flexibility with this; Our Well Integrity Supervisors'contact information is listed below. Brent Rogers/Kelly Lyons 1907.659.7224 I n1617@conocophillips.com Rachel Kautz/Travis Smith 1907.659.7126 ( n2549@conocophillips.com I'm not sure if it changes anything regarding your concerns but I noticed 3H-22 is a water injector. There was a pre-production period that ended in May. Please let me know if there's anything else I can do to assist. Cheers, Matt Matthew Raiche/Darrell Humphrey Production Engineering Specialist <image001.jpg> Ph:907.659.7535 I Pg:924 I Mail: NSK 69 2 • • From:Jones,Jeffery B(DOA) [mailto:jeff.iones@alaska.gov] Sent:Saturday,June 10, 2017 8:28 PM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: [EXTERNAL]Re:3H-22 flutes out of conductor: excessive well head movement Ok, I will be back on the the slope on the 15th. Send me their contact info & I will coordinate with them. Thanks, Jeff Sent from my iPhone On Jun 10, 2017, at 2:33 PM,NSK Prod Engr Specialist<nl 139@conocophillips.com>wrote: Jeff, Please let me know when you'd like me to set up the meeting with our well integrity group. If it's easier I can put you in touch so you're able to coordinate directly. Let me know what works best for you. Cheers, Matt From:Jones,Jeffery B(DOA) [mailto:ieff.iones@alaska.gov] Sent:Tuesday, May 16, 2017 12:08 PM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: [EXTERNAL]RE: 3H-22 flutes out of conductor: excessive well head movement OK,we'll hook up next hitch. Jeff B.Jones Petroleum Inspector Alaska Oil&Gas Conservation Commission N.Slope Ofc: 907-659-2714 Mobile: 907-744-4446 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. 3 . • From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent: Monday, May 15, 2017 8:53 AM To:Jones,Jeffery B(DOA)<jeff.iones@alaska.gov> Subject: RE: 3H-22 flutes out of conductor:excessive well head movement Jeff, Looks like we missed you last time! I came up a little late this hitch and Darrell said he wasn't able to reach you before leaving on 5/9. Please let me know when you'll be available next to meet with our well integrity group. Cheers, Matt From:Jones,Jeffery B (DOA) [rnailto:ieff.iones@alaska.gov] Sent:Tuesday,April 18, 2017 8:12 AM To: NSK Prod Engr Specialist< 11139@conocophillips.com> Subject: [EXTERNAL]RE: 3H-22 flutes out of conductor: excessive well head movement Matt, No problem, I will be back on the slope May 3rd through the 10th, barring any unforeseen events. Thanks, Jeff B.Jones Petroleum Inspector Alaska Oil &Gas Conservation Commission N. Slope Ofc:907-659-2714 Mobile: 907-744-4446 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent:Tuesday,April 18, 2017 7:18 AM To:Jones,Jeffery B(DOA)<jeff.jones@alaska.gov> Subject: RE: 3H-22 flutes out of conductor: excessive well head movement 4 • Jeff, Roger is committed to two sites across the field and won't be able to fit an additional meetup in today. Additionally, I've been told roads and pads are still working through some cleanup from the recent winds. Can we circle back on this next time you're up? Cheers, Matt Matthew Raiche/Darrell Humphrey Production Engineering Specialist <i mage001.j pg> Ph:907.659.7535 I Pg:924 I Mail: NSK 69 From:Jones,Jeffery B(DOA) [niaiito:ieff.iones@alaska.gov] Sent: Monday,April 17, 2017 7:15 PM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: [EXTERNAL]RE: 3H-22 flutes out of conductor: excessive well head movement Matt, I had no plans to come to Kuparuk tomorrow as I am working with BPXA on PBF 2-03. Thanks, Jeff B.Jones Petroleum Inspector Alaska Oil &Gas Conservation Commission N. Slope Ofc:907-659-2714 Mobile: 907-744-4446 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. From: NSK Prod Engr Specialist[mailto:n1139@conocophillips.com] Sent: Monday,April 17, 2017 6:44 PM To:Jones,Jeffery B (DOA)<ieff.iones@alaska.gov> Subject: RE: 3H-22 flutes out of conductor excessive well head movement 5 • Jeff Thank you for trying to fit this in last minute. Will you be in Kuparuk tomorrow or would you need to make a trip solely to see us? I'm trying to reach the Well Integrity Supervisor, Roger Winter, as he'd be critical to the meeting. I'll let you know as soon I find out if Roger can make this work with his schedule tomorrow. Cheers, Matt Matthew Raiche/Darrell Humphrey Production Engineering Specialist <image001.jpg> Ph:907.659.7535 I Pg:924 I Mail:NSK 69 From:Jones,Jeffery B(DOA) [mailto:jeff.jones@alaska.gov] Sent: Monday,April 17, 2017 5:08 PM To: NSK Prod Engr Specialist<n1139@conocophillips.cc > Subject: [EXTERNAL]RE: 3H-22 flutes out of conductor excessive well head movement Hi Matt, Is there a time tomorrow that will work for you? I am changing out on Wednesday morning. Thanks, Jeff B.Jones Petroleum Inspector Alaska Oil &Gas Conservation Commission N. Slope Ofc: 907-659-2714 Mobile: 907-744-4446 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. 6 • • From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.cor ] Sent: Monday, April 17, 2017 3:42 PM To:Jones,Jeffery B(DOA)<eff. ones@alaska.gov> Subject: RE: 3H-22 flutes out of conductor : excessive well head movement Jeff, After a thorough review and discussion with our well integrity group we've come to an impasse at the moment. The steel clamp you referred to is part of a floor kit that isn't designed to assist with the issue highlighted. I feel the most productive next step would be an onsite meeting at the wellhead to discuss and exchange ideas. Please let me know and I'll coordinate the meeting with our well integrity group when convenient for you to meet them. Cheers, Matt Matthew Raiche/Darrell Humphrey Production Engineering Specialist <image001.jpg> Ph:907.659.7535 I Pg:924 j Mail:NSK 69 From:Jones,Jeffery B(DOA) [mailto:jeff.jones@alaska.gov] Sent:Thursday,April 13, 2017 6:26 AM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: [EXTERNAL]RE: 3H-22 flutes out of conductor:excessive well head movement Darrel, While I was testing SVS on this well, it was "slugging" and the tree and piping were moving around without anyone shaking it, enough to cause concern that over time a leak may develop. Can you put a steel clamp on the conductor X surface pipe, like you did with other similar wells on this pad? Thanks, Jeff B.Jones Petroleum Inspector Alaska Oil &Gas Conservation Commission N. Slope Ofc:907-659-2714 Mobile: 907-744-4446 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the 7 • • AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent:Tuesday, April 04, 2017 3:58 PM To:Jones,Jeffery B(DOA)<ieft.jones@alaska.gov> Subject: FW: 3H-22 flutes out of conductor: excessive well head movement Jeff-wanted to give you a little background on 3H-22 to help resolve the deficiencies you noted for this well. I asked Well Integrity to investigate your findings and they have replied back to me with the following: 1. The wellhead was identified as growing in 2005. The wellhead had grown enough in March, 2006 to install a 32' hose into the conductor to perform a cement top job. 2. In July 2009,the conductor was topped off with 4.25 bbls of Arctic Grade cement and then 8.5 gallons of RG-2401 in August. 3. It has been noted the tree rise at approximately 6" since December 2012 and has not increased from that to date. 4. The well is a pre-produced injector that required a piping modification to be built following the CTD sidetrack in Jan 2017 so the wellhead was in its' current status when that piping was constructed. It is not believed that piping would have been built to be stressed from the beginning,the piping was designed to bolt up without stressing the piping and the wellhead has not moved since that piping was installed. 5. Also since this well is normally an injector,the temporary line for gaslift is a 1" Parflex hose, we do not see how this is causing stress. 6. Physically trying to shake the tree,the wellhead hardly moves. If you get on the wellhead platform and try to move it,the platform moves but the actual wellhead has very little movement. As you can see from the photos this is new piping by the markings on pipe and does not appear to be showing any stress.As noted the Parflex hose is being used for the artificial lift as this well is an injector currently being produced.The production for this well should be completed by the first part of May and the well swapped back to injection. Please advise us if this response is sufficient and I will complete and forward the Discrepancy Report or if you require further action on this well. Thanks, Darrell Humphrey/Matthew Raiche Production Engineering Specialist <image001.jpg> Ph:907.659.7535 I Pg:924 I Mail:NSK 69 From:Jones,Jeffery B(DOA) Hailto:jeff.jones@alaska.gov] Sent:Tuesday, March 28, 2017 6:04 PM To: NSK Prod Engr Specialist<n1139@conocophillips.com> Subject: [EXTERNAL]FW: 3H-22 flutes out of conductor: excessive well head movement 8 • • Hello Matt, Please sign &return to me. Thanks, Jeff B.Jones Petroleum Inspector Alaska Oil &Gas Conservation Commission N. Slope Ofc:907-659-2714 Mobile: 907-744-4446 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. From:Jones,Jeffery B (DOA) Sent:Tuesday, March 28, 2017 5:48 PM To:Jones,Jeffery B(DOA)<jeff.jones@alaska.gov> Subject: 3H-22 flutes out of conductor:excessive well head movement Jeff Jones AOGCC Petroleum Inspector 907 659 2714- Office 907 744 4446- Mobile 9 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� / DATE: Wednesday,June 28,2017 RP.I.Supervisor l r 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 3H-22 FROM: Chuck Scheve KUPARUK RIV UNIT 3H-22 Petroleum Inspector Src: Inspector Reviewed B P.I.Supry Jr' NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3H-22 API Well Number 50-103-20097-00-00 Inspector Name: Chuck Scheve Permit Number: 188-011-0 Inspection Date: 6/24/2017 Insp Num: mitCS170625093349 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3H-22 Type Inj W TVD 5979 ' Tubing 1950 1950 " 1950 1950 PTD 1880110 - Type Test SPT Test psi 1500 IA 570 2800 " 2710 2700 ' BBL Pumped: 2.9 BBL Returned: 2.7 OA 340 420 • 420 - 420 Interval INITAL P/F Notes: Initial MITIA post conversion per Sundry 317-159 SCANNED AUG 2 22017.. Wednesday,June 28,2017 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Plug Perforations R- Fracture Stimulate E Pull Tubing R Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill ❑erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ PROD TO WAGE] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 188-011 3.Address: P.O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑6.API Number: 99510 50-103-20097-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25523,25531 KRU 3H-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,234 feet Plugs measured None feet true vertical 6,379 feet Junk measured None feet Effective Depth measured 10,052 feet Packer measured 9578 feet true vertical 6,267 feet true vertical 5979 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79 16 115 115 Surface 4,313 12 4,348 3,127 Intermediate Producion 10,017 7 10,052 6,268 RECEIVED Liner JUN 14 2017 Perforation depth Measured depth 9,690 feet ®��}(�.; iy�- True Vertical depth 6,047 feet ry �`a�le.AC + Tubing(size,grade,measured and true vertical depth) 3.5 L-80 9652 6024 Packers and SSSV(type,measured and true vertical depth) Model F Prod Pkr 9578 5979 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED Nov 2 .$ 2017, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 170 490 1180 1300 200 Subsequent to operation: 1900 1150 2865 14.Attachments(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development p ❑ Service E Stratigraphic El Copies of Logs and Surveys Run El 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ff Printed and Electronic Fracture Stimulation Data Cl GSTOR ❑ WINJ El WAG Q GINJ ❑ SUSP❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-159 Contact Name: Lynn Aleshire Authorized Name: Lynn Aleshire Contact Email: Lynn.Aleshire@conocophillips.com Authorized Title: Petroleum Engineer Authorized Signature: Date: 4/121 0? Contact Phone: (907)265-6525 177"L lbJl !l- RBDMS l/'' JUN 1 4 2017 Form 10-404 Revised 4/2017 Submit Original Only 0 y� ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 RECEIVED June 8, 2017 JUN 14 2017 AOGCC Commissioner AC State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 3H-22 (PTD# 188-0110). If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed 1 • 3H-22 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 6/6/17: OPEN WELL. RETURN TO SERVICE 5/27/17: LOAD IA W/225 BBL'S INHIBITED SW&65 BBL'S DIESEL FREEZE PROTECT. SET DV @ 9517' RKB. MIT IA TO 3000 PSI, PASS. 5/26/17: MEASURED BHP @ 9717' RKB (2763 psi) PULLED OV @ 5598' RKB. SET DV @ SAME. PULLED GLV @ 3246' RKB. SET DV @ SAME, DRAW DOWN TEST GOOD. PULLED DV @ 9517' RKB. READY TO LOAD IA, SBHP OF 2,763 PSI MEASURED. 5/22/17: FREEZE PROTECT TUBING W/25 BBLS OF DIESEL. FREEZE PROTECT 3H-34 FLOWLINE W/ 11 BBLS OF DIESEL L, KUPID • 3H-22 •ConocoPhillipsgz,.., . Well Attributes Max Angle&MD TD Alaska.Inc, a Wellbore APW WI Field Name Wellbore Status ncl0 MD(ftKB) Act Btm(ftKB) Can oePhdlips l 501032009700 KUPARUK RIVER UNIT INJ 60.15 5,100.00 10,234.0 ... Comment Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3H-22,6/13/20179:31;25 AM SSSV:None 240 4/30/2017 Last WO: 3/20/2016 42.01 2/28/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,803.0 5/26/2016 Rev Reason:H2S,GLV C/O pproven 5/28/2017 HANGER;35.0Qerg I Casing Strings 1Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(L..Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread ^w41111W WILLI ULIAL110)411.414•.•.1,. ,a,\: '.14, u,0-SURFACE 95/8 8.921 35.0 4,347.6 3,126.8 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread ..o.."...". . ^PRODUCTION 7 8.276 35.0 10,052.2 6,267.8 26.00 J-55 BTC Tubing Strings Tubing DescriptionString Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;36.0-115.0-a TUBING RWO 2016 1 31/21 2.9921 35.01 9 ,586.8] 5,984. 61 9.301 L-80 'Top 8rd Mod Completion Details Nominal ID GAS LIFT;5246.3lif Top(ftKB) Top(TVD)(ftKB) Top not(1 Item Des Com (in) 35.0 35.0 0.09 HANGER McEvoy Gen III Tubing Hanger,MSDP-1-6.5-MS-3,7- 2.950 1/16"x 3-1/2"EUE 8rd Boxx Box,3"H BPVG 9,574.2 5,976.9 52.65 LOCATOR Locator Sub,GBH-22(bottom of the locator spaced out 2.990 3.83') 9,575.3 5,977.6 52.65 SEAL ASSY Seal Assembly,80-40 3.020 Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection LOWER COMP RWO 41/2 3.958 9,578.3 9,736.0 6,075.31 12.60 L-80 STC SURFACE;35.0-4,347.6-. 2016 Completion Details s--i Nominal ID GAS LIFT;5,596.9 inETop(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) 9,578.3 5,979.4 52.65 PACKER 587-400 Model'F'Production Packer 4.000 9,581.6 5,981.4 52.64 SBE 80-40 Seal Bore Extension(SBE) 4.000 9,591.0 5,987.1 52.62 XO Reducing Crossover,4-3/4"Stub Acme Box x 3-1/2"EUE 8rd Pin 2.970 9,639.7 6,016.7 52.57 NIPPLE Nipple,HES,2.813"X,SN:C-3562596 2.812 GAS LIFT;7,260.2lia 9,651.6 6,023.9 52.56 PORTEDPorted Crossover,3-1/2"EUE 8rd Mod Box x 4-1/2"STC 2.992 CROSSOVER Pin L _ 9,653.4 6,025.0 52.56 PORTED Ported Wearsox Joint,4-1/2",12.68,L-80,STC Box x 3.958 WEARSOX Mule Shoe GAS LIFT;6,576.6 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inel Top(ftKB) ((KB) (°) Des Com Run Date ID(in) ..--.. 9,697.0 6,051.5 52.52 Junk Catcher AVA CATCHER(2.73"x 35") 3/14/2017 0.000 _--J 9,715.0 6,062.5 52.52 WHIPSTOC BAKER 3.5"X4.5"WHIPSTOCK(GENII DELTA). 10/6/2016 TOWS=9715,WHIPSTOCK ORIENTATION= GAS LIFT;9,517.2 330DEG,CCL TO TOP OF WHIPSTOCK=14.9', /1.33 RA TAG @7.35 FROM TOP,WHIPSTOP OAL=12.97 Perforations&Slots .f Shot �..:f LOCATOR;9,574.2 'j Top(ND) Btm(NDens D) (shots/ Top(51(B) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 9,690.0' 9,710.0 6,047.3 6,059.4 A-3,3H-22 8/11/1988 8.0 APERF 21/8 EnerJet;60 deg ph PACKER;9,578.3, SEAL ASSY;9,575.3 9,716.0' 9,736.0 6,063.1 6,075.3 A-2,3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet;60 deg ph SBE;5581.6 9,754.0 9,774.0 6,086.2 6,098.4 A-1,3H-22 4/25/1988 4.0 IPERF SOS 4.5"Ultra P;120 x0 Reducing;9,591.0 deg ph Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 3,246.3 2,509.1 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/26/2017 NIPPLE;9,639.6 2 5,598.9 3,802.4 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/26/2017 ' 3 7,260.2 4,693.3 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/15/2017 4 8,576.8 5,395.5 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/19/2016 5 9,517.3 5,942.4 Camco MMG ' 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/27/2017 PORTED CROSSOVER; 9,651.6 Notes:General&Safety End Date Annotation 4/28/1988 NOTE:Bad spot in 7"CSG 8257'-8281';Max ID=6.45";Tested to 2600psi w/10 ppg Brine. PORTED WEAR50X;9,653.4 ��1�gggg��e�,�A��pppp 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 Junk Catcher;9,697.0 APERF;9,690.0-9,710.0-+ li WHIP6TOC;9,715.0 1 APERF;0,710.0-0,730D� IPERF;9,750-9,774.0 II PRODUCTION,35.0-10,052.2 1 1 LI-03 Liner;9,714.0-12,000.0 r KUP 0 0 3H-22L1 •ConocoPhillips Q , Well Attributes Max Angle&MD TD Alaska.trig•. -. Wellbore APSUWI Field Name Wellbore Status Inc!0) MD(ftKB) Act Btm(ftKB) Com 4hillips 501032009760 KUPARUK RIVER UNIT INJ 99.31 10,800.66 11,751.0 A -.. Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3H-22L1,6/13)20175:32:14 AM SSSV: None 240 4/30/2017 Last WO: 3/2072016 42.01 2/28/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _i lRev Reason:ADD LATERALS 8 GLV C/O pproven 2/9/2017 tf HANGER;35.0 �7 .. Casing Strings JCasing Description OD(in) ID(in) Top(ftKB) Set Depth Mai) Set Depth(TVD)...Wt/Len(I...Grade Top Thread L1 Liner 23/8 1.992 9,8122 11,751.0 4.70 L-80 STL Liner Details r:unuun,iuuru,.nremnumeicumuor e,. 1 u, . ,u.,, Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Corn (in) -A-r.., al Top 9,812.2 6,104.3 79.00 Aluminum Aluminum Billet 0.000 Billet CONDUCTOR;36.0-115.0/ GAS LIFT;3,246.3 SURFACE;35.0-4,347.6—. 1 GAS LIFT;5,598.9 GAS LIFT;7,260.2 GAS LIFT;8,576.6 GAS LIFT;9,517.2 4 LOCATOR;9,574.2 d MIN. PACKER;9,578.3 SEAL ASSY;9,575.3 '--riarrI SBE;9,581.8 rwmae' upI XO Reducing;9,591.0 41 (' f NIPPLE;9,639.6 t a. PORTED CROSSOVER; 9,651.6 PORTED WEARSOX;9,653.4 ,_—• WJunk Catcher,9,70.0 _I APERF;9,690.,690.0-9,7110.0 WHIPSTOC;9,715.0 I�1 L1-03 Liner,9,714.0-12,000.0 1■- PRODUCTION;35.0-10,052.2 I I I I L1 Liner;9,812.2-11,751.0 i KUP • •H-22L1-02 ✓ •ConocoPhillips m Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ORB) Act Blm MKS) CarwmVhillips 501032009762 KUPARUK RIVER UNIT INJ 100.26 10,940.98 11,984.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3H-220-02,6/13/20179:32:39 AM SSSV:None 240 4/30/2017 Last WO: 3/20/2016 42.01 2/28/1988 Vertical schematc(actual) Annotation Depth(MB) End Date Annotation 'Last Mod By End Date Rev Reason:ADD LATERALS&GLV CIO pproven 2/9/2017 HANGER;35.0 1-J®T �® Casing Strings Casing Description OD(in) ID(in) Top MKS) Set Depth MKS) Set Depth(TVD)... Wt/Len(I...Grade Top Thread L1-02 Liner 2 3/8 1.992 10,049.7 11,984.0 4.70 L-80 STL • UU•• ,. tan, L W Ue Liner Details U4 Nominal ID �h^ Top(ftKB) Top(TVD)(ftKB) Top net(°) Item Des Com (In) 10,049.7 6,124.4 90.38 Aluminum OH Anchor&Aluminum Billet 1.920 Billet&Anchor CONDUCTOR;36.0-115.0--4 • 10,632.2 6,113.5 91.14 Deployment Shorty Deployment Sleeve Sleeve GAS LIFT;3,246.3 IIDIE SURFACE;35.01,347.6-�- GAS LIFT;5,598.9 GAS LIFT;7,260.2 / GAS UFT;8,576.6 GAS LIFT;9,5172 4 LOCATOR;9,574.2 ,136- PACKER; PACKER;9,578.3 - SEAL ASSY;9,575.3 SBE;9,581.8 XO Reducing;9,591.0 • • NIPPLE.9639.6 T PORTED CROSSOVER; 9,651.6 PORTED WEARSOX; Junk Carohen 9,710.0 I APERF;9,650.0-8,710.0etches aI WHIPSTOC;9,715.0 APERF;9,716.09,736.0-+ _ I (PERF;9,754.0-9,774.0-. I I I L1-03 Liner;9,714.0-12,000.0 PRODUCTION;35.0-10,052.21 I I • L1-02 Liner,10,049.7-11,984.0 KUP r •H-22L1-03 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska.1714: Wellbore APVUWI Field Name Wellbore Status ncl(') MD(RKB) Act Btm(RKB) CAMco'Flit5ps 501032009763 KUPARUK RIVER UNIT INJ 101.16 10,170.57 12,000.0 y ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3H-22L1-03,6113/20179.3308 AM SSSV:None 240 4/30/2017 Last WO: 3/20/2016 42.01 2/28/1988 Vertical schematic(actual) Annotation Depth(MB) End Date Annotation Last Mod By •End Date _ _�p Rev Reason:ADD LATERALS 8 GLV C/O pproven 2/9/2017 , HANGER;35.0 1 (d.- Casing Strings ll ((I Casing Description I0D(in) IID(in) Top(RKB) I Set Depth(RKB) I Set Depth(TVD)...I WVLen(I...Grade I Top Thread L{ L1-03 Liner 2 3/8 1.992 9,7140 12,000.0 6,138.7 4.60 L-80 ST-L Liner Details Nominal ID Top(ROB) Top(TVD)(RKB) Top Incl('( Item Des Corn (in) 9,714.0 6,061.9 52.52 Deployment Shorty Deployment Sleeve 1.000 Sleeve CONDUCTOR;36.0-115.0 • • GAS LIFT;3,246.3in SURFACE;35.0-4,347.0—+1 ` GAS LIFT;5,598.911 • GAS LIFT;7,260.2 J if GAS LIFT',8,576.8 GAS LIFT;9.517.2 LOCATOR;9,574.2 PACKER;9,578.3, C SEAL ASSY;9,575.3 SBE;9,581.8 XO Reducing;9,591.0 • i. 11. NIPPLE;9,639.6 1__ PORTED CROSSOVER; 9,651.8 • PORTED WEARSOX;9.653.4 Junk Catcher;9,697.0— APERF;9,690.09,710.0 •6 WHIPSTOC;9,715.0+ .� APERF;9,716.0-9,730.0--, IPERF;9,754.0-9,774.0--. I 1 PRODUCTION;35.0-10,092.2 L1-03 Liner;9,714.0-12,000.0 OF 711. • I g I//7: A THE STATE Alaska Oil and Gas t,, O�l 1Ls Conservation Commission 333 West Seventh Avenue ` ^�., GOVERNOR BILL WALKER107-" Anchorage, Alaska 99501-3572 aF Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Lynn Aleshire Petroleum Engineer ;R r I ConocoPhillips Alaska, Inc. � �� P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 3H-22 Permit to Drill Number: 188-011 Sundry Number: 317-159 Dear Ms. Aleshire: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this Z� day of April, 2017. RBDMS -4fA? - 3 2017 STATE OF ALASKA ' 2 0 y,,z 7 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS E 20 AAC 25.280 1.Type of Request: Abandon H Plug Perforations H Fracture Stimulate H Repair Well H Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: PROD to WAG l2 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development Q. 188-011-0 3.Address: Stratigraphic ❑ Service ❑ 6.API tber: 153_aOOg .00'-CSD P.O.Box 100360,Anchorage,Alaska 99510 7.If perforating: 8.Well Name and Number: �'47 What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require a spacing exception? Yes ❑ No EJ KRU 3H-22 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25523, 25531 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): alb 10,234' 6,379' t O0-V,' 6 a6?r Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 4,313' 12" 4,348' 3,127' Intermediate Production 10,017' 7" 10,052' 6,268' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9690-9710,9716-9736,9754- 6047-6059,6063-6075,6086- 3.500" L-80 9,652' 9774 6098 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): No SSSV PACKER-587-400 MODEL'F'PRODUCTION PACKER ' MD=9578 TVD=5979 12.Attachments: Proposal Summary 17 Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service E 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/1/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑., . GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned H 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: Lynn Aleshire Contact Name: Lynn Aleshire Authorized Title: Petroleum Engineer Contact Email: Lynn.Aleshire@conocophillips.com ® Contact Phone: (907)265-6525 Authorized Signature: 6 Date: la �,�- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ 4- S F 9 114111 Other: Post Initial Injection MIT Req'd? Yes �]No ❑ A Spacing Exception Required? Yes ElNod Subsequent Form Required: /C-- O RBDSIS t(-- MA.? - 3 201 APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date: Z C/ ri '1/ 07- dei 1r/0- 1777-112(01/7- OR f in Form and Form 10-403 Revised 4/2017 e i is valid for 12 months from the date of approval. Attachmentsencs in Duplicate ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 RECEIVED April 21, 2017 APR 2 0 2017 AOGCC Commissioner AOGCC State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 3H-22 and its associated laterals from Oil Production to Water Alternating Gas Injection service. This request for conversion will conclude the post-CTD pre-production period. Enclosed you will find the 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3H-22, 3H-22L1, 3H-22L1-02 and 3H-22L1-03 (PTD# 188-0110, 216-1450, 216-1470, 216-1480). If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Proposal Summary AOR Detail Area Map Well Schematic 1 • • • 3H-22 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk River Unit Well 3H-22 and its associated laterals L1, L1-02 and L1-03 (PTD# 188-0110, 216-1450, 216-1470, 216-1480) from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: Kuparuk River Unit Well 3H-22 and its associated laterals was completed as an injector on 1/20/17 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing producers 3H-19, 3H-20 and associated laterals and 3H-21. The top of the A sand was found at 9690' MD/6047'TVD. Area Map with 1/4 mile radius around target injection zone(see attached): The map attached shows that, with the exception of the offset injector 3H-31 and producers 3M-29 and 3M- 29A, there are no additional production/injection wells located within a 1/4 mile radius of the 3H-22, 3H-22L1, 3H-22L1-02, 3H-22L1-03 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 3H-22 is and its associated laterals is good and is classified as a "CTD horizontal triple-lateral"well. The injection tubing/casing annulus is isolated via a Baker F packer located at 9578' and (5979'tvd). A State-witnessed MIT-IA will be performed once well 3H-22 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: See attached AOR Detail. The 16" Conductor was cemented with 250 Sx AS I. The 9-5/8" Surface casing was cemented with 1500 Sx AS III &500 Sx Class G. The 7" Production casing was cemented with 1280 Sx Class G & 175 Sx AS I • • ADL355032 ADL025522 ADLO25 ADL025523 3M * 36y501 41> /7_ ADL025524 Ani 525 e M oN cv N 20 z Z 1 1 3 Well Pad Top A Form Picks(ATDB) w N • Producer:Oil N 2 id INJ:MWAG en • INJ:PW P+A Well Trajectory 3H-22 Open Interval ADL025631 -3H-22L1 Open Interval ADL025531 t 1 3H-22L1-02 Open Interval -3H-22L1-03 Open Interval r 1 3H-22 01 Quarter Mile Radius O 3H-22L1 01 Quarter Mile Radius N ConocoPhillips Q 3H-22L1-02 01 Quarter Mile Radius Alaska,Inc. Q 3H-22L1-03 01 Quarter Mile RadiusA Other Active Well 3H_22 et al -- - Other Inactive Well 0 0.2 0.4 0.6 0.8 Injection Sundry Miles CPAI Leases 4/13/2017 1 0 • # (� k Lc kR ) § i! :22, »E ) - /(� _`.-2. - \ \) \/ �\ / /,a _\�` '6 a \ - j { j \ / ( )4\j 72 1 0n ®!» ~ gE` {2! ) � \\\ \\\ f � \! 2 2 LU !.; > ". NLU 8 I /L \ i u_ e. n O . < �» < /- \ / \ t� ) \ ; \ 4g ( a ( \( . . \\ < / /k ! \ \ \ \ } \ ! , / \ 2 | E.' \ 8 • • ... 3H-22 EOW CTD Schematic Modified by RLP 3120/17 3-1/7 9.3#L-80 EUE 8rd Tubing to surface I I 3-1/7 Camco MMG gas lift mandrels at 3246,5599', —.NEI 7260,8577,9517MD 16"82.5#H-40 Locator&80-40 seal assembly at 9574'MD shoe @ 115'MD Baker F packer at 9578 MD Baker 80-40 sealbore extension at 9582'MD L._ 3-1/2"HES landing nipple at 9640'MD (2813"mm ID) shoe @ 4348'MD 4-1/2"Big Tail Pipe 9653'-9736'MD , '1 ,..._...a.: 3H-22L1-03WP07 TD @ 12.000'MD 9714'TOWS ..." NL Liner top at 9714'MD 330"toolface i _ ...„........... A-sand parts --: i ca ..,,p ww--- •;%';'" 3H-22:1-03PB2 ID@ 11,090'MD ..., A3:9690'-9710' 4; • Billet @ 10,350'MD A2:9718'.9738' 47 Al:9754'-9774' = - .:::: C:1 rt „ -;,--- 3H-22L1-03PB1 TD @ 11,072'MD 47 175'MD .7 ----------- - ..--: --:- ....-- 3H-22L1-02 north TD @ 11 984'MD ....,. Billet @ 10,057'MD N r 28#J-55 shoe @ 10,05Z MD : •:. , s':.:^. - -- r„Liao' - --- 3H 22L1 west —mot) Imiii..._ --::::::-.7::::-7.-...-,- • TO @ 11,751'MD Billet @ 9,812'MD STATE OF ALASKA ' ARKA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon fl Plug Perforations E Fracture Stimulate E Pull Tubing r Operations Shutdown E Performed: Suspend E Perforate Other Stimulate r Alter Casing I- Change Approved Program IT Plug for Redrill fl Perforate New Pool rRepair Well r Re-enter Susp Well Other: INJ TO PROD IV 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 9.....: Exploratory fl 188-011 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20097-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25523,ADL 25531 KRU 3H-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10234 feet Plugs(measured) None true vertical 6379 feet Junk(measured) None Effective Depth measured 10052 feet Packer(measured) 9578 true vertical 6267 feet (true vertical) 5979 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 4313 9 5/8 4348 3127 PRODUCTION 10017 7 10052268 scow APR 1 2�„ Perforation depth: Measured depth: 9690-9710,9716-9736, 9754-9774 RECEIVED True Vertical Depth: 6047-6059,6063-6075,6086-6098 MAR 1 0 2017 Tubing(size,grade,MD,and ND) 3.5 X 4.5, L-80,9736 MD,6075 TVD A OGCC Packers&SSSV(type,MD,and ND) PACKER-587-400 MODEL'F'PRODUCTION PACKER @ 9578 MD and 5979 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 375 1350 0 Subsequent to operation 200 240 1650 1350 200 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory Development F Service r Stratigraphic Copies of Logs and Surveys Run IT 16.Well Status after work: Oil F Gas r WDSPL Printed and Electronic Fracture Stimulation Data IT GSTOR r WINJ IT WAG IT GINJ SUSP I- SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-071 Contact Lynn Aleshire @ 265-6525 Email lynn.aleshire@cop.com Printed Name Lynn Aleshire Title Petroleum Engineer Signature Phone:265-6525 Date 3/i h,-- firl/ vr'- 3/ / 11- Form / / i7-Form 10-404 Revised 5/2015 . ..,4,- 34,,h RSDr°JIS �,i ;m,+7 9 2 2U Submit Original Only KUP D 3H-22 ConocoPhillips z Well Attribute Max Angle TD e .Alaska.ino Wellbore API/0W! Field Name Wellbore Status ncl El MD(ftKB) Act Btm(ORB) GanOtah' Mips' 501032009700 KUPARUK RIVER UNIT PROD 60.15 5,100.00 10,234.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3H-22,3/9/2017 0.28 28 AM SSSV. None Last WO. 3/20/2016 42.01 2/28/1988 Vertical schemanc(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date Last Tag:SLM 9,803.0 5/26/2016 Rev Reason ADD LATERALS 8 GLV C/O pproven 2/9/2017 HANGER,35.0 .1� {il1 r l "," Casing Strings F- Cas ng Description OD(in) ID(in) Top(OKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread 5 6 5 2 • Casing 50 ) en J Description (in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth 3,126 Wt/Len(I H- WELDED PRODUCTIONgDescrDescription OD 7ID in) To (ftK) Set Depth1ftKB) Set Depth 267.8 Wt/L26�(00 Grade Top Thread SURFACE 95/8 8.921 35.0 4,347.6 3,1268 36.00 J-55 BTC 0,052 ' Casing De rlption ODGrade Top Thread J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ibfft) Grade Top Connection CONDUCTOR;36.0-115.0 11 TUBING RWO 2016 1 31/21 2.9921 35OI 9,586 .81 5,984.61 9.301 L-80 I EUE 8rd Mod Completion Details i Nominal ID Top(ftKB) Top(TVD)(ORB) Top Incl(°) Item Des Com (in) GAS LIFT;3,246.3 35.0 35.0 0.09 HANGER 'McEvoy Gen III Tubing Hanger,MSDP-1-6.5-MS-3,7- 2.950 1/16"x 3-1/2"EUE 8rd Box x Box,3"H BPVG 9,574.2 5,976.9 52.65 LOCATOR Locator Sub,GBH-22(bottom of the locator spaced out 2.990 3.83') O9,575.3 5,977.6 52.65 SEAL ASSY 'Seal Assembly,80-40 3.020 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection I LOWER COMP RWO 41/2 3.958 9,578.3 9,736.0 6,075.3 12.60 L-80 STC 016 SURFACE;35.0-4,3476 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) lop Incl(') Item Des Com (in) GAS LIFT;5,598.9 - 9,5783 5,979.4 52.65 PACKER 587-400 Model'F'Production Packer 4.000 9,581.6 5,981.4 52.64 SBE 80-40 Seal Bore Extension(SBE) 4.000 9,591.0 5,987.1 52.62 XO Reducing Crossover,4-3/4"Stub Acme Box x 3-1/2"EUE 8rd Pin 2.970 9,639.7 6,016.7 52.57 NIPPLE Nipple,HES,2.813"X,SN:C-3562596 2.812 9,651.6 6,023.9 52.56 PORTED Ported Crossover,3-1/2"EUE 8rd Mod Box x 4-1/2"STC 2.992 GAS LIFT,7,260.z - CROSSOVER Pin It 9,653.4 6,025.0 52.56 PORTED Ported Wearsox Joint,4-1/2",12.6#,L-80,STC Box x 3.958 IliWEARSOX Mule Shoe Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT 85/6.8 Top(ND) Top Incl Top(ftKB) (ftKB) (') Des Corn Run Date ID(in) 9,715.0 6,062.5 52.52 WHIPSTOC BAKER 3.5"X4.5"WHIPSTOCK(GENII DELTA). 10/6/2016 TOWS=9715,WHIPSTOCK ORIENTATION= 330DEG,CCL TO TOP OF WHIPSTOCK=14.9', RA TAG @7.35 FROM TOP,WHIPSTOP OAL=12.97 GAS LIFT;9,5172 C. Perforations&Slots Shot I Dens Top(TVD) BSe(ND) (shots/ 11 Top(MB) Btm(ftKB) (ftKB) (ftKB) Zone Date tt) Type Com 9,690.0 9,710.0 6,047.3 6,059.4 A-3,3H-22 8/11/1988 8.0 APERF 21/8 EnerJet;60 deg ph LOCATOR;9,574,2 ta :I, 9,716.0 9,736.0 6,063.1 6,075.3 A-2,3H-22 '8/11/1988 8.0 APERF 2 1/8 EnerJet;60 deg ph arM T. PACKER;9,576.3 SEAL ASSY;9,575.3 le' ! • Date Event Summary 01/27/17 Install GL valves 01/28/17 Pull AVA catcher on top of liner 01/30/17 POP'd well for 60 days of pre-production i OF ? • • ,,,,%.„ 1,7,,,-.� THE STATE Alaska Oil and Gas 4, o ® Conservation Commission -, fALAS��I� lsr�x �� 333 West Seventh Avenue / t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS--,,L, LAS�P Fax: 907.276.7542 www.aogcc.alaska.gov Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. sCONEQ t ' ' P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 31-1-22 Permit to Drill Number: 188-011 Sundry Number: 317-071 Dear Ms. Aleshire: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080,within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, N647 P9'124-€ . Cathy P. Foerster Chair hat DATED this Z day of March, 2017. RBDMS I,t- PR - 6 2017 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 9 ?017 APPLICATION FOR SUNDRY APPROVALS i „SI -I/7 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: INJ to PROD 1 2.Operator Name: 4.Current Well Class: 0 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 1 .? 188-0110 " 3.Address: 6.APm_be� 3 P. O. Box 100360, Anchorage, Alaska 99510040 Stratigraphic r Service 14�-329 _x-A�9700--000, 00_co 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No p KRU 3H-22 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25523,25531 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 10234 6379 10052' 6267' None None Casing Length Size MD ND Burst Collapse Conductor 79' 16" 115' 115' Surface 4343' 9-5/8" 4348' 3127' Production 10017' 7" 10052' 6268' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9690-9710,9716-9736,9754-9774 6047-6059,6063-6075,6086-6098 3.5 J-55 9586.8 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) 5847-400 Model'F'Production Packer 9578'MD and 5979'ND 12.Attachments: Proposal Summary i,7 WellBore Schematic p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development Service r 14.Estimated Date for 15. Well Status after proposed work: 01/30/17 OIL ,. WINJ Suspended Commencing Operations: r r WDSPL r p r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Lynn Aleshire Printed Name Lynn Aleshire Phone:265-6525 Email: Ivnn.aleshireacop.com Title: Petroleum Engineer Signature Date: Mb-7— Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \I 07 k Rug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r 12_ Other: RBDMS i, WAR - 6 2017 Post Initial Injection MIT Req'd? Yes V" No r-, Spacing Exception Required? Yes r No rt Subsequent Form Required: /b— 4-d 4- APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3-2-17 n9) tii t 1/7-L .3/1//r • �` Submit Form and Rt %Form 10-403 Revised 11/2015 0 26a� is IAL id for 12 months from the date of approval. Attachments in Duplicate • ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. RECEIVED Anchorage, AK 99501-3448 FEB 13 2017 February 13, 2017 AOGCC AOGCC Commissioner State of Alaska, Oil &Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 3H-22 from Water Injection service to Oil Production. This request for conversion is to accommodate the planned 60-day pre-production period. The 10-407 Completion Reports for KRU 3H-22's newly dril laterals 3 -22L1 (PTD#216-145), 3H-22 L1-02 (PTD #216-147) and 3H-22 L1-03 (PTD #216-148) placed them in Oil Production status. After pre-production, the motherbore and its associated laterals will be converted to Water Injection service. The appropriate 10-403 Sundry Applications with AOR details will be submitted for the conversion of the main wellbore and the three laterals. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding KRU 3H-22, (PTD# 188-0110). If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, a Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application 1 KUPPROD • 3H-22 Con0CUPhIltips 9 Well Attributes Max Angle&MD TD Ai ISKa Inc. Wellbore APIIUWI Field Name Wellbore Status net(°) MD(ftKB) Act Btm(ftKB) _Olkhltspc'1' 501032009700 KUPARUK RIVER UNIT PROD 60.15 5,100.00 10,234.0 --. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3H-22,21920172:27:45 PM SSSV:None Last WO. 3/20/2016 42.01 2/28/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date I _If Last Tag:SLM 9,803.0 5/26/2016 Rev Reason:ADD LATERALS 8 GLV C/O pproven 2/9/2017 i ii HANGER:350 Casing Strings iI. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread is CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED IIICasing Description OD(in) ID(In) Top(ftKB' Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread I SURFACE 95/8 8.921 35.0 4,347.6 3,126.8 36.00 J-55 BTC Auu.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 10,052.2 6,267.8 26.00 J-55 BTC Tubing Strings il. Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;36.0-115.0 a TUBING RWO 2016 1 31/21 2.9921 35.01 9,586.871 ; 1 5,984.61 9.301 L-80 'EUE 8rd Mod Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) GAS UFT,3,246.3 -. 35.0 35.0 0.09 HANGER McEvoy Gen HI Tubing Hanger,MSDP-1-6.5-MS-3,7- 2.950 1!! 1/16"x 3-1/2"EUE 8rd Box x Box,3"H BPVG 9,574.2 5,976.9 52.65 LOCATOR -Locator Sub,GBH-22(bottom of the locator spaced out 2.990 3.83') 9,575.3' 5,977.6 52.65 SEAL ASSY Seal Assembly,80-40 3.020 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..1 Set Depth(ND)(...Wt(Mt) 'Grade 'Top Connection LOWER COMP RWO 41/2 3.958 9,578.3 9,736.01 6,075.3 12.60 L-80 STC • 2016 SURFACE;35.04,347.6-. Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 9,578.3 5,979.4 52.65 PACKER 587-400 Model'F'Production Packer 4.000 GAS LIFT.5,598 9 :al: I 9,581.6 5,981.4 52.64 SBE 80-40 Seal Bore Extension(SBE) 4.000 9,591.0 5,987.1 52.62 XO Reducing Crossover,4-3/4"Stub Acme Box x 3-1/2"EUE 8rd Pin 2.970 I9,639.7 6,016.7 52.57 NIPPLE Nipple,HES,2.813"X,SN:C-3562596 2.812 11 9,651.6 6,023.9 52.56 PORTED Ported Crossover,3-1/2"EUE 8rd Mod Box x 4-1/2"STC 2.992 GAS LIFT;7,2602 gr- CROSSOVER Pin 9,653.4 6,025.0 52.56 PORTED Ported Wearsox Joint,4-1/2",12.6#,L-80,STC Box x - 3.958 it WEARSOX Mule Shoe Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;8,576.6 Top(ftKB) (MB) 01 Des Com Run Date ID(inl 111 9,715.0 6,062.5 52.52 WHIPSTOC BAKER 3.5"X4.5"WHIPSTOCK(GENII DELTA). 10/6/2016 TOWS=9715,WHIPSTOCK ORIENTATION= IIE 330DEG,CCL TO TOP OF WHIPSTOCK=14.9',RA TAG @7.35 FROM TOP,WHIPSTOP OAL=12.97 111 GAS LIFT;9.517.2 : Perforations&Slots Shot Dens Top(ND) Btm(TVD) )ohots/f Top(ftKB) BM(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 9,690.0 9,710.0 6,047.3 6,059.4 A-3,3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet;60 deg ph LOCATOR;9,574.2 YYY 9,716.0 - - _9,736.0 6,063.1 6,075.3 A-2,3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet;60 deg ph PACKER;9,578.3 9,754.0 9,774.0 6,086.2 6,098.4 A-1,3H-22 4/25/1988 4.0 IPERF SOS 4.5"Ultra P;120 SEAL ASSY;9,575.3 - I deg ph SBE;9,581.6 Mandrel Inserts St XO Reducing , '9'591.0 V a° Top(TVD) Valve Latch Port Size TRO Run IIIN Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com Il 3,246.3 2,509.1 Cameo MMG 11/2-GAS LIFT GLV RK 0.188 1,357.0 1/27/2017 2 5,598.9 3,802.4 Cameo MMG ' 1 1/2 GAS LIFT GLV RK 0.188 1,295.0 1/27/2017 3 7,260.2 4,693.3 Cameo MMG 1 1/2 GAS LIFT GLV RK 0.188 1,260.0 1/27/2017 4 4 8,576.8 5,395.5 Cameo MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/19/2016 • NIPPLE;9,639k5 9,517.3 5,942.4 Cameo MMG 11/2 GAS LIFT OV RK 0.281 0.0 1/26/2017 Notes:General&Safety End Date Annotation 4/28/1988 NOTE:Bad spot in 7"CSG 8257'-8281';Max ID=6.45"Tested to 2600psi w/10 ppg Brine• . PORTED CROSSOVER; 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 9,651.6 ii PORTED WEARSOX;9,653.41 APERF;9,690.0-9,710.0- WHIPSTOC;9,715.0 L APERF;9,716.0-9,736.0 - IPERF;9.754.0-9,774.0- PRODUCTION;35.0-10,052.2 L1-03 Liner;9,714.0-12,000.0 • i • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Friday, February 10, 2017 9:28 AM To: lynn.aleshire@conocophillips.com' Cc: Loepp,Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: KRU 3H-22 (PTD 188-011): Sundry Application Good morning Lynn, Please provide a cover letter for the KRU 3H-22 sundry application stating the reasons why ConocoPhillips wants to convert the well from an injector to a producer. Also, 10-403 Sundry Applications need to be submitted for all laterals drilled from the motherbore requesting to convert the wells from injector(as permitted)to producers. Laterals are: 3H-22L1 3H-22L1-01 3H-22L1-02 3H-22L1-03 3H-22L1-04 3H-22L1-05. Thank you, this information is needed for our database records. Best Regards, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. rr °M 4r,n , A-l64,,vk, 0i1 al 131/ . y -� ,Q-y67 For l spm, 1 to • • � 9 V) r (-7 (C 0 0 W H > _r o U w CO N Z _ L 4 � °?m v _ D Q 4 h U QTY OO 4"' - ? ro L..) a co y L Y a w ° =o v a C. Q u Q -J ❑ 4-' C a Cr C1 w LO CI C 0 t,0 O O O O O O O v.' -C a) U L N Q 0 d aa)i 0 U 0 U 0 U U U i +J u 0 . 0 0 0 0 0 0 0 0 c (0 u --LII N 2 V) F N N N M V (O N oO 6 ° O -O f, O ✓ N Z 0 a) E U cc Z Q L > -p N 4--' u (6 0 F. CO N -o ,., u ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ C a1 ry a J J J J J J J J J J - C `4-- a 4O ,�, W W W W W W W W W W vi a 'C F- LL LL LL IL LL LL lL LL LL LL ✓ a) a) a, -0 0 J J J J J J J J J JQ _O C C _ Q Q Q Q Q Q Q Q Q Q u0 4- 'C O Z Z Z Z Z Z Z Z Z Z Q) s Q1 • LL LL LL LL LL LL LL LL LL LL K '-. -0 Y Q) , C v L 4 O E N Q a 0 Q U > O - 0 C O ro w > u a +' Z 0 V a. 3 Q (1) a 0 C a V ^h w LL `u LI- LL '7 p a) y ao co V H O $4). co O. O — - —a. 1/...) s ~ a N Md to OS w s W > V tet a 0 Ag 0 11 a' 0 N Z E le 73 o ud J J J J J J J J J J ii 01 t/1w dit)111-)...9 I I f o wwZZZZww'ww L > > R a' a' > >;> > Q 2 2 > > > >WWWW 2 RIR2 z Y Y cErtY Y Y Y_ Y w Q Q > > > > Q Q Q Q O w� o C.! Y Y a_ a a_ a Y Y Y Y c 0 N > > d4 C aim 0 cc W N M N M co co O O X N .� ❑ 0 0 0 0 0 0 0 0 •r^ E ill �� 0 0 0 0 0 0 0 0 0 0 a) _ O co O 0 0 O O O O co co ro U � '� (-) ° > > > § § 3 § § O4 > ao ao Cr rn co a) rn o f9 C7 (c m (o m (o w CI CI 0 0 0 ❑ ❑ ❑ ❑ ❑1 Q c a c E 0 a o O O o O o o o o " o o o o 000000 Q co cr) {t' ..,.,:.::= P Y) N CO (0 N N N a+ • LI (!I u N .- M CO N CO N C ,- 0- N a- O M O M 0 N O E N a N N N N N N N N N N '4 • N < 6 A o) r) o) A o) 0, 6 w c a. 01 NONONONNNNu O O 0CD O O O 0 �- 0 OU 0 0 0 0 0 0 0 0 0 0 ++ N c O aa 4 C It) U) N u) In w u) N u) u) d v O C C CU On S QoE a, ,� • a w Y w N E E ra .� Z G.; 5. , Q ., N O — u N> INTr N O +4.4 ' Q) C L. TS E a) v v 1 = z m th Y Y (.j i ma o6 co N — C < N i.JLT, M M (y N ,. M M v- N U, z to O O .ED a= t�I A., CO C y E E co CA a0ex ~ c ? F a a 1-0 1O- STATE OF ALASKA ALIOKA OIL AND GAS CONSERVATION COM OSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon I.... Plug Perforations r Fracture Stimulate Pull Tubing 17 Operations Shutdown ]✓.•... Performed: Suspend P Perforate E Other Stimulate "" Alter Casing g r Change Approved Program Plug for Redrill ( Perforate New Pool F Repair Well Re-enter Susp Well F Other: CTD Setup F 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development P Exploratory fl 188-011 3.Address: .. 6.API Number: Stratigraphic Service l P. O. Box 100360,Anchorage,Alaska 99510 50-103-20097-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25523 KRU 3H-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: . Total Depth measured 10234 feet Plugs(measured) 9636 true vertical 6379 feet Junk(measured) None Effective Depth measured 9818 feet Packer(measured) 9578 true vertical 6125 feet (true vertical) 5979 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 4313 9 5/8 4348 3127 PRODUCTION 10017 7 10052 6268 RECEIVED Perforation depth: Measured depth: 9690'-9710', 9716'-9736', 9754'-9774' APR 0 2016 True Vertical Depth: 6047'-6059', 6063'-6075', 6086'-6098' //� ^ AO(CC Tubing(size,grade,MD,and TVD) 3 1/2 X 4 1/2, L-80, 9736 MD, 6075 TVD Packers&SSSV(type,MD,and TVD) PACKER-587-400 MODEL'F' PRODUCTION PACKER @ 9578 MD and 5979 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: y Intervals treated(measured): N/A \P� 1 2 ati Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut In Subsequent to operation Off Line 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations''7 Exploratory Development I Service Iv' Stratigraphic ia . Copies of Logs and Surveys Run I..-.. 16.Well Status after work: Oil P Gas P WDSPL 1--- Printed Printed and Electronic Fracture Stimulation Data P GSTOR ...... WINJ 17 WAG 1- GINJ I- SUSP P SPLUG 1- 17. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-059 Contact Andrew Beat @ 265-6341 Email Andrew.T.Beat/conocophillips.com Printed Name Andrew t Title Sr. Wells Engineer Signature 1 Phone:265-6341 Date / , / Form 10-404 Revised 5/2015 VTL 4 C/Z /!G Submit Original Only A Vz--(,A RBDMS 0-, APR 1 1 2016 • • et-„, Operations Summary (with Timelog Depths) ,,„ 3H-22 Phitips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB),., End Depth(ftKB) 3/9/2016 3/9/2016 3.50 MIRU MOVE MOB P De-Mob rig off 3H-20 03:30 07:00 3/9/2016 3/9/2016 9.00 MIRU MOVE MOB P MIRU Rig accepted @ 16:00 Hrs. 07:00 16:00 3/9/2016 3/9/2016 3.50 MIRU MOVE RURD P RU secondary valve on IA. RU 16:00 19:30 Lubricator. 3/9/2016 3/9/2016 0.50 MIRU WELCTL MPSP P Pulled BPV.Tubing=200 psi. IA= 19:30 20:00 180 psi.Lay down lubricator. 3/9/2016 3/9/2016 1.50 MIRU WELCTL COND P Continued to take on 14.8 Mud.Build 20:00 21:30 Mud push sweep.prep for well kill. 3/9/2016 3/10/2016 2.50 MIRU WELCTL KLWL P PT lines to 3500 psi.Begin well kill 21:30 00:00 pumping 40 BBL 14.8 Hi-vis sweep. followed with 14.8 WBM @ 3BPM. ICP=145 psi. 3/10/2016 3/10/2016 2.50 MIRU WELCTL KLWL P Continue to circulate in 14.8#WBM @ 00:00 02:30 3 BPM..FCP=1040 psi©1.5 BPM 3/10/2016 3/10/2016 0.50 MIRU WELCTL OWFF P Flow check. 02:30 03:00 3/10/2016 3/10/2016 0.50 MIRU WELCTL RURD P RD kill Lines from tree. 03:00 03:30 3/10/2016 3/10/2016 0.50 MIRU WHDBOP MPSP P Install BPV 03:30 04:00 3/10/2016 3/10/2016 2.00 MIRU WHDBOP NUND P ND Tree and adapter.RU approved 04:00 06:00 lifting apparatus for tree removal,pull adapter off extended neck seals at 18k. Attempt to clean and inspect 3- 1/2 8rd lift threads-no success-only able to make up 6 out of 13 threads. 3/10/2016 3/10/2016 7.00 MIRU WHDBOP NUND P NU 13-5/8"5M BOPE adapted to 7- 06:00 13:00 1/16"5M McEvoy Gen III Tbg head. Adjust turn buckles to center well under sub base, Install Riser. Prep cellar and well head for conducting Initial BOP test. 3/10/2016 3/10/2016 0.25 MIRU WHDBOP BOPE P Conduct Initial BOP test @ 250/4,500 13:00 13:15 psi on rams and valves. 250/3,500 psi on Annular w/2-7/8 and 3-1/2 test joints. 24 hr notice was submitted to AOGCC on 3-8-16 @ 18:11 hrs and Right to witness was waived by Matt Herrera on 3-9-16 @ 17:30 hrs. Test BOP components in the following sequence 1) 2-7/8 test jt in Annular to 250/ 3,500 psi against CMV 1-2-3-16, Rig Floor Kill,Outer Test spool valve and 3-1/2 8RD FOSV and HT 38 Dart valve. Page 1/11 Report Printed: 4/5/2016 • • lung Operations Summary (with Timelog Depths) ._ W 3H-22 conocophiiiips Rig: NABORS 7ES Job: RECOMPLETION Time Log ".. C_. Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/10/2016 3/10/2016 1.00 MIRU WHDBOP BOPE T Conduct Initial BOP test @ 250/4,500 13:15 14:15 psi on rams and valves. 250/3,500 psi on Annular w/2-7/8 and 3-1/2 test joints. 24 hr notice was submitted to AOGCC on 3-8-16© 18:11 hrs and Right to witness was waived by Matt Herrera on 3-9-16 @ 17:30 hrs. 2) 2-7/8 test jt in UPR 2-7/8 x 5" VBR's to 250/4,500 psi against CMV 1-2-3-16,Rig Floor Kill,Outer Test spool valve and 3-1/2 8RD FOSV and HT 38 Dart valve. Blind ram door seal failed-Attempt to tighten door seal, retry test-failed. 3/10/2016 3/10/2016 1.50 MIRU WHDBOP BOPE T Bleed off pressure,blow down and 14:15 15:45 drain BOP stack. Open blind ram door and replaced seal. Retighten door. Fill stack and function rams to remove air from ram cavity Page 2/11 Report Printed: 4/5/2016 • Operations Summary (with Timelog Depths) r e ` 3H-22 ConocoPtaillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB)', End Depth(ftKB)', 3/10/2016 3/10/2016 7.50 MIRU WHDBOP BOPE P Conduct Initial BOP test @ 250/4,500 15:45 23:15 psi on rams and valves. 250/3,500 psi on Annular w/2-7/8 and 3-1/2 test joints. 24 hr notice was submitted to AOGCC on 3-8-16 @ 18:11 hrs and Right to witness was waived by Matt Herrera on 3-9-16 @ 17:30 hrs. Attempt to Test BOP components in the following sequence 2) 2-7/8 test jt in UPR 2-7/8 x 5" VBR's to 250/4,500 psi against CMV 1-2-3-16, Rig Floor Kill,Outer Test spool valve and 3-1/2 8RD FOSV and HT 38 Dart valve.Fail/Pass 3) 2-7/8 test jt in LPR 2-7/8 x 5" VBR's to 250/4,500 psi.fail/pass 4) 3-1/2 test jt in Annular to 250/ 3,500 psi against CMV 1-2-3-16,Rig Floor Kill,Outer Test spool valve and 3.5 8rd FOSV. 5) 3-1/2 test jt in UPR 2-7/8 x 5" VBR's to 250/4,500 psi against CMV 4-5-6,HCR Kill,Pass 6) 3-1/2 test jt in LPR 2-7/8 x 5" VBR's to 250/4,500 psi.Pass 7) BR,Choke 8,9,10.7 Failed initial test Fail/pass 8) Supper choke,Bean choke. Pass 9) Choke 10,11, Man kill.Pass 10) Choke 12,13,15. Pass 11) Choke 14. Pass 1'2)Choke HCR,TD man XT 38 IBOP.Pass 13) Man choke,TD HCR.PAss 14) Choke#7.Pass Draw down:200 psi recovery=15 sec.full recovery=98 sec. Nitrogen X 5=1950 psi. 3/10/2016 3/10/2016 0.25 MIRU WHDBOP RURD P RD testing equipment 23:15 23:30 3/10/2016 3/11/2016 0.50 COMPZN RPCOMP RURD P RU Weatherford and Camco 23:30 00:00 equipment. 3/11/2016 3/11/2016 0.50 COMPZN WHDBOP MPSP P Pull PBV. 00:00 00:30 Page 3/11 Report Printed: 4/5/2016 III 0 �a)�;i�F K L's f is � Operations SummaryDe �with Timelog Depths) ) msµ 3H-22 CcoPhiHliiprs Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr)', Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)', 3/11/2016 3/11/2016 0.50 COMPZN RPCOMP BHAH P Make up spear assembly. 00:30 01:00 3/11/2016 3/11/2016 0.50 COMPZN RPCOMP FISH P Engaged spear into hanger and set. 0.0 32.0 01:00 01:30 Pulled hanger to rig floor.55K for hanger to move.72 K string with blocks 3/11/2016 3/11/2016 0.50 COMPZN RPCOMP PULL P Removed SSSV lines from hanger 32.0 0.0 01:30 02:00 and laid down hanger. 3/11/2016 3/11/2016 2.50 COMPZN RPCOMP CIRC P Circulated hole volume to condition 0.0 0.0 02:00 04:30 mud.@ 5 BPM @ 2720 psi.Pumped dry job. 3/11/2016 3/11/2016 12.50 COMPZN RPCOMP PULL P POOH laying down 2 7/8 8rd 9,492.0 0.0 04:30 17:00 completion.Recovered 32 of the 34 SS bands.SSSV,290 Jts of 2-7/8,J- 55 EUE 8rd Tubing,4 GLM's, 15.04-ft of jt 291. 3/11/2016 3/11/2016 1.00 COMPZN RPCOMP RURD P RD Weatherford pipe handling 0.0 0.0 17:00 18:00 equipment.RU Drill pipe equipment. Installed wear ring. 3/11/2016 3/11/2016 1.50 COMPZN RPCOMP BHAH P Load and pick up BHA#2;.5.5"Wash 0.0 399.0 18:00 19:30 pipe assembly. 3/11/2016 3/12/2016 4.50 COMPZN RPCOMP PULD P RIH with BHA#2 picking up drill pipe. 399.0 2,900.0 19:30 00:00 3/12/2016 3/12/2016 8.00 COMPZN RPCOMP PULD P Continue to RIH w/BHA#2 to jt#288, 2,900.0 9,480.0 00:00 08:00 Tag top of fish @ 9,490-ft ORKB, 9,480-ft current rig floor. 3/12/2016 3/12/2016 1.50 COMPZN RPCOMP CIRC P 4.4 bpm @ 2,420 psi.while rotating© 9,480.0 9,480.0 08:00 09:30 23 rpm w/6.4k Free torque. Picked up BHA#3 Overshot assembly W 2 7/8 grapple.and dress off guide. 3/12/2016 3/12/2016 0.50 COMPZN RPCOMP WASH P While circulating at 5 bpm @ 2,420 9,480.0 9,516.0 09:30 10:00 psi.with no rotating,washed down from 9,480-ft to 9,526-ft. 3/12/2016 3/12/2016 1.00 COMPZN RPCOMP CIRC P Circulate Bottoms up at 5 bpm @ 9,516.0 9,480.0 10:00 11:00 2,420 psi while rotating and reciprocating. 3/12/2016 3/12/2016 5.00 COMPZN RPCOMP TRIP P POOH laying down 2 singles and 9,480.0 399.0 11:00 16:00 stranding back 96 stands to 399-ft 3/12/2016 3/12/2016 4.00 COMPZN RPCOMP BHAH P POOH standing back 3 stands of 4-3/4 399.0 321.0 16:00 20:00 DC's,lay down Jar/BS assembly along with 3 Jts of 5-3/4"Wash Pipe. 3/12/2016 3/13/2016 4.00 COMPZN RPCOMP TRIP P RIH with BHA#3 321.0 7,889.0 20:00 00:00 3/13/2016 3/13/2016 1.25 COMPZN RPCOMP TRIP P Continue to RIH with overshot 7,889.0 9,460.0 00:00 01:15 assembly on drill pipe. 3/13/2016 3/13/2016 1.75 COMPZN RPCOMP CIRC P Est parameters.Up wt=175K.78K 9,460.0 9,460.0 01:15 03:00 Down 100K RT wt.@ 20 RPMs @ 7K F/TQ.circulation @ 5 BPM @2725 psi.Condition mud. 3/13/2016 3/13/2016 1.25 COMPZN RPCOMP FISH P Tagged TOF at 9479 ft RKB.ORKB= 9,460.0 9,489.5 03:00 04:15 9489.5.rotated over the top of the stump.Engaged fish pulled up to 9460 ft.broke circulation @ 2 BPM @ 900 psi.dropped back over the top of the stump.pressure increased to 1550 psi.indication of seals on. 3/13/2016 3/13/2016 0.25 COMPZN RPCOMP OWFF P Flow check 15 min's. 9,489.5 9,400.0 04:15 04:30 Page 4/11 Report Printed: 4/5/2016 i 0 Operations Summary (with Timelog Depths) ,0 '- R 3H-22 ConocoPhiflips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End,Depth(ftK8)', 3/13/2016 3/13/2016 6.00 COMPZN RPCOMP TRIP P POOH with BHA#3. 9,400.0 321.0 04:30 10:30 3/13/2016 3/13/2016 1.50 COMPZN RPCOMP BHAH P Laid down over shoit.recovered 321.0 0.0 10:30 12:00 15.01 ft cut 2 7/8"6.08 pup jt.OEJ seals 17.6. 3/13/2016 3/13/2016 1.50 COMPZN RPCOMP BHAH P Pick up BHA#4:over shot with 3.25 0.0 321.0 12:00 13:30 grapple. 3/13/2016 3/13/2016 0.50 COMPZN RPCOMP SVRG P Service and inspect top drive 321.0 321.0 13:30 14:00 3/13/2016 3/13/2016 4.50 COMPZN RPCOMP TRIP P RIH with BHA#4 321.0 9,435.0 14:00 18:30 3/13/2016 3/13/2016 1.00 COMPZN RPCOMP SLPC P Slip and cut drilling line. 9,435.0 9,435.0 18:30 19:30 3/13/2016 3/13/2016 1.00 COMPZN RPCOMP CIRC P Circulate hole volume to condition 9,435.0 9,435.0 19:30 20:30 mud prior to engagement of packer. 3/13/2016 3/13/2016 0.50 COMPZN RPCOMP FISH P Engaged top of fish @ 9502.0 with 9,435.0 9,523.0 20:30 21:00 grapple.Guide depth=9507.00. Up wt= 165 K.Down wt=82 K down. 100 K RT.20 RPM=8K F/TQ.Set grapple.Opened jars.straight pulled to 250K.No movement hit jars twice at 50 K.Packer free down.Sat down with packer at 9523 ft guide depth.tail depth=9608.0 ft set jars.pulled 50 K over packer free up.Pulled up to 9498 ft. 3/13/2016 3/13/2016 2.00 COMPZN RPCOMP CIRC P Dropped ball and pumped down 9,523.0 9,523.0 21:00 23:00 opened pump out sub.Open PO @ 600 psi.Circulated one hole volume @ 3 BPM @ 1245 psi. 3/13/2016 3/14/2016 1.00 COMPZN RPCOMP TRIP T POOH with fish.Swabbing.pumped 9,523.0 9,400.0 23:00 00:00 15 BBL 16.8#dry job.Continue to POOH. 3/14/2016 3/14/2016 2.00 COMPZN RPCOMP TRIP T Continued to POOH at 10'per min. 9,400.0 9,294.0 00:00 02:00 swabbed back 3.1 bbls in two stands. hole not taking fluid.worked packer up/down from 9180-9120.ft. attempting to wash element free.Run 1 stand back in hole. 3/14/2016 3/14/2016 2.50 COMPZN RPCOMP CIRC T Circulated @ 2 BPM @ 790 psi.took 9,294.0 9,294.0 02:00 04:30 17.5 bbls to get returns.Increased rate to 3 BPM @ 1180 psi down from 1st circulation by 100 psi.losing rate of 75 BPH.Total loss during bottoms up=131.5 BBLS. 3/14/2016 3/14/2016 17.50 COMPZN RPCOMP PMPO T POOH at 10 ft per min.pumping at.5 9,294.0 320.0 04:30 22:00 BPM @ 620 psi. 3/14/2016 3/15/2016 2.00 COMPZN RPCOMP BHAH P Lay down BHA#4:Recovered 17.45 320.0 0.0 22:00 00:00 slick stick,7.27 packer.2 jts and x nipple=67.22.over all=91.94 ft 3/15/2016 3/15/2016 1.00 COMPZN RPCOMP BHAH P Break off the overshot from the OEJ 0.0 0.0 00:00 01:00 slick stick and lay down OEJ slick stick with packer. 3/15/2016 3/15/2016 0.50 COMPZN WELLPR SVRG P Daily top drive service and inspection. 0.0 0.0 01:00 01:30 3/15/2016 3/15/2016 1.00 COMPZN WELLPR BHAH P PU and MU BHA#5:6-1/8"bit clean 0.0 327.0 01:30 02:30 out assembly. 3/15/2016 3/15/2016 0.50 COMPZN WELLPR PULD P RIH with BHA#5 picking up DP from 327.0 800.0 02:30 03:00 the pipe shed from 327'to 800'RKB. Page 5/11 Report Printed: 4/5/2016 ° • • ,, Operations Summary (with Timelog Depths) 44- �. ivy .. 4 3H-22 conocophiwps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur Or) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/15/2016 3/15/2016 6.75 COMPZN WELLPR TRIP P TIH with BHA#5 from 800'to 9410' 800.0 9,410.0 03:00 09:45 RKB(PU=170K and SO=80K) 3/15/2016 3/15/2016 0.25 COMPZN WELLPR SFTY P Kick while tripping drill. Well secured 9,410.0 9,410.0 09:45 10:00 in 33 seconds and crew in place in 54 seconds. Held AAR with rig crew. 3/15/2016 3/15/2016 0.50 COMPZN WELLPR SVRG P DOM'S inspection on the TD. 9,410.0 9,410.0 10:00 10:30 3/15/2016 3/15/2016 0.50 COMPZN WELLPR WASH P MU the TD and obtain parameters. 9,410.0 9,971.0 10:30 11:00 Mud pump#1 SPR: 2 BPM=1140 psi and 3 BPM=1480 psi. Mud pump #2 SPR: 2 BPM=1120 psi and 3 BPM=1280 psi. PU= 170K,SO= 80K,and rotating weight= 108K. Wash down at 5 BPM=2750 psi to 9694'RKB with a high loss rate. Continue in the hole without pumps to 9844'RKB and set 10K down. Bring the pumps up to 5 BPM with 60 RPM rotation and work down to 9883'RKB. Shut down the rotary and continue to wash down to hard tag at 9971'RKB with 10K down. 3/15/2016 3/15/2016 1.00 COMPZN WELLPR CIRC P Circulate a bottoms up at 5 BPM= 9,971.0 9,971.0 11:00 12:00 2750 psi while rotating at 20 RPM and reciprocating(7500 ft-lbs free torque). Got a large amount of frac sand over the shakers. Pumped 421 bbls and got 348 bbls returns. 3/15/2016 3/15/2016 0.50 COMPZN WELLPR PMPO P Pump out of hole at 2 BPM=1020 psi 9,971.0 9,410.0 12:00 12:30 from 9971'to 9410'RKB to bet the bit above the perforations. 3/15/2016 3/15/2016 2.50 COMPZN WELLPR CIRC P Circulate the well at 5 BPM=2750 psi 9,410.0 9,410.0 12:30 15:00 but had a high loss rate. Slowed the pumps down to 3 BPM= 1430 psi (loss rate= 17 BPH)while rotating at 20 RPM and reciprocating(7500 ft-lbs free torque). 3/15/2016 3/15/2016 2.00 COMPZN WELLPR OWFF T Stand back 1 stand of DP and monitor 9,410.0 9,410.0 15:00 17:00 the well. Had slight flow from the DP and the IA. 3/15/2016 3/15/2016 2.00 COMPZN WELLPR COND T Weight up the mud system from 14.8 9,410.0 9,410.0 17:00 19:00 ppg to 14.9 ppg mud. 3/15/2016 3/16/2016 5.00 COMPZN WELLPR CIRC T Circulate the well over to 14.9 ppg 9,410.0 9,410.0 19:00 00:00 mud at 1.5 BPM(ICP and FCP=950 psi). Lost 20 bbls during the circulation. 3/16/2016 3/16/2016 1.00 COMPZN WELLPR OWFF T Got good 14.9 ppg mud at surface. 9,410.0 9,410.0 00:00 01:00 Shut down the pumps and monitored the well. Had slight flow from the DP and the IA. 3/16/2016 3/16/2016 1.00 COMPZN WELLPR COND T Weight up the mud system from 14.9 9,410.0 9,410.0 01:00 02:00 ppg to 15.0 ppg mud. 3/16/2016 3/16/2016 6.00 COMPZN WELLPR CIRC T Circulate the well over to 15.0 ppg 9,410.0 9,410.0 02:00 08:00 mud at 1.5 BPM=1000 psi. 3/16/2016 3/16/2016 0.50 COMPZN WELLPR OWFF T Blow down the TD. Monitor the well 9,410.0 9,410.0 08:00 08:30 for 30 minutes and the well is static. 3/16/2016 3/16/2016 1.50 COMPZN WELLPR PMPO T TOOH 2 stands on elevators 9,410.0 8,230.0 08:30 10:00 (calculated hole fill=2.23 bbls and actual hole fill=0.3 bbls). Pump out of the hole 8 stands at 1 BPM=760 psi at a rate of 65 FPM to 8230'RKB (PU= 160K and SO=74K). Page 6/11 Report Printed: 4/5/2016 • 411, Operations Summary (with Timelog Depths) 3H-22 Conoco hi lips '=;` Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time: :End Time Dur(hr) Phase Op Code Activity Code. Time P-T-X Operation (ft(S) End,Depth(ftKB). 3/16/2016 3/16/2016 2.00 COMPZN WELLPR OWFF T Monitor the well and had slight flow. 8,230.0 8,230.0 10:00 12:00 The flow increases and decreases; acts like the well is breathing. 3/16/2016 3/16/2016 1.50 COMPZN WELLPR OWFF T Continue to monitor the well into a low 8,230.0 8,230.0 12:00 13:30 volume container(1.4 gallon gain in 90 minutes). 3/16/2016 3/16/2016 1.00 COMPZN WELLPR TRIP T TIH to 9663'RKB(PU=160K and SO 8,230.0 9,663.0 13:30 14:30 =75K). 3/16/2016 3/16/2016 4.00 COMPZN WELLPR CIRC T Circulate bottoms up at 1.5 BPM= 9,663.0 9,663.0 14:30 18:30 1020 psi checking mud weights in/out every 15 minutes. Continue to circulate until clean. No gas seen at bottoms up. 3/16/2016 3/16/2016 0.50 COMPZN WELLPR OWFF P Monitor the well for 30 minutes and 9,663.0 9,663.0 18:30 19:00 slight breathing observed. 3/16/2016 3/17/2016 5.00 COMPZN WELLPR PMPO P Pump out of the hole at 1 BPM=850 9,663.0 6,380.0 19:00 00:00 psi from 9663'to 6380'RKB. 3/17/2016 3/17/2016 0.50 COMPZN WELLPR OWFF P Monitor the well for 30 minutes and 6,380.0 6,380.0 00:00 00:30 slight breathing observed. 3/17/2016 3/17/2016 11.50 COMPZN WELLPR PMPO P Continue to pump out of the hole at 1 6,380.0 327.0 00:30 12:00 BPM=850 psi from 6380'to 327' RKB. Monitoring the well for 5 minutes every 10 stands pulled(slight breathing). Filling 1.5 times pipe displacement per 5 stands. 3/17/2016 3/17/2016 3.00 COMPZN WELLPR BHAH P Monitor the well and the well is static. 327.0 0.0 12:00 15:00 POOH laying down(9)4-3/4"DCs, fishing jars,bumper sub,magnet, 6.151"OD string mill,pup joint,casing scraper,and 6-1/8"Bit. Clean and clear the floor. 3/17/2016 3/17/2016 1.00 COMPZN RPCOMP RURD P Bring handling equipment and power 0.0 0.0 15:00 16:00 tong to the rig floor. RU Weatherford power tubing tong. 3/17/2016 3/17/2016 0.50 COMPZN RPCOMP SVRG P Service the TD and DOMS inspection. 0.0 0.0 16:00 16:30 3/17/2016 3/17/2016 0.25 COMPZN RPCOMP SFTY P Held PJSM with third party venders 0.0 0.0 16:30 16:45 and rig crew on running the lower completion packer assembly on drill pipe. 3/17/2016 3/17/2016 2.25 COMPZN RPCOMP PUTB P PU mule shoed Wearsox joint and 0.0 174.0 16:45 19:00 install 6-1/8"Hydroform centralizer with stop rings on mule shoe. PU second Wearsox joint,install 6-1/8" Hydroform centralizer on the pin end with stop rings and Baker Lok the Wearsox connection. MU the nipple assembly and place 2.78"OD x 8' catcher sub on top of the PXX plug/VV prong set in'X'nipple. MU 1 joint of 3 -1/2"tubing. Fill the joint of tubing with pal mix to top of plug/prong. MU F-1 Packer with SBE assembly. Land in slips,remove'J'hydraulic running tool,fill the packer/SBE assembly with pal mix,MU`J'hydraulic running tool, and RIH. Page 7/11 Report Printed: 4/5/2016 • • , ` Operations Summary (with Timelog Depths) xn A ` 'sz't ' 3H-22 sf ConocoPh '' Rig: NABORS 7ES Job: RECOMPLETION Time Log StartDepth Start Time End Time Dur(hr)', Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(5KB):. 3/17/2016 3/18/2016 5.00 COMPZN RPCOMP RCST P TIH with lower completion assembly 174.0 6,796.0 19:00 00:00 on 3-1/2"HT-38 DP to 6796'RKB at midnight(PU=120K and SO=68K) and toping of the DP every stand with the fill up hose. 3/18/2016 3/18/2016 2.25 COMPZN RPCOMP RCST P Continue to TIH with lower completion 6,796.0 9,736.0 00:00 02:15 assembly on 3-1/2"HT-38 DP from 6796'to 9736'RKB(PU=165K and SO=80K)and toping of the DP every stand with the fill up hose. 3/18/2016 3/18/2016 0.25 COMPZN RPCOMP CIRC P Circulate 10 bbls at 1 BPM=800 psi 9,736.0 9,736.0 02:15 02:30 to verify flow path. 3/18/2016 3/18/2016 1.25 COMPZN RPCOMP PACK P Drop the setting ball and circulate at 9,736.0 9,578.0 02:30 03:45 1.5 BPM=900 psi to the ball seat in the model'J'hydraulic setting tool. Pressure up to 1500 psi to set the packer,pull 10K to ensure packer set, and continue to pressure up to 2600 psi to release the model'J'hydraulic setting tool. 3/18/2016 3/18/2016 0.25 COMPZN RPCOMP RURD P Lay down 1 joint of DP,blow down the 9,578.0 9,573.0 03:45 04:00 TD,and RU pressure testing equipment. 3/18/2016 3/18/2016 0.50 COMPZN RPCOMP PRTS P PT the model'F'packer,PXX plug 9,573.0 9,573.0 04:00 04:30 with W prong,and 7"casing to 1000 psi for 10 minutes(good test)with 15.0 ppg mud. 3/18/2016 3/18/2016 2.00 COMPZN RPCOMP COND P Cleaning the pill pit and building 9,573.0 9,573.0 04:30 06:30 spacer pills for displacing the well from 15.0 ppg mud to seawater. 3/18/2016 3/18/2016 0.50 COMPZN RPCOMP SVRG P Service the TD and DOM'S inspection. 9,573.0 9,573.0 06:30 07:00 3/18/2016 3/18/2016 5.00 COMPZN RPCOMP DISP P Displacing the well from 15.0 ppg mud 9,573.0 9,573.0 07:00 12:00 to seawater. Pumped 80 bbls of 11.6 ppg heavy viscous brine followed by 38 bbls of viscous seawater,then displace with 422 bbls of seawater until clean returns at surface. Circulating at 2 BPM(ICP=530 psi ICP,max circulating pressure=2567 psi,and FCP=225 psi)while reciprocating drill pipe. 3/18/2016 3/18/2016 0.50 COMPZN RPCOMP OWFF P Conduct 30 minute negative no flow 9,573.0 9,573.0 12:00 12:30 test(NFT)with 2000 psi differential across the'F'packer/PXX plug with W prong combination and the well is static. 3/18/2016 3/18/2016 0.50 COMPZN RPCOMP PRTS P PT the model'F'packer,PXX plug 9,573.0 9,573.0 12:30 13:00 with W prong,and 7"casing to 3000 psi for 15 minutes(good test)with seawater. 3/18/2016 3/18/2016 10.50 COMPZN RPCOMP PULD P POOH laying down DP from 9,573.0 17.0 13:00 23:30 9573'(PU= 160K and SO=85K)to 17'RKB. 3/18/2016 3/19/2016 0.50 COMPZN RPCOMP BHAH P Lay down model'J'hydraulic setting 17.0 0.0 23:30 00:00 tool. 3/19/2016 3/19/2016 0.50 COMPZN RPCOMP RURD P MU wear ring pulling tool,pull the 0.0 0.0 00:00 00:30 wear ring,lay down the wear ring pulling tool,and lay down joint of DP. 3/19/2016 3/19/2016 0.50 COMPZN RPCOMP RURD P RU Weatherford power tubing tongs 0.0 0.0 00:30 01:00 and 3-1/2"tubing elevators. Page 8/11 Report Printed: 4/5/2016 • 'All,;-4 " - 4= Operations Summary (with Timelog Depths) rr' ,, 3H-22 ConocoPhiIlips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time '.. Dur(hr) Phase Op Code Activity Code'.. Time P-T-X '.. Operation (ftK6) End Depth(ftK8).. 3/19/2016 3/19/2016 0.25 COMPZN RPCOMP SFTY P PJSM with Weatherford,Baker,and 0.0 0.0 01:00 01:15 rig crew for running 3-1/2"tubing completion. 3/19/2016 3/19/2016 4.50 COMPZN RPCOMP PUTB P PU seal assembly,MU 1 joint of 0.0 3,880.0 01:15 05:45 tubing,and MU GLM assembly. RIH with upper completion on 3-1/2"tubing installing GLM's per tally to 3880'RKB (PU=55K and SO=49K). 3/19/2016 3/19/2016 0.25 COMPZN RPCOMP SFTY P Well control drill-kick while tripping. 3,880.0 3,880.0 05:45 06:00 Well shut in time=41 seconds and CRT=61 seconds. AAR with rig crew. 3/19/2016 3/19/2016 5.50 COMPZN RPCOMP PUTB P Continue RIH with upper completion 3,880.0 9,570.0 06:00 11:30 on 3-1/2"tubing installing GLM's per tally from 3880'to 9570'RKB(PU= 98K and SO=65K). 3/19/2016 3/19/2016 0.50 COMPZN RPCOMP RURD P RU circulating equipment on joint 9,570.0 9,575.0 11:30 12:00 #300 and RIH 5'. 3/19/2016 3/19/2016 0.25 COMPZN RPCOMP CIRC P Circulate 81 bbl at 5 BPM=500 psi. 9,575.0 9,575.0 12:00 12:15 Slow the pump rate to 1 BPM=40 psi. 3/19/2016 3/19/2016 0.25 COMPZN RPCOMP HOSO P Locate the top of the'F'packer at 9,575.0 9,578.0 12:15 12:30 9578'RKB,continue to SO to locate out at 9591'RKB with 10K down,and mark the pipe for space out. PU to the mule shoe is just above the packer. 3/19/2016 3/19/2016 0.50 COMPZN RPCOMP CIRC P Reverse circulate 173.5 bbls at 5 BPM 9,578.0 9,578.0 12:30 13:00 =880 psi. 3/19/2016 3/19/2016 1.00 COMPZN RPCOMP CIRC T Attempt to lay down joint#300 with 9,578.0 9,578.0 13:00 14:00 circulating equipment but the hole is out of balance. MU joint#300 with circulating equipment and reverse circulate 176 bbls at 5 BPM=940 psi. 3/19/2016 3/19/2016 0.75 COMPZN RPCOMP HOSO P RD circulating equipment. Lay down 9,578.0 9,550.0 14:00 14:45 joint#'s 300,299,and 298. MU space out pups 10.36'and 10.33'. MU joint #298 3/19/2016 3/19/2016 0.75 COMPZN RPCOMP THGR P MU the tubing hanger, MU landing 9,550.0 9,565.0 14:45 15:30 joint with circulating equipment,and RIH 15'. 3/19/2016 3/19/2016 2.00 COMPZN RPCOMP CRIH P Line up to reverse circulate. Reverse 9,565.0 9,565.0 15:30 17:30 circulate 320 bbls of corrosion inhibited seawater at 3 BPM=420 psi and clear the surface lines with 6 bbls of seawater. 3/19/2016 3/19/2016 0.50 COMPZN RPCOMP THGR P Drain the BOP stack,land the tubing 9,565.0 9,587.0 17:30 18:00 hanger,and RILDS. 3/19/2016 3/19/2016 2.00 COMPZN RPCOMP PRTS P PJSM. PT the tubing to 3500 psi for 9,587.0 0.0 18:00 20:00 30 minutes(good test),bleed the tubing pressure to 2000 psi,and PT the IA to 3000 psi for 30 minutes (good test). Bleed the IA to 0 psi, bleed the tubing to 0 psi,and ramp up the pressure on the IA to shear the SOV(SOV sheared at 2700 psi). Pump 1 bbl each way to confirm a good flow path through sheared SOV. Page 9/11 Report Printed: 4/5/2016 • S •,Ak Operations Summary (with Timelog Depths) 024 3H-22 ConocoPhitilps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start..Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End,Depth(ftKB)'.. 3/19/2016 3/19/2016 0.25 COMPZN RPCOMP RURD P RD circulating equipment and lay 0.0 0.0 20:00 20:15 down the landing joint. 3/19/2016 3/19/2016 0.25 COMPZN WHDBOP MPSP P Install 3"'HP'BPV. 0.0 0.0 20:15 20:30 3/19/2016 3/19/2016 0.50 COMPZN WHDBOP WWWH P Change elevators to 3-1/2"DP. PU a 0.0 0.0 20:30 21:00 joint of DP,MU stack jetting tool,jet the stack,lay down stack jetting tool, lay down joint of DP,and blow down the TD. 3/19/2016 3/20/2016 3.00 COMPZN WHDBOP SVRG P Cleanout under the rotary table and 0.0 0.0 21:00 00:00 steam tables with a super sucker. 3/20/2016 3/20/2016 0.50 COMPZN WHDBOP SVRG P Blow down all surface lines. 0.0 0.0 00:00 00:30 3/20/2016 3/20/2016 2.50 COMPZN WHDBOP SVRG P Perform CPAI Between Wells 0.0 0.0 00:30 03:00 Maintenance(BWM)on the BOP stack: Break bolts on the lower ram doors,open doors,and function ram pistons to the closed position. Remove the 2-7/8"x 5"VBRs. Inspect rams,ram cavities,sealing surfaces, and door seals. Install 5-1/2"solid body rams in the lower ram cavities. Close the lower ram doors and tighten the bolts(photos taken of all components and of stack cavities). 3/20/2016 3/20/2016 2.50 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Break 0.0 0.0 03:00 05:30 bolts on blind ram doors,open doors, and function ram piston to the closed position. Inspect ram cavities,sealing surfaces,and door seals. Inspect blind upper seal and front packer assembly.Change out the top seal on the blind rams(photos taken of all components and of stack cavities). 3/20/2016 3/20/2016 1.50 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Break 0.0 0.0 05:30 07:00 bolts on the upper ram doors,open doors,and function ram pistons to the closed position. Inspect rams,ram cavities,sealing surfaces,and door seals(photos taken of all components and of stack cavities). 3/20/2016 3/20/2016 3.00 COMPZN WHDBOP SVRG T Close the doors on the blind rams. 0.0 0.0 07:00 10:00 Door bolt on the off drill side(ODS) cross threaded. Open the door,clean the threads with a tap,close the door and tighten the bolts. Close the upper rams doors. Change out the middle door hinge on the upper pipe rams ODS door. Close the door and tighten the bolts. 3/20/2016 3/20/2016 1.00 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Pull 0.0 0.0 10:00 11:00 the riser. Install 3-1/2"joint of DP and function annular checking for excessive wear and overall condition (photos taken of annular). 3/20/2016 3/20/2016 1.50 COMPZN WHDBOP NUND P Remove lower Koomey line off the 0.0 0.0 11:00 12:30 annular,remove turn buckles,and attach the lift ring. ND the BOP stack and ND the DSA. Set the BOP stack on the stump and secure. Page 10/11 Report Printed: 4/5/2016 • • r; Operations Summary (with Timelog Depths) otste ` 3H-22 ConacoPhat bps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code :Activity Code Time P-T-X Operation MKS) End Depth(ftKB). 3/20/2016 3/20/2016 2.50 COMPZN WHDBOP NUND P Remove the DSA and clean around 0.0 0.0 12:30 15:00 the tubing hanger. Install the blanking plug into the BPV and NU the tubing head adapter. 3/20/2016 3/20/2016 0.50 COMPZN WHDBOP PRTS P PT the tubing hanger void to 250/5000 0.0 0.0 15:00 15:30 psi(good test). 3/20/2016 3/20/2016 1.00 COMPZN WHDBOP NUND P NU the 3-1/8"tree. Change the 0.0 0.0 15:30 16:30 orientation of the swab valve 180°and torque the bolts. 3/20/2016 3/20/2016 1.00 COMPZN WHDBOP PRTS P Fill the tree with diesel and RU testing 0.0 0.0 16:30 17:30 equipment. PT the tree to 250/5000 psi for 5 minutes each(good test). 3/20/2016 3/20/2016 0.50 COMPZN WHDBOP MPSP P Pull blanking plug and 3"'HP'BPV 0.0 0.0 17:30 18:00 with dry rod. 3/20/2016 3/20/2016 1.00 COMPZN WHDBOP FRZP P RU circulating lines to freeze protect 0.0 0.0 18:00 19:00 the well and RU Little Red Services (LRS). 3/20/2016 3/20/2016 1.25 COMPZN WHDBOP FRZP P PT LRS lines and circulating lines to 0.0 0.0 19:00 20:15 2500 psi(good test). With LRS pump 85 bbls of diesel down the IA taking returns out the tubing to the cutting box at 2.5 BPM(ICP=900 psi and FCP=1150 psi)and suck back 2.5 bbls. 3/20/2016 3/20/2016 1.00 COMPZN WHDBOP FRZP P Place the tubing and IA in 0.0 0.0 20:15 21:15 communication allowing the well to u- tube and equalize. Blow down circulating lines. SimOps: RD LRS. 3/20/2016 3/20/2016 0.25 COMPZN WHDBOP MPSP P Install 3"'H'BPV with dry rod. 0.0 0.0 21:15 21:30 Final well pressures: Tubing=0 psi, IA=0 psi,and OA=220 psi. 3/20/2016 3/20/2016 0.50 DEMOB MOVE RURD P RD all cellar lines and RD annulus 0.0 0.0 21:30 22:00 valve. Install gauges on the tree, secure the well,and secure the cellar. Release the rig at 22:00 hours on 3-20 -16 Page 11/11 Report Printed: 4/5/2016 .'� KUP � 3H-22 ConocoPhillips Well Attrib Max Ang D TD Alaska Inc '^y` Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) • Ca,,,, FlNbps 501032009700 KUPARUK RIVER UNIT INJ 60.15 5,100.00 10,234.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 381-22,4/7/20167.04:51 AM SSSV: None Last WO: 3/20/2016 42.01 2/28/1988 Vertical schematic.(.:Wal) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:DP 9.971.0 3/15/2016 • 2/26/2016 Hanger;35.0 1.I 11-f': TUBINGRAN FLAPPER CHECKER • SSSV asing rings 1 �' .• DU •. .. . •01.062 1. •• -.1 Set r 1 - .-. . 1 - 1 .1 .. • •. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 4,347.6 3,126.8 36.00 J-55 BTC , ' �� , Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread al PRODUCTION 7 6.276 35.0 10,052.2 6,267.8 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. (TVD)(...Wt(IbIR) Grade Top Connection Tubing RWO 2016 1 3 1/21 2.9921 35.01 9,586.81 Set Depth(5,984.61 9.301L-80 1EUE 8rd Mod CONDUCTOR,36.0-115.0 Completion Details Nominal ID TTop(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 35.0 35.0 0.09 Hanger McEvoy Gen III Tubing Hanger,MSDP-1-6.5-MS-3,7- 2.950 Mandrel,3,246.3 1/16"x 3-1/2"EUE 8rd Box x Box,3"H BPVG 9,5742 5,976.9 52.65 Locator Locator Sub,GBH-22(bottom of the locator spaced out 2.990 3.83') ii. 11 9,575.3 5,977.6 52.65 Seal Seal Assembly,80-40 3.020 Assembly Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/tn) Grade Top Connection Lower Completion 41/2 3.958 9,578.3 9,736.0 6,075.3 12.60 L-80 STC RWO 2016 SURFACE,3s.04,3476-. Completion Details Nominal ID T Top(ftKB) Top(TVD)(ftKB) Top Incl(3 Item Des Corn (in) 9,578.3 5,979.4 52.65 Packer 587-400 Model'F'Production Packer 4.000 Mandrel,5,596.9 .+a 9,581.6 5,981.4 52.64 SBE (Seal 80-40 Seal Bore Extension(SBE) 4.000 Bore Extension) 9,591.0 5,987.1 52.62 XO Reducing Crossover,4-3/4"Stub Acme Box x 3-1/2"EUE 8rd Pin 2.970 9,639.7 6,016.7 52.57 Nipple- Nipple,HES,2.813"X,SN:C-3562596 2.812 2.813"X Mandrel;7,260.2 ' ' 9,651.6 6,023.9 52.56 Ported Ported Crossover,3-1/2"EUE 8rd Mod Box x 4-1/2"STC 2.992 Crossover Pin 9,653.4 6,025.0 52.56 Ported Ported Wearsox Joint,4-1/2",12.6#,L-80,STC Box x 3.958 Wearsox Mule Shoe Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Mandrel,8,576.8 , �: Top(TVD) Top Incl Top(ftKB) (0613) (3 Des Com Run Date ID(in) 9,626.0 6,008.4 52.58 Junk Catcher 2.78"x 8'Junk Catcher 3/18/2016 2.000 9,636.0 6,014.4 52.57 PXX Plug 2.813"PXX Plug with W Prong 3/18/2016 0.000 with W Prong Perforations&Slots Mandrel;9,517.2 I': 4 Shot Den lop(ND) Btm(TVD) (shots/ Top(ftKB) Btm(11KB) (ftKB) (ftKB) Zone Date ft) Type Com •11 11 6,047.3 6,059.4 1 61 deg ph -- •1 9,736.0 6,063.1 6,075.3 8.0 .1. Locator;9,571.2 �i < 1 1 1: 19 , • degph deg ph Packer,9,578.3- t' ir ' Seal Acsernbty,9,575.3 I. SBE(Seal Bore Extension); ' 9,581 8 Air 4/28/1988 NOTE:Bad spot in 7"CSG 8257'-8281';Max ID=6.45";Tested to 2600psi w/10 ppg Brine. XO Reducing;9,591.0 lir 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 I iii Iii Junk Catcher;9,626 0 ci hig PXX Plug With W Prong;9,636.0 i Nipple-2.813"X;9,639.6 I! I Ported Crossover 9,651.6 Ported Wessex;9,653.4-, APERF;9,690.09,710.0--. APERF;9,716.0-9,736.0-• ~ IPERF;9,754.03,774.0 PRODUCTION;35.616052.2 1�OF Thr Iv7,,v THE STATE Alaska Oil and Gas o f LsKA Cmnservati®n Commission z 333 West Seventh Avenue 1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \TPR: Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Andrew Beat 3 2.016 Sr. Wells Engineer 5044INE � i'�LD 32 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H-22 Permit to Drill Number: 188-011 Sundry Number: 316-059 Dear Mr. Beat: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / /0;_e_44(1 .. Cathy P. oerster Chair DATED this day of February, 2016. RBDMS 0- FFR 1 1 2016 • • RECEIVED STATE OF ALASKA JAN 2 8 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION nri Z// 1, APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing Wr , Change Approved Programs Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CO setup Z. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. ' Exploratory ❑ Development ❑ 188-011 " 3.Address: Stratigraphic ❑ Service a: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20097-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes ❑ No 2 KRU 3H-22 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025523 . Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10234' • 6379' ' 9818' • 6125' • 4323 / none 10001' Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 4306' 9.625" 4346' 3126' Intermediate Production 10016' 7" 10051' 6267' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9690'-9710' . 6047'-6059' 3.5"x 2.875" J-55 9606' 9716'-9736' • 6063'-6075' 9754'-9774' - 6086'-6098' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV: CAMCO TRDP-1A-SSA SAFETY VALVE MD=1789 TVD=1625 • PACKER-CAMCO HRP-1 PACKER MD=9531 TVD=5951 12.Attachments: Proposal Summary ❑ Wellbore schematic O 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: 3/31/2016 OIL ElWINJ Q' WDSPL Ell Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Andrew Beat @ 265-6341 Email Andrew.T.Beat@conocophillips.com Printed Name Andrew Beat 265-6341 Title Sr.Wells Engineer Phone Signature // 2....57 Date VZ-7/Z-0140 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -- \t_.e — 09 Plug Integrity ❑ BOP Test IY17 Mechanical Integrity TestTr/ Location Clearance ❑ Other: BOP f'✓St to "t50O p5i1 (A4P5P is 4323?5 9 ) f}-r,I7vlor✓ pretClh * fr.' ?'5-3 tD ZSC-1 c) `.)515 5,-u. tt C f-✓7f5S d Artc 7--/4 re-Tv/`.-ed a ftti 57-1b ,'l,3,ci' ►'j"cc Is o1" Post Initial Injection MIT Req'd? Yes No ❑ Spacing Exception Required? Yes ❑ No ® Subsequent Form Required: /0 -- 404 RBDMS o--- F 1 1 2016 APPROVED BY Approved by: RialphICA COMMIS IONER 1 THE COMMISSION/� Date:2...../0_1c„, ti'T Z/S//6 ••f CY) j'2c(/IT Submit Formand Form 10-403 Revised 11/2015 for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips RECEIVED Alaska JAN 2 8 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC January 27,2015 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc.hereby submits an Application for Sundry Approval to work over Kuparuk Injector 3H-22(PTD# 188-011). 3H-22 was originally drilled and completed in 1988 as an 'A' sand injector in Kuparuk.This well has been identified as a candidate for our 2016 CTD program. 1 The proposed workover scope for 3H-22 will cover pulling the existing 2-7/8"completion, cleaning out fill down to liner setting depth, and installing a new 3-1/2"completion with a 5-1/2"liner set below the production packer. If you have any questions or require any further information,please contact me at 265-6341. Sincerely A 411111, Andrew Beat Wells Engineer CPAI Drilling and Wells • • • 3H-22 Rig Workover CTD Setup—3-1/2"Tbg w/5-1/2"Liner (PTD#: 188-011) Current Status: Shut-in for pressure management. Scope of Work: Pull the existing 2-7/8"tubing,cleanout fill,and install new 3-1/2"completion with a 5-1/2" liner. General Well info: Well Type: Injector MPSP: 4,321 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 4,928 psi/6,073' TVD(15.6 ppg EMW)measured on 10/27/2015 Wellhead type/pressure rating: McEvoy Gen III,7"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: 4 Yr MIT-IA Passed- 12/2/2013 Earliest Estimated Start Date: March 13,2016 Production Engineer: Marina Krysinski Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Pre-Rig Work 1. Inspect pad and work area for hazards. Complete the PJSM. 2. Set a plug in the nipple at 9,571' RKB.Perform a DDT to confirm isolation. 3. Pull dummy valve from GLM#4. 4. Set BPV and test from below to confirm isolation. 5. FT LDS. Workover Procedure 1. MIRU. 2. Verify well is static. 3. ND tree,NU BOPE&test to 250/4,500 psi(rams)and 250/2,500 psi(annular). a. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe rams will be tested upon pulling the completion. 4. Pull BPV,screw in landing joint,BOLDS's,unland tubing hanger. 5. POOH laying down 2-7/8"tubing. 6. MU and RIH with 2-7/8"spear to just above PBR. Circulate KWF around.Ensure well is balanced. a. While RIH, set storm packer and N/D BOPE and tubing head.Replace PO.N/U tubing head and ✓ BOPE and shell test stack to 250/4,500 psi. 7. Spear the PBR and jar the packer free.POOH with packer. 8. MU cleanout assembly and cleanout to 20'past liner setting depth.POOH with DP. 9. RIH with 5-1/2"liner(plug pre-installed in liner)and liner top packer to setting depth. Set packer and release running tools. 10. Displace WBM to seawater and POOH with DP. 11. RIH with new 3-1/2"tubing and sting into PBR until fully located. Space out and MU hanger. 12. Pump corrosion inhibited fluid around and re-engage seals. 13. Land the tubing hanger,RILDS. 14. PT the tubing,bleed tubing,PT the IA,and record.Bleed the IA to zero,then tubing. Ramp up the IA pressure quickly to shear the SOV. 15. Pull the landing joint,install BPV.Pressure test the BPV from below. 16. ND BOPE. 17. NU tree.Pull BPV and install tree test plug.Test tree and pull test plug. 1 • • 3H-22 Rig Workover CTD Setup—3-1/2"Tbg w/5-1/2"Liner (PTD#: 188-011) 18. Freeze protect well with diesel. Set BPV. 19. RDMO. Post-Rig Work 1. Pull BPV. 2. RU Slickline to pull SOV and run gas lift design. 3. Pull plug from liner. 4. Reset well house(s)and flowlines of adjacent wells. 5. Turn well over to operations. 2 • _N KUP INJ 3H-22 v- , ConoclPhiIllps A 1 Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) pR 501032009700 KUPARUK RIVER UNIT INJ 60.15 5,100.00 10,234.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3H-22,10/28/2015 4:36:30 PM SSSV:TRDP Last WO: 42.01 2/28/1968 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,818.0 10/26/2015 Rev Reason:TAG pproven 10/28/2015 HANGER;35.0 ' ';1J1 Casing Strings Ili Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(WD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED , Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 4,347.6 3,126.8 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 10,052.2 6,267.8 26.00 J-55 BTC Ate .i.Tubing Strings CONDUCTOR;36.0-115.0 a Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 27/8 2.441 35.0 9,606.0 5,996.2 6.50 J-55 EUE8rdABMOD Completion Details Nominal ID I Top(ftKB) Top(TVD)(ftKB) Tap Incl 7) Item Des Com (in) W.n 35.0 35.0 0.09 HANGER MCEVOY TUBING HANGER w/3.5"XO PUP 3.500 SAFETY VLV;1,789.1 f'�! 1,789.1 1,624.5 45.53 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.313 9,513.4 5,940.1 52.78'PBR CAMCO OEJ PBR 2.312 9,531.0 5,950.7 52.74 PACKER CAMCO HRP-1 PACKER 2.347 GAS LIFT;3,549 5 9,571.2 5,975.1 52.66 NIPPLE CAMCO D NIPPLE NO GO 2.250 9,605.3 5,995.8 52.60 SOS CAMCO SHEAR OUT SUB 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ft613) (ftKB) 7) Des Com Run Date ID(in) 10,001.0 6,236.5' 52.32 FISH FISH Flapper seat from surface line check valve- 12/17/1999 possibly downhole-lost 12/17/1999 Perforations&Slots Shot SURFACE:35.0.4,347 6-A Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type _ Com 9,690.0 9,710.0 6,047.3 6,059.4'A-3,3H-22 8/11/1988 8.0 APERF 2 1/8 EnerJet;60 deg ph GAS LIFT',6,828 9 9,716.0 9,736.0 6,063.1 6,075.3 A-2,3H-22 8/11/1988 8.0'APERF '2 1/8 EnerJet;60 deg ph 9,754.0 9,774.0' 6,086.2 6,098.4'A-1,3H-22 4/25/1988 4.0 (PERF SOS 4.5"Ultra P;120 GAS LIFT;8,812.5 deg ph Mandrel Inserts St ati Top(WD) Valve Latch Port Size TRO Run GAS LIFT;9.468.5 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,549.5 2,679.7 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 4/29/1988 2 6,828.9 4,461.9 McMurray 'FMHO 1 GAS LIFT DMY BK 0.000 0.0 4/29/1988 3 8,812.5 5,528.5 McMurray FMHO 1 GAS LIFT DMY BK 0.000 0.0 4/29/1988 4 9,468.5 5,912.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/14/1988 Not PBR; &Safety PBR;9,513.4 _ End Date Annotation 4/28/1988 NOTE:Bad spot in T'CSG 825T-8281';Max ID=6.45";Tested to 2600psi w/10 ppg Brine. PACKER;9,531.0 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;9,571.2 SOS;9,605.3 . f APERF;9,690.0-9,710.0 APERF;9,716.0-9,736.0-.. (PERF;9,754.0-9,774.0-- FISH;10,001.0 PRODUCTION;35.0-10,052.2 • • 3H-22 Proposed RWO Schematic Modified by ATB 1/27/16 / Baker Orbit Valve at—3500'MD (2.835"minimum ID) 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 16"62.5#H-40 3-1/2"Camco gas lift mandrels @ TBD shoe @115'MD Baker PBR @—9,511'MD Baker FHL packer @—9,531'MD 3-1/2"HES landing nipple—9,581' MD 9-5/8"36#J-55 shoe (2.812"min ID) @ 4348'MD 5-1/2"Big Tail Pipe configuration (see details) 9651'-9735'MD CRITICAL DEPTH!! /5"3 I 2 Jts 5-1/2", 14#,H-40/J-55,Range 3(assume jnts 42'ea) *Depth correlated to log 6"OD special clearance connections p� *Wearsox 6"OD,every 2.5-3.0'along the pipe 9715'proposed *Bevel/shoe on bottom TOWS depth o o� ` *All connections Baker-Locked — `l(,`Lo A-sand perfs A3:9690'-9710' A2:9716'-9736' Al:9754'-9774' • C f o 5 c �` w bv; �5/ k_ e e ll/2 I.7 e/ 3 ; f oa ,„). arc ici12.0t ti 51 r"),- fre vv+ 7"26#J-55 shoe -Z y..2. @ 10,052'MD J 5-e' 5 w► w),1-e9.-- 1 t "'IA 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. Organization (done) Well History File Identifier Color items: DIGITAL DATA Diskettes, No. OVERSIZED (Scannable) Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: TOTAL PAGES: NOTES: [] Other, No/Type Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ SCANNED BY: BEVERLY BREN VINCENT SHERYL ~ LOWELL RESCANNEDBY~VERLY~EN VINCENT SHERYL MARIA LOWELL General Notes or Comments about this file: Quality Checked (done) Rev1 NOTScanned,wpd • Conoc P ' ' o hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: , ~~; }t,~~'~~: . f ~ ~_' ,~i`µ~ ~ ~ ~~~~~ 1 ~ ~ ~- 3,~~~.' Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~` and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, v~G~~ ( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 ~~ ~~ ~~ fl ~., ~..,, ell Name PI # TD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date ,...~ Corrosion inhibitor ~ Corrosion inhibitoN sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" Na 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'S" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-10B 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" - n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8!9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF Na 18" Na 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'S" 4.50 20" 7/30/2009 9.35 8/8l2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 • MEMORANDUM To: Jim Regg ~~~ ~ ~~27~~ ~ l P.I. Supervisor FROM: Chuck Scheve Petroleum InsPector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHiLLIPS ALASKA INC 3H-22 KUPARiJK RIV LJNIT 3H-22 5rc: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~3~~--"" Comm Well Name: KUPARUK RN iJNIT 3H-22 Insp Num: mitCS090608151622 Rel Insp Num: API Well Number: 50-103-20097-00-00 Permit Number: 1sg-oii-o ~ Inspector Name: Chuck Scheve Inspection Date: 6/7/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~] 3H'ZZ Type Inj. ~ W 7'~ 5950 jA ( 450 ~ 2080 ~ 2000 1990 P.T.D issoiio TypeTest SPT Test psi 1__ 1500 QA 100 300 300 300 - Interval 4YRTST P~` P ~ Tubing 2500 2500 2500 2500 NOtes: Pretest pressures observed and found stable. ~ T~a i:~ i ` "~~ ,~ : ~~' k; Wednesday, June 10, 2009 Page 1 of 1 MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg \~. I','.... ,', I I c¡ c, (; ,?(:\ LG P.I. Supervisor '(f . t· I. DATE: Wednesday, June 14, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-22 KUPARUK RIV UNIT 3H-22 Src: Inspector \éb;O\\ Reviewed By: P.I. Suprv ,:Jt3fL- Comm FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3H-22 Insp Num: mitJCr060613125306 Rei Insp N urn API Well Number 50-103-20097-00-00 Permit Number: 188-011-0 Inspector Name: John Crisp Inspection Date: 6/10/2006 Packer Depth Pretest Initial 15 Min. Well --I 3H-22 Type Inj. ! w -I TVD - : 595ii-- IA I - 950--r162o-----l5s·0 P.T. I_ 1880110 TypeTest I SPT 1 Test psi i- ~oo -. i OA 1 130 .-1 230 I 230 Interval__4YR~~___ P/F p _______Tubin~1_~2~0 I ~!~_L.____~760 Notes 2.6 bbl's pumped for test. 30 Min. 45 Min. 60 Min. 1:37 i --~- f .~-= 2760 I -----i-·--..--- ----....-.1 ----i...-____ SCJ\NNED JUN 2 &7 2006 Wednesday, June 14,2006 Page I of I . Conoc6Phillips . Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 May 18, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3H-22 (APD # 188-011) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 3H-22. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, (, J;!, I1P~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 188-011/ 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20097 -00 7. KB Elevation (ft): 9. Well Name and Number: RKB 76' 3H-22 8. Property Designation: 10. Field/Pool(s): ADL 25523:ALK 2559 Kuparuk River Field / Kuparuk Oil Pool , 11. Present Well Condition Summary: Total Depth measured 10234' I feet true vertical 6379' feet Plugs (measured) Effective Depth measured 9850' feet Junk (measured) 10001' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 115' 115' SURF. CASING 4272' 9-5/8" 4348' 3127' PROD. CASING 9976' 7" 10052' 6268' Perforation depth: Measured depth: 9690'-9710',9716'-9736',9754'-9774' true vertical depth: 6047'-6059',6063'-6075',6086'-6098' RBDMS BFl MAY 3 0 70nH Tubing (size, grade, and measured depth) 3.5" /2-7/8", J-55, 36' / 9606' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1' pkr= 9531' Cameo TRDP-1A-SSA' SSSV= 1789' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: refer to summary attached 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation na na 340 Subsequent to operation na na 340 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ0. WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Lead Signature j L J/! Phone Date 5/7-2/6(. ~ ,., " Prenared bv Shamn AI/sun-Drake 263-4612 - " Form 10-404 Revised 04/2004 LJR1G\NA[ h,5{'N .~þ >. z.~.DC. S~i:;"/~ð DATE 04/21/06 . 3H-22 Well Events Summary . Summary Pumped 4 stage breakdown - 720 bbls 70-80 deg seawater at max rate of 6.3 bpm @ 4000psi. " ConocoPhillips AlaR, Inc.. . KRU 3-1-22 3H-22 API: 501032009700 Well Tvpe: INJ Anale!iiJ TS: 53 dea !iiJ 9678 SSSV Tvpe: TRDP Orig Completion: 2/28/1988 Angle @ TD: 52 dea @ 10234 Annular Fluid: Last W/O: Rev Reason: TAG FILL, est. 76' SSSV II Rathole below BTM (1789-1790, PERF 00:2.875) Reference Loa: Ref Log Date: Last Update: 4/9/2006 Last Tag: 9850 TD: 10234 ftKB Last T aa Date: 4/7/2006 Max Hole Anale: 60 deg @ 5100 Casino Strina - ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 Gas Lift M SURF. CASING 9,625 0 4348 3127 36.00 J-55 I ndrellDum m y PROD. CASING 7.000 0 10052 6268 26.00 J-55 Valve 1 (3550-3551 , Tubina Strina - TUBING 00:5.313) Size I Top I Bottom TVD I Wt I Grade I Thread 3.500 I 0 I 36 36 I 9.30 I J-55 I 8RD MOD 2.875 I 36 I 9606 5996 I 6.50 I J-55 I 8RD AB MOD Perforations Summary Gas Lift Interval TVD Zone Status Ft SPF Date Type Comment mdrel/Oummy 9690 - 9710 6047 - 6059 A-3 20 8 8/11/1988 APERF 2 1/8 EnerJet; 60 dea ah Valve 2 9716 - 9736 6063 - 6075 A-2 20 8 8/11/1988 APERF 2 1/8 EnerJet; 60 dea ph (6829-6830, 00:5.313) 9754 - 9774 6086 - 6098 A-1 20 4 4/25/1988 IPERF SOS 4.5" Ultra P; 120 dea ph Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt Gas Lift 1 3550 2680 McMurrav FMHO DMY 1.0 BK 0.000 0 4/27/1988 I ndrel/Oummy 2 6829 4462 McMurray FMHO DMY 1.0 BK 0.000 0 4/27/1988 Valve 3 3 8812 5528 McMurray FMHO DMY 1.0 BK 0.000 0 4/27/1988 (8812-6813, 4 9468 5913 Camco MMG DMY 1.5 RK 0.000 0 5/14/1988 00:5.313) Other (,Iuos, eauip. etc.) - JEWELRY Depth TVD Type Description ID 1789 1624 5SSV Cameo 'TRDP-1A-SSA' 2.313 Gas Lift .. 9513 5940 PBR Cameo 'OEJ' 2.312 IndrellDummy 9531 5951 PKR Camco 'HRP-1' 2,347 Valve 4 9571 5975 NIP Camco 'D' Nipple NO GO 2.250 (9468-9469, 9605 5996 50S Camco 2.441 00:5.750) 9606 5996 TTL 2.441 Fish - FISH Depth I Description I Comment 10001 ¡FISH I Flapper seat from surface line check valve - possibly downhole - lost PBR L 12/17/1999 (9513-9514, General Notes 00:2.875) Date I Note 4/28/1988 I NOTE on HandOver Form: Bad spot in 7" CSG from 8257'-8281'; Max ID-6.45"; Tested to 2600 Dsi w/10 000 Brine. PKR (9531-9532, 00:6.151) NIP (9571-9572, 00:2.875) TUBING (36-9606, 00:2.875, 10:2.441 ) SOS (9605-9606, 002.875) Perf - - (9690-9710) - - - - - - -- = Perf - (9716-9736) - - - - - - Perf = = (9754-9774) - - - - - - - - ') ) Mike Mooney Wells Group Team Leader Drilling & Wells conocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 22, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3H-22 (APD.#1.88~011) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 3H-22. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M., N/~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells NOV ~ 2tJt14 MM/skad SCANNED NO\! 2 9 2004 "-'-:: -:-- ,. :,,":':1.'-,;~...,..~ ,- OR\G\NAL ) ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION NOV2 2004 REPORT OF SUNDRY WELL OPERATIO~§",<.T' ,~. Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0"< . Oth~r::,;:. .:Q Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 188-011 1 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 50-103-20097-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 76' 3H-22 1. Operations Performed: 8. Property Designation: ADL 25523, ALK 2559 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURF. CASING PROD. CASING Perforation depth: measured 10234' feet true vertical 6379' feet measured 9856' feet true vertical 6148' feet Length Size MD 115' 16" 115' 4272' 9-5/8" 4348' 9976' 7" 10052' Plugs (measured) Junk (measured) TVD Burst Collapse 115' 3127' 6268' Measured depth: 9690'-9710',9716'-9736',9754'-9774' true vertical depth: 6047'-6059', 6063'-6075',6086'-6098' RBDMS BFL NOV 2 9 2004 Tubing (size, grade, and measured depth) 3.5" 1 2-7/8", J-55, 36' 1 9606' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1' pkr= 9531' Cameo'TRDP-1A-SSA' SSSV= 1789' 12. Stimulation or cement squeeze summary: 9690'-9710',9716'-9736',9754'-9774' Intervals treated (measured) 728 bbls of slick seawater 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl n/a 350 525 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: onO GasO WAG 0 GINJO WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Oil-Bbl n/a CasinQ Pressure TubinQ Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Contact Printed Name Signature WDSPLO Mike Mooney @ 263-4574 Mike Mooney j/¡, JI/~ Title Phone. Kuparuk Wells Team Leader 1/ Date 'f¡ Z Z/ð t:¡- PreDared bv Sharon Al/suD-Drake 263-4612 UK\G',NAL Submit Original Only Form 10-404 Revised 04/2004 ) PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY FISH (1-2, J I 3H-22 00:3.500) ,,'. API: 501032009700 SSSV Type: Cameo < ~ 'TRDP-1 A-SSA' Annular Fluid: SSSV (1789-1790, 00:2.875) Gas Lift Mandrel/Dummy Valve 1 (3550-3551 , 00:5.313) Gas Lift Mandrel/Dummy Valve 2 (6829-6830, 00:5.313) Gas Lift Mandrel/Dummy Valve 3 (8812-8813, 00:5.313) Gas Lift Mandrel/Dummy Valve 4 (9468-9469, 00:5.750) PBR (9513-9514, OD:2.875) PKR (9531-9532, OD:6.151) NIP (9571-9572, 00:2.875) TUBING (36-9606, OD:2.875, J 10:2.441 ) SOS (9605-9606, OD:2.875) Perf (9690-9710) Perf (9716-9736) Perf (9754-9774) Gas Lift MandrelsNalves . St MD TVD Man Man Mfr Type 1 3550 2680ll1eMurra' FMHO 2 6829 4462 lI1eMurra, FMHO 3 8812 5528l11cMurra, FMHO 4 9468 5913 Cameo' MMG Other (plugs, equip., etc.) - JEWELRY ¡ Depth TVD Type 1789 1624 SSSV 9513 5940 PBR 9531 5951 PKR 9571 5975 NIP 9605 5996 SOS 9606 5996 TTL Fish...FISH Depth 1 Reference Log: Last Tag: 9856 Last Tag 8/17/00 Date: Casing Strings - All Description Size I CONDUCTOR 16.000 SURF. CASING 9.625 PROD. CASING 7.000 Tubing Strings - All I' Description Size TUBING 3.500 TUBING 2.875 i Perforations Summary Interval TVD 9690 - 9710 6047 - 6059 9716 - 9736 6063 - 6075 9754 - 9774 6086 - 6098 u LJ KRU) 3H-22 Well Type: INJ Orig Compltn: 2/28/88 Last W /0: Angle @ TS: 53 deg @ 9678 Angle @ TD: 52 deg @ 10234 Ref Log Date: Rev Reason: Update Last Tag; by JWP Last Update: 11/8/00 TD: 10234 ftKB Max Hole 60 deg @ 5100 Angle: Top Bottom TVD Wt Grade Thread 0 115 115 62.50 H-40 0 4348 3127 36.00 J-55 0 10052 6268 26.00 J-55 Top Bottom TVD Wt Grade Thread 0 36 36 9.30 J-55 8RO MOD 36 9606 5996 6.50 J-55 8RD AB MOD Zone Status Ft SPF Date Type Comment A-3 20 8 8/11/88 APERF 2 1/8 EnerJet; 60 deg ph A-2 20 8 8/11/88 APERF 21/8 EnerJet; 60 deg ph A-1 20 4 4/25/88 IPERF SOS 4.5" Ultra P; 120 deg ph V Mfr V Type VOD Latch Port TRO DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 OMY 1.0 BK 0.000 0 OMY 1,5 RK 0.000 0 Description Date Run 4/27/88 4/27/88 4/27/88 5/14/88 Vlv Cmnt ID 2.313 2.312 2.347 2.250 2.441 2.441 Cameo 'TROP-1 A-SSA' Cameo 'OEJ' Cameo 'HRP-1' Cameo '0' Nipple NO GO Cameo Description FISH Comment Flapper seat from surface line check valve - possibly downhole. 'General Notes Date Note 4/28/88 NOTE on HandOver Form: Bad spot in 7" CSG from 8257'-8281'; Max ID=6.45"; Tested to 2600 psi wi 1 0 ppg Brine. . ) 3H-22 Well Events Summary ) Date Summary 11/03/04 POOR BOY HPBD COMPLETED PUMPED 728 BBLS OF 55 DEGREE SLICK SEAWATER. MAX WHTP 4000 PSI AND MAX RATE OF 7 BPM. RETURNED WELL TO SW INJECTION POST BREAKDOWN. [HPBD] MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor (~\ Chair THRU: Tom Maunder P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector DATE: June 27, 2002 SUBJECT: Mechanical Integrity Tests PAl 3H multiple KP, U Kuparuk River Field NON- CONFIDENTIAL WellI 3H-15 P.T.D. I1871030 Notes: WellI 3H-17 ' P.T.D.I 1870990 Notes: ' WellI 3H-18 'P.T.D.I 1880090 Notes: , WellI 3H-22 P.T.D.! 188O11O Notes: WellI 3H-24 p.T.D.I 1960150 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. ITypelnj.I G I T'.V.D. i~ I Tubing I 3700 I ~o0 I ~oo I ~00 I lntervall 4' Ty'petestI p I Testpsi[ 1458 ICasi~gI 2275I 2875I 2850I 2850I P/F I 13 I Typelnj.I G I T.V.D. I~ I Tubingl 1450 I 1440 I~""~ I~"~ I lntervall 4' Type testI P I Testpsil 1482 I Casingl 200 I 228°l 227° 1'226° I P/F I 13 I Type,nj.I S I T.V.D. I~ I Tubingl ~,00 I~"00 1~"30 I~"~ I'"terva'l 4 I Type testI P I Testpsil 1458 I Casingl 1875I 2320! 2320I 23201 P/F I 13 I Typelnj. I S ! T.v.D.I ~ I~u~'". I~°° I ~,,o I ~,,o I'~.~0 I lntervall 4 Typetest!P ITestpsil 1488 lCasingI 1100I 2180I 2150I 21:40I P/FIE Type,nj.I s I ~.v.~. I ~,o I~u~,.,l~oo I~,~o I~,=~ I~,~oi'nterva'l 4' ITypetestI p ,ITestpsil 1485 l Casingj 1100I 2275 J 2260I 2250I PIF '1 13 Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Page 2 of 3 Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) M.I.T.'s performed: _5 Attachments: none Number of Failures: _0 Total Time during tests: 3 hrs. cc: .none MIT report form 5/12/00 L.G. mit(2) kru 3h 6-27-02js.xls 7/16/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 76 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__x Kuparuk Unit 4. Location of well at surface 8. Well number 957' FNL, 282' FWL, Sec. 12, T12N, RSE, UM (asp's 498684, 6000704) 3H-22i At top of productive interval 9. Permit number / approval number 800' FSL, 2364' FWL, Sec. 35, T13N, RSE, UM (asp's 499680, 6007736) 188-011 At effective depth 10. APl number 50-103-20097 At total depth 11. Field / Pool 1241' FSL, 2370' FWL, Sec. 35, T13N, R8E, UM (asp's 499685, 6008178) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 10234 feet Plugs (measured) Tagged Fill (8/17/00) @ 9856' MD. true vertical 6379 feet Effective depth: measured 9856 feet Junk (measured) true vertical 6148 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 250 Sx AS I 115' 115' SURF CASING 4272' 9-5/8" 1500 Sx AS III & 500 Sx 4348' 3127' Class G PROD CASING 9976' 7" 1280 Sx CIG & 175 AS I 10052' 6268' r.. Perforation depth: measured 9690 - 971 0'; 971 6 - 9736'; 9754 - 9774' ' ..... ! i'~'~'~ :~' true vertical 6047 - 6059'; 6063 - 6075'; 6086 - 6098' A/asl~,.,o 0#~ -~,t/'POn! . Tubing (size, grade, and measured depth) 3.5,9.3#, J-55, Tubing @ 36' MD; 2.875" 6.5#, J-55, Tubing @ 9606' MD. Packers & SSS¥ (type & measured depth) Camco 'H RP-I' Packer @ 9531' MD. Camco 'TRDP-1A-SSA' @ 1789' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (soo attached) Treatment description induding volumes used and final pressure 14. Representative Daily Avera,qe Production or Iniection Data OiI-Bbl Gas-MO Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 525 - 2800 Subsequent to operation - 550 - 2800 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service __(Water Inj).__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3H-22i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN TREATMENT 8/17/00: RIH & tagged fill at 9856' MD. 8120/00: MIRU & PT equipment. Pumped a Fullbore High Pressure Breakdown treatment through the open perforation intervals located at: 969O - 9710' MD 9716 - 9736' MD 9754 - 9774' MD Pumped Scour Stage #1: a) 150 bbls Slick Seawater Pad, followed by b) 30 bbls Scour w/0.50 ppa 20/40 mesh proppant, followed by c) 300 bbls Slick Seawater Flush @ 30 bpm, followed by d) Shutdown. Saw some pressure breaks while pumping. ISIP @ 3067. Pumped Scour Stage #2: e) 5 bbls Gelled Diesel w/2 ppg Rock Salt Diverter, followed by f) 30 bbls Scour w/0.50 ppa proppant, followed by g) 250 bbls Slick Seawater Flush, followed by h) Shutdown. ISIP @ 3060. Pumped Scour Stage #3: i) 150 bbls Slick Seawater Pad, followed by j) 50 bbls Scour w/0.75 ppa proppant, followed by k) 275 bbls Slick Seawater Flush @ 30 bpm, followed by I) Shutdown. ISIP @ 3130. Returned the well to water injection & obtained a valid injection rate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown m Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing , Other X Convert well to WI 2. Name of Operator ARCO Alaska, Inc. 3. Address 'P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X W I Location of well at surface 957' FNL, 282' FWL, Sec. At top of productive interval 800' FSL, 2364' FWL, Sec. At effective depth 1031' FSL, 2367' FWL, Sec. At total depth 1241' FSL, 2370' FWL, Sec. 12, T12N, R8E, UM 35, T13N, R8E, UM 35, T13N, R8E, UM 35, T13N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 1 0 2 3 4' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 76 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-~2 9. Permit number/approval number 88-723 10. APl number $o-103-20097 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 6378' feet Cement' 9970'-10234 Effective depth: measured 9 9 70' true vertical 6217' feet Junk (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical Length Size Cemented Measured depth True vertical depth 80' 1 6" 250 Sx AS I I 15' 1 15' 4313' 9 5/8" 1500 SxAS III & 4348' 3127' 500 Sx Class G 10017' 7" 1280 Sx Class "G" 1 0052' 6267' 175 Sx AS I measured Tubing (size, grade, and measured depth) 2 7/8", J-55 set at 9606' Packers and SSSV (type and measured depth) Camco HRP-1 @ 9531', Camco TRDP-1A-SSA @1789' 9690'-9710' 8 SPF 60 degree phasing, 9754'-9774' 4 SPF 90 degree p_hasing 9716'-9736' 8 SPF 60 degree phasing R (~' 6046'-6058', 6053'-6074', 6085'-6097' TVD i',/i,~.,[." t .i!. ? " " ~ ',, :? : :~,, ..... '~,. ~nchorag~ ,, 13. Stimulation or cement squeeze summary Well was converted from oil producer to water injector. Procedure and MIT record are attached. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Productign gr Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 820 1530 0 700 psi 0 0 -1600 920 psi 16. Status of well classification as: Oil _ Gas ,., Suspended 190 psi 195O psi Service Waterl njector_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date ARCO Alasl~a, ~n~=. ~ SuO$idiary of Atlantic Richfield Coral. WELL PBDT CONTRACTOR /?c - i FIELD - DISTRICT- STATE OPERATION AT REPORT TIME REMARKS WELL SERVICE REPOR IDAYS i DATE / /j-/~- [--'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Report oF Factor ~Wind Vel. Chill Visibility °FI miles; knots CAMCO DAILY OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J, HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting TOTAL FIELD ESTIMATE DESCRIPTION Il Signed~. ~' . /..,~occ~J''' ACCUM. TOTAL STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO Revised to reflect added perforations. Classification of Service Well 1. Status of Well OIL ~ GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-11 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20097 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3H-22 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 4. Location of well at surface 957' FNL, 2821 FWL, 5ec.12, T12N, RSE, UN At Top Producing Interval 800' FSL, 23641 FWL, 5ec.35, T13N, RSE, UN At Total Depth 1241I FSL, 2370! FWL, 5ec.35, T13N, RSE, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 76' I ADL 25523 ALK 2559 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 02/17/88 I 02/26/88 I 05/27/88* N/A feet MSL 1 17. Total Depth (MD+TVD) 118. Plug Back Depth(MD+TVD)/19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 10234'MD, 6378'TVDI 9970'MD, 6217'TVpYES ~ NO []I 1789 feet MD I 1600' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 24" 250 sx AS I 9-5/8" 36.0# J-55 26.0# J-55 SETTING DEPTH MD TOP BOTTOM Surf 1151 Surf 4348' Surf 10052' 12-1/4" 8-1/2" 1500 sx AS III & 500 1280 sx Class G & 17! 711 sx Class G sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Perforated w/4 spf, 90° phasing 9754 ' -9774 'MD 6085 ' -6097 'TVD SIZE 2-7/8" DEPTH SET (MD) 9606' PACKER SET (MD) 95;$1 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL(MD) See attached A( tor tracture AMOUNT& KIND OF MATERIAL USED dendum dated-iD/Z//88, data. Perforated w/8 spf, 60° phasing 9690'-9710'MD/6046'-6058'TVD 9716'-9736'MD/6062'-6074'TVD 27. PRODUCTION TEST Date First Production N/A Hours Tested IMethod of Operation (Flowing, gas lift, etc.) GAS-MCF PRODUCTION FOR [OIL-BBL TEST PERIOD I~ OIL-BBL WATER-BBL Date of Test ICHOKESIZE IGAS'OILRATIO OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED GAS-MCF WATER-BBL Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED JAN u ';, ~9~im AJaska Oil & Gas Cons- Commiss[o~-~ ' ~ ~chorage *Note: Drilled RR 2/28/88. Perforated well & tubing run 4/26/88. Fractured well 5/27/88. Added perforations 8/11/88. Form 10-407 Submit in duplicate /, Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC4/81 :DAN I /'Z,~//~ 29. 3O. GEOLOGIC MARKERS FORMATION TESTS NAME I Include interval tested, pressure data, all fluids recovered and gravity, ·l MEAS. DEPTH TRUE VERT, DEPTH GOR, and time of each phase. Top Kuparuk C 9678' 6039' N/A Base Kuparuk C 9678' 6039' Top Kuparuk A 9678' 6039' Base Kuparuk A 9821' i 6126' 31. LIST OF ATTACHMENTS AddendlJm (dated 10/27/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 supplementai records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: if no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Date: November 28, 1988 Transmittal #: 7362 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3 H - 0 3 Kuparuk Fluid Level Report I 1 - 1 1 - 8 8 Casing 3 H- 1 8 Kuparuk Fluid Level Report I 1 - 1 1 - 8 8 Casing 3 A- 0 1 KUparuk Fluid Level Report 1 1 - 2 3 - 8 8 Casing 3 A-01 Kuparuk Fluid Level Report I 1 - 1 8 - 8 8 Casing 30-02 Kuparuk Fluid Level Report I 1 - 1 9 - 8 8 Casing 3 H - 2 2 Kuparuk Fluid Level Report 1 1 - 1 7 - 8 8 Tubing 3 H - 1 2 .Kuparuk Fluid Level Report I I - 1 7- 8 8 Tubing Receipt Acknowledged: DISTRIBUTION: D&M SAPC Chevron Unocal Mobil State of Alaska ADDENDUM WELL: 5/17/88 5/27/88 7/22/88 8/11/88 3H-22 RU GSL equip. Tst ins to 3000 psi. Pmp 15 bbls diesel thru teree. Mx & heat 21 bbls diesel + 5% Musol to 145°F. Pmp 5% Musol/diesel into well @ 1.6 BPM, 2500 psi. Displ Musol/diesel w/59 bbls, 145°F diesel @ 1.6 BPM, 2500 psi. Left i bbl Musol/Diesel in 9-5/8". No drop in puress as Musol entered perfs. SI well, RD GSL. Notified Production. Frac Kuparuk "A" sand perfs 9774'-9754' in six stages per procedure dated May 5, 1988, as follows: Stage 1: Pmp 100 bbls gelled diesel @ 22 BPM, 4717 psi pad Stage 2: 501 bbls gelled diesel SF @ 22 BPM, 4550 psi Stage 3: 52 bbls gelled diesel 16/20, 2 ppg @ 22 BPM, 4750 psi Stage 4: 101 bbls gelled diesel 16/20, 4 ppg @ 20 BPM, 4975 psi Stage 5: 153 bbls gelled diesel 1620, 6 ppg @ 20 BPM, 6100 psi Stage 6: 59 bbls gelled diesel @ 20 - 15 BPM, 6450 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 857 bbls 47,700f'~ 250~ 5200 psi MIRU Arctic Coil tbg. Test to 4000 psi. RIH to 2000'. Begin pumping BJ gelled diesel at ½ bpm at 1500 psi. GTV TP. RIH. CIr ½ bpm @ 1200 psi. Short tripped 3 times from 9955' to 9520'. POOH will displacing gelled diesel with straight diesel. RD Arctic CTU. Well secured. RU Schl. RIH, perf well f/9716'-9736', 9716'-9736' & 9690'-9710'. ~upervi~o~ ARCO Alaska, lnc, Date- October 14, 1988 Transmittal #: 7316 RETURN TO: ~ · ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3 H- 1 2 Sub-Surface Pressure Survey 9- 2 2 - 8 8 PBU 3 H- 1 2 Sub-Surface Pressure Survey 9 - 2 2 - 8 8 PBU 3 H - 1 7 "Sub-Surface Pressure Survey 9 - 2 2 - 8 8 PBU 3 H - 2 2 Bottom-Hole Pressure Survey 8 - 0 7 - 8 8 PBU 2 C- 1 1 Kuparuk Fluid Level Report 1 0- 0 6 - 8 8 Casing 3 H - 1 4 Kuparuk Fluid Level Report 1 0- 0 7 - 8 8 Tubing 3 F- 1 3 Kuparuk Fluid Level Report 1 0- 0 7- 8 8 Casing 3 C - 1 6 Kuparuk Fluid Level Report 1 0- 0 7 - 8 8 Casing 3 K - 0 6 Kuparuk Fluid Level Report I 0 - 1 I - 8 8 Casing Receipt Acknowledged: DISTRIBUTION; D&M "~tate of Alaska Chevron .Unocal Mobil. SAPC -' STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program Pull tubing _ Variance _ Perforate _ 2. Name of Operator 5. Type of Well: Development ...~. ARCO Alaska, Inc. Exploratory _ RKB 76 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit Other X 6. Datum elevation (DF or KB) feet 4. Location of well at surface 957' FNL, 282' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 800' FSL, 2364' FWL, Sec. 35, T13N, R8E, UM At effective depth 1031' FSL, 2367' FWL, Sec.35, T13N, R8E, UM At total depth 1241' FSL, 2370' FWL, Sec. 35, T13N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 1 0234' feet 6 3 7 8' feet 8. Well number 3H-22 9. Permit number 88-11 10. APl number so-103-200~7 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) Cement' 9970'-10234' Effective depth: measured true vertical 9970' feet Junk (measured) 621 7' feet None Casing Length Structural Conductor~ 8 0' Surface 4 31 3' Intermediate Production 1 0 01 7' Liner Perforation depth: measured 9690'-9710' 9716'-9736' true vertical 6046'-6058', Size Cemented 1 6" 250 Sx AS I 9 5/8" 1500 Sx AS III & 500 Sx Class G 7" 1280 Sx Class G 175 Sx AS I 8 SPF 8 SPF Measured depth 115' 4348' 10052' 60 degree phasing,9754'-9774' 60 degree phasing 6053'-6074', 6085'-6097' TVD True vertical depth 115' 3127' 6267' Tubing (size, grade, and measured depth 2 7/8" J-55 set at 9606' Packers and SSSV (type and measured depth) Camco HRP-1 @ 9531', Camco TRDP-1A-SSA @ 1789' 13. Attachments Description summary of proposal Convert well from oil producer to water injector. 14. Estimated date for commencing operation September. 1~)88 16. If proposal was verbally approved Name of approver 4 SPF 90 degree phasing · _ Detailed operation program X.~ {Wellbore schematic attached). 15. Status of well classification as: Oil Gas BOP s~etch Service Water Injector .. Date approved Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test Location clearance__ Subsequent form require Mechanical Integrity Test ..~, . ORIGINAL SIGNE0 BY Approved by the order of the Commissioner I NNNIE C. SMITH Form 10-403 Rev 06/15/88 Commissioner .~pproved Copy Returned llAppr°val NoeL. '- .... ~.~,._~ "' SUBMIT IN TRIPLICATE 3H WATERFLOOD CONVERSIONS GENERAL PROCEDURE , . . . Obtain final 12 hour well test. Check to insure that the sundry notice for converting the well to water injection has been approved by the State (Erin · ext. 6523). SI well to perform surface equipment modifications. Install catalytic heater, rotate check valve and choke, install 2" meter runs, and calibrate instrumentation. Notify the State of the upcoming Mechanical Integrity Test. After 72 hour shut in, contact Engineering (ext. 7525) to record wellhead pressure and shoot tubing fluid level. Conduct MIT. paCker depths and required 7" annular pressures are shown in the table below. Bleed the annulus to 500 psi after completing the test. Send a copy of the WSR and the State's MIT form to S. Twiggs at ATO 1130. WELL 3H-07 3H-09 3H-12 3H-22 DEPTH (TVD) OF PACKER 578 9' 572 7' 587 7' 595 0' REQUIRED ~ PRESSURE FOR MIT (PSI) 2084 2062 2115 21 42 . The targeted injection rates and estimated set pressures are summarized below. After the initial trial, modify the injection set pressure to more closely match the desired rates (+/- 500 BPD is fine). WELL 3H-(~7 3H-09 3H-12 3H-22 DESIRED INITIAL INJECTION RATE (BWPD) 5000 7000 5000 3000 ESTIMATED SET PRESSURE (PSI) 1200 1200 1500 1500 . The above set pressures and rates will apply only until the STP begins winter time operation. Then the injection rates will be increased. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6OO1-A Well 3H-22 Conversion to Water Injection 1. The proposed procedure is attached. . No BOPE will be necessary to convert the well to water injection service. , The static bottomhole pressure will be acquired by taking a WHP/FL prior to the well's conversion. The reservoir pressure is estimated to be 2000 psi based on the producing GOR. 4. No workover fluid will be used. WELL 3H-22 SURFACE LOCATION: 957'FNL, 282'FWL, SEC 12, T12N, R8E, UM TREE: McEVOY 3 1/2" 5000 PSI APl #: 5010320097 DEPTHS: REFERENCED TO 0' RKB REVISION: 9/9/88 TUBING SPOOL ELEV: 35' RKB 16": 62.5# H-40 @115' 9 5/8": 36# J-55 @ 4348' SBR: CAMCO OEJ 2.312" ID @ 9513' PKR: CAMCO HRP-1 2.347" ID @ 9531' NOGO: CAMCO 'D' NIPPLE 2.250" ID @9571' L 1 3.6' PUP JOINT 3 1/2", 9.2 # J-55 SSSV' CAMCO TRDP-1A-SSA @ 1789' McMURRY FMHO GLMs (BK-2 Latches) GLMI' 3550' / 1.0" GLM2: 6828' / 1.0" GLM3: 8812' / 1.0" Camco MMG-II GLM (RK Latch) GLM4: 9468' / 1.5" A3 A2 A1 7": 26# J-55 @ 10052' 2-7/8" 6.5# J-55 ABMOD TUBING TAIL @ 9606' HOLE ANGLE ACROSS KUPARUK=60° 9690' 8 SPF 9710' 9716' 8 SPF 9736' 9754' 4 SPF 9774' FILL @ 9847' (73' RATHOLI) PBTD: 9968' ARCO Alaska, Inc. Date: August 26, 1988 Transmittal #: 7280 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3 H -2 2 Kuparuk Well Pressure Report 6 - 2 9 - 8 8 Amerada 3 H - 2 2 Kuparuk Well Pressure Report 8 - 1 0 - 8 8 Sand 'A' 3 H - 1 8 Bottom-Hole Pressure Survey 8 - 2 2 - 8 8 PBU 3 K - 1 7 Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing 3 B - 1 4 Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing 3 B - 1 3. Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Chevron Mobil Unocal SAPC · , - STATEOF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~,~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL EX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-11 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20097 4. Location of well at surface 9. Unit or Lease Name 957' FNL, 282' FWL, Sec.12, T12N, R8E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 800' FSL, 2364' FWL, Sec.35, T13N, R8E, UM 3H-22 At Total Depth 11. Field and Pool 1241' FSL, 2370' FWL, Sec.35, T13N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet Oi 1 Pool RKB 76'I ADL 25523 ALK 2559 12..Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 02/17/88 02/26/88 05/27/88*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10234'MD, 6378'TVD 9970'MD, 6217'TVD YES~] NO []I 1789 feet MD 1600' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6;~ hZ.b# H-40 Surf 115' 24" 250 sx AS I 9-5/8" 36.0# J-55 Surf 4348' 12-1/4" 1500 sx AS Ill & 500 sx Cla~,s 7" 26.0# J-55 Surf 10052' 8-1/2" 1280 sx Class G & 175 s~ A$ 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) Perforated w/4 spf, 90° phasing 2-7/8" 9606' 9531' 9754 ' -9774 'MD 6085 ' -6097 'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addend, m dated 6/1/88, for fracture da1 a. 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A 1 Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure cALCULATED,4~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA None JUN 2 1988 Alaska .Oil & Gas Cons. Commission Anchorage *Note: Drilled EE 2/28/88, Perforated we]] & tubing run 4/26/88, Fractured we]] 5/27/88, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC4/81 :DANI 29. i 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 9678' 6039' N/A Base Kuparuk C 9678' 6039' Top I<uparuk A 9678' 6039' Base Kuparuk A 9821' 6126' 31. LIST OF ATTACHMENTS Addendum (dated 6/1/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~¢, (~/)'~'~,~--/ ,~7~-~/LU /~ J Title Associ ate Engineer Date ~' ~tD" ~'~, ... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: AttaChed supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 5/17/88 5~27~88 3H-22 RU GSL equip. Tst ins to 3000 psi. Pmp 15 bbls diesel thru teree. Mx & heat 21 bbls diesel + 5% Musol to 145°F. Pmp 5% Musol/diesel into well @ 1.6 BPM, 2500 psi. Displ Musol/diesel w/59 bbls, 145°F diesel @ 1.6 BPM, 2500 psi. Left 1 bbl Musol/Diesel in 9-5/8". No drop in puress as Musol entered perfs. SI well, RD GSL. Notified Production. Frac Kuparuk "A" sand perfs 9774'-9754' in six stages per procedure dated May 5, 1988, as follows: Stage 1: Pmp 100 bbls gelled diesel @ 22 BPM, 4717 psi pad Stage 2: 501 bbls gelled diesel SF @ 22 BPM, 4550 psi Stage 3: 52 bbls gelled diesel 16/20, 2 ppg @ 22 BPM, 4750 psi Stage 4: 101 bbls gelled diesel 16/20, 4 ppg @ 20 BPM, 4975 psi Stage 5: 153 bbls gelled diesel 1620, 6 ppg @ 20 BPM, 6100 psi Stage 6: 59 bbls gelled diesel @ 20 - 15 BPM, 6450 psi Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 857 bbls 47,700# 250# 5200 psi Dril~~g Superv<i~or RECEIVED JUN 2 3 1988 Alaska Oil & Gas Cons. Commission Anchorage ' Dante $ UB.$ URFA CE DIRECTIONAL SURVEY ["~'i UI DANCE I~'i ONTINUOUS I-flooL Company ARCO ALASKA, INC. Well Name 3H-22 (957' FNL,282' FWL,SEC 12,T12N,RBE,UM) Field/Location KUPARUK, NORTH SLOPE, AI~ASKA Job Reference No. 72721 WEST Date ,. 24-APR-88 Computed By:. KRUWELL GCT DIRECTIONAL SURYEY CUSTOMER LISTING ARCO ALASKA, INC, KUPARIJK NORTH SbOPE~ALASKA ~UkVE¥ DATEJ 2~-AP~-88 ENGINEERJ T, WEST METHODS OF COMPUTATION TOOL LOCATION: TANGEN]'IAL- Averaged deviation and azimuth INTERPOLATION~ LINEAR VERTICAL SECTION: HORIZ, LIST, PROOECTED ONTO A TARGET AZIMUTH OF NO~TH 8 LEG 53 SIN EAST ARCO ALASKA, INC. 3H-22 KUPARUK NORTH SbOPE~AEASKA COHPUTATIOh PAnEl 4-MA¥-88 PAGE DATE OF SURYEY: 24-APR-88 KELLY BUSHING gbgVATlOh: 76.00 FT ENGINEER: T, WEST I. FERPOLATED VALUES FOR EVEN I00 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE I~EASURED VERTICAL VERTICAL DEVIATION AZINUTH DEPTH DEPTH L)EPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MXN 0 O0 100 O0 20O O0 ]00 O0 400 O0 5OO O0 600 O0 7OO O0 8O0 O0 900 O0 0.00 '76.00 0 0 N 0 0 E 100.00 24.00 0 15 N 76 30 W 200.00 124.00 0 15 S 69 47 ~ 299,99 223,99 0 30 N 31 3 W 399: 90 323,90 4 22 N 6 27 E 499 26 423.26 8 4 N 8 34 E 597.94 521.94 10 27 N 9 17 E 695,69 619,69 13 57 N 8 33 E 792,08 716.08 16 55 N 10 5 E 886.90 810,90 19 58 N 11 7 E 0.00 0.00 0,00 N 0 O0 '0.06 0 28 0.03 N 0:53 '0.14 0:23 0 O1N 1,02 '0.03 1,54 0:19 N 1,41 3,65 4 60 3'91N 1.38 14.77 1:94 14,91 N O,23 30,91 2 66 30,85 N 2,77 5~.93 3:81 51,61N 6.06 78.52 3,06 77.87 N 110.22 2,51 1U9,04 N 1000 00 1100 1200 1300 1400 1500 600 7OO 1800 1900 980.22 9('}4.22 22 20 O0 1071.41 995.41 26 18 O0 1159.30 1083.36 30 16 00 1244,36 1168,36 32 48 O0 1327,52 1251.52 34 55 O0 1407,93 1331,93 37 45 00 1485.89 1409.89 39 47 00 1560 79 1484,79 43 17 O0 1631:86 1555.86 45 48 O0 1701.51 1625,51 45 21 N 11 28 E P~ 11 14 E Nil 5 E N 10 19 E N 9 40 E N 8 18 E N 9 10 E N 9 31 g N 9 29 E N 9 49 E lO 29 E si N 7 E 16:15 E 110:23 N 8 25 E 2000 O0 1772.]7 1696.37 44 23 2100 O0 1844.21 1768.21 44 22 2200 2300 2400 250O 2600 2700 2800 2900 O0 1913 05 1837.05 48 49 O0 1976:17 1900.17 52 26 O0 2035: 35 1959.35 55 14 O0 2090 85 2014.85 56 37 00 2146,06 2070.05 56 9 O0 2203.22 2127.22 54 16 O0 2262.51 2186.51 53 38 O0 2319,31 2243,31 57 12 140.11 3.78 144,25 N 187.05 5.64 184,42 N 234.57 3.51 231,09 N 287.20 1,76 282.82 N 342.71 3.35 337.50 N 402 14 2 23 396,23 N 464i76 2!52 458,13 N 530 99 3 29 523,48 N b01,31 1,62 592,84 N 100 673.06 0,75 663,5U N 112 0,79 2,23 4 64 2:25 3.55 0.22 1,44 1,44 1,92 2,24 3000 O0 2372.84 2295.~4 57 31 3100 O0 2427.23 2351.23 56 29 , 2406.83 2538, 2594, 2650, 3200 3300 3400 3500 3600 3700 3800 3900 O0 2482 83 56 11 00 aB 2462,48 56 11 O0 27 2518,27 55 53 00 77 2574.77 55 16 O0 2708,19 2632.19 54 46 O0 2766,10 2690.10 54 36 O0 2822.73 2746,73 55 40 O0 2877.10 2801.10 56 56 N 10 24 E 743,60 h tO 7 E 813.15 I~ 9 35 E 885,62 a 9 10 g 963,15 a 7 14 E 1043.74 N 6 52 g 1126,87 ~ 6 38 E 1210,18 ~4 7 33 E 1292,19 ~ B 42 E 1372,70 N 9 1 E 1454.97 0,67 1 13 0:14 0,15 0,42 0,88 0,52 0,78 1,90 0,56 0,00 N 0 0 E 0,53 N 87 4 W 1,02 N 89 13 W 1,42 N 82 21 W 4,14 N 19 28 W 14,91 N 0 51 E 30,98 N 5 7 E 51.97 N 6 41 E 1~ 8 59 g 1539.44 N 9 30 E 1623,35 N 9 45 E 1706.46 N 9 40 E 1789.53 i~ 9 41E 1872,51 N 9 38 E 1955.02 N 9 22 E 2036,89 N 9 21E 2118.41 N 9 59 E 2200.81 N 10 13 E 2284,71 23 22 E 146,11 N 9 8 E 31:33 g 187,07 N 9 38 g 40,52 E 234,61 N 9 56 E 50,29 E 287,26 N 10 5 E 59.96 E 342,78 N 10 4 E 69 10 E 402,21 N 9 53 E 78 50 E 464,81 N 9 43 £ 89 32 E 531,04 N 9 40 £ 94 E 601,37 N 9 39 E 88 E 673,12 N 9 39 E 733,0~ N 125 36 ~ 743,67 N 9 42 E 801,49 N 137:77 E 813,24 N 9 45 E 872.90 N 150:17 E 885,72 N 9 45 E 949 39 N 152 86 E 963,26 N 9 44 E 1029 14 N 174 46 E 1043.82 N 9 37 ~ 1111 70 N 184:56 E 1126,92 N 9 25 E 1194 51N 194,30 E 1210,21 N 9 14 E 1275 94 N 204,29 E 1292,19 N 9 5 E 1355 65 N 215,73 E 1372,71 N 9 2 E 1436 92 N 228,53 E 1454,97 N 9 2 E 1520,35 N 241,71 E 1539,44 N 9 2 E 1603 19 N 255 11 E 1623,36 N 9 2 E 1685 12 N 269 09 E 1706,47 N 9 4 E 1767 O0 N 283 16 E 1789,54 N 9 6 ~ 1848 82 N 297 04 E 1872,53 S 9 7 E 19~0 14 N 311 00 E 1955,04 N 9 9 E 2010 90 N 324 50 E 2036,91 N 9 10 E 2091 34 N 337 74 E 2118,44 N 9 10 E 2172 58 N 351,56 g 2200,84 N 9 11E 2255 19 N 366,35 E 2284,76 N 9 13 E ARCO ALASKA~ INC. 3H-22 KUPARUK NORTH SLOPE,ALASKA CD~PUTATIDN I.)ATE ~ 4-MA¥-88 PAGE 2 DATE OF SLIRVE¥1 24-APR-BO KELLY BUSHING ESEVATION{ 76,00 FT ENGINEER: T, WEST INTERPOLATED VAbUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE MEASURED VERTICA5 YERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4000 O0 2932.00 2856,00 56 28 4100 O0 2987 45 2911.45 56 10 4200 O0 3043 30 2967,30 3023,50 55 48 3079,71 43OO 4400 4500 4600 4700 4800 4900 55 53 O0 3099 50 O0 3155 71 55 51 O0 3212 30 3136,30 55 14 O0 3270,01 3194.0i 54 19 O0 3329,37 3253.37 52 55 O0 3389.10 3313.10 54 25 O0 3446,17 3370.17 56 8 5O0O O0 530O 52OO 53O0 5400 5500 5600 57O0 58O0 59OO 3498 49 3422,49 60 7 O0 3548:X5 3472,15 60 9 O0 3598'16 3522,16 59 49 O0 3648 54 3572,54 59 36 O0 3699 46 3623.46 59 8 O0 3750 92 3674.92 59 3 O0 3802 61 3726.61 58 37 O0 3854 85 3'178,85 58 24 O0 3907 40 3831.40 58 6 O0 3960:54 3884.54 57 38 6000 O0 4014,55 3938.55 57 1 6100 O0 4069,23 3993,23 56 41 6200 O0 4124, ,61 4103.61 56 24 6300 6400 6500 6600 6700 6800 6900 30 4048,30 56 28 O0 4179 O0 4234'69 4158.69 56 55 O0 4288:29 4212,29 58 5 O0 4340,97 4264.97 58 10 O0 4393.5~ 43%7,58 58 17 O0 4446,15 4370,15 58 23 O0 4499,09 4423.09 57 27 7000 O0 4553,20 4477,20 57 22 7100 O0 4607,05 4531,06 57 19 7200 00 4661, 4585,01 .64 4637.64 58 35 7300 7400 7500 7600 7700 7800 7900 01 57 37 O0 4713 O0 4766.08 4690.08 58 6 O0 4818,68 4742.68 58 t5 O0 4871.30 4795,30 58 13 O0 4924.03 4848,03 58 7 O0 497~,78 4900.78 58 2 O0 5030,07 4954.07 57 44 DEG MIN FEET DEG/IO0 FEET FEET FEET DEG mIN N 10 12 g 2368,27 N 10 7 E 2451,47 N 10 5 E 2534,40 N 10 13 g 2617,09 N 9 28 E 2699,79 N 9 29 E 2782.22 N 9 29 E 2863,89 N 10 1E 2944.35 N 10 13 E 3024.53 N 10 13 E 3106,62 N 10 47 E 3191.77 N 10 19 E 3278,52 N 9 55 E 3365.10 h 9 42 E 3451,46 ~ 9 18 g 3537.53 N 8 58 E 3623,27 N 8 42 E 3708,87 N 8 40 E 3794.14 l~ 8 36 E 3879 22 iv 8 21E 3963:93 N 7 54 E 4048.09 {~ 7 30 E 4131.79 i~ 7 0 g 4215,23 N 6 37 g 4298,48 t'; 7 28 E 4381 89 N 8 29 E 4466:30 ~ 8 8 E 4551.30 n 7 46 E 4636.33 ~ 7 41E 4721,37 t~ 8 5b E 480b,20 ~ 8 58 E 4890,30 N 8 49 E 4974,55 N 8 49 g 5058,75 N 10 21 g 5143,77 N 9 53 E 5228.88 t~ 9 9 E 5313,93 N 8 29 E 5398.97 a 7 48 E 5483,92 ~ 7 37 E 5568,86 N 8 33 E 5653.46 0,35 0,23 0,29 0,30 0.25 0,45 1,32 1 62 2:16 3,19 2337 44 N 381,21E 2368,33 N 9 15 E 2419 35 Id 395,88 E 2451,53 N 9 17 E 2501 O1N 410,49 E 2534,47 N 9 ~9 E .18 N 9 20 E 2582 43 ~ 425,04 E 2617 2663 92 N 439,22 E 2699 88 N 9 21E 2745 2~ N 452,80 E 2782 32 N 9 21E 2825,79 N 4~6,22 E 2863 99 N 9 22 E ) 2905,11 N 479,77 E 2944 46 N 9 22 E 2984,05 N 493,92 E 3024 65 N 9 23 E 3064,87 N 508,46 E 3106 76 N 9 25 g 0,58 0,37 0.35 0.70 0.25 0,53 0,34 0.56 0,60 3148 61N 524 3233 92 N 540 3319 18 n 555 3404 29 N 569 3489 17 N 584 3573 83 N 597 3658 42 N 610 3742,72 N 623 3826,83 N 3910,60 N 05 E 3191 92 N 9 26 E O0 E 3278 70 N 9 28 E 19 E 3365 29 N 9 29 E 92 E 3451 67 N 9 30 E 18 g 3537 74 N 9 30 E 74 E 3623,48 N 9 29 E 89 E 3709,08 N 9 28 E 75 E 3794,34 N 9 27 E 636 58 E 3879,41 N 9 26 E 649:10 E 3964,11 N 9 25 E 0 65 0 61 0 40 0 53 2 32 0 b5 0 68 0,48 0,96 1,18 3993 92 N 561 02 E 4048 25 N 9 23 E 4076 89 N 672 26 E 4131 94 N 9 21 g 4159 68 N 682 81E 4215 35 N 9 19 E 4242 41N 692 65 E 4298 58 N 9 16 £ 4325 29 N 702 54 E 4381 97. N 9 13 E 4408 84 N 714,58 E 44~6 37 N 9 12 E 4492:94 N 726,89 E 4551,36 N 9 11E 4577,17 N 738,66 i 4636,38 N 9 10 E 4661,48 N 749,94 E 4721,42 N 9 8 E 4745,41N 762,31E 4806,25 N 9 7 E 0,47 0,50 1,45 ,84 ~,37 0.73 0,41 0,49 0,86 0,71 4828 47 N 775,45 E 4890,34 N 9 7 E 4911 70 N 788 54 E 4974,60 5058,79 N 9 6 E 4994 5078 51~2 5246 5330 5414 5498 5582 N 9 7 E 94 N 801 20 g 78 N 815 36 E 5143 81 N 9 7 E 55 S 830 61 E 5228 94 N 9 8 E 43 N 844 67 E 5313 99 N 9 8 E 4(; N 857 68 E 5399 0~ N 9 8 E 6 N 869,79 E 5483 97 N 9 7 E 5b N 881,05 E 5568,90 N 9 6 E 55 IV 892,88 E 5653,50 N 9 5 E ARCO ALASKAv INC. 3H'22 KUPARUK NORTH SLUPEwALASKA CUMPU£A~ION DATE: 4-MAY-88 PAGE 3 DATE OF SURVEY: 24-APR-SE BUSHING EbEVATIONI 76,00 FT ENGINEERI T, WESt' INTERPOLATED VALUES FOR EVeN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL D[]G~EG RECTANGULAR cOORDINATES HORIZ, DEPARTURE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/wEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG 8000 O0 5083,25 8100 O0 5136,79 8200 8300 8400 8500 8bO0 8700 8800 8900 5007.25 57 39 5060.79 57 39 O0 5190,03 5114.03 57 54 O0 5243.39 5167.39 57 33 O0 5297'35 5221,35 57 9 O0 5352:10 5276,10 56 32 O0 5407,68 5331.68 55 58 O0 5463.90 5387,90 55 41 O0 5520.54 5444.54 55 11 O0 5577,70 5501'76 55 4 9000 O0 5635 28 5559,28 54 42 9100 O0 5693 34 5617,34 54 17 9200 00 5751 95 5675.95 53 54 9300 00 5811 08 5735.08 53 28 9400 O0 5870 84 5794,84 53 7 9500 O0 593! 10 5855,10 52 48 9600 00 599X:63 5915,63 52 36 9700 00 6052,45 5976,45 52 30 9800 00. 6113 33 6037,33 52 31 9900 00 6174:20 609'8,20 52 35 iO000,O0 6235.28 5159,28 52 19 i0100,00 6296,41 6220,41 52 19 10200.00 6357,54 6281.54 52 ~.9 10234.00 6378,32 6302.32 52 19 DEG HIN FEET DEG/100 N 8 22 E 5738.15 N 8 21 E 5822.61 N 9 24 E 5907 26 N 9 12 E 5991:83 N 8 26 E 6076,01 N 7 36 E 6159.69 N 6 43 E 6242.77 N 5 59 E 6325.40 N 5 16 E 6407,67 N 4 4~ E 6489,50 N 3 59 g u571.05 N 3 4 E 6652.12 N 2 24 E 6732.69 N 2 6 E 6812.78 N 1 45 E 6892,36 ~ 1 32 E 6971,53 t. 1 14 g 7050.45 N 1 9 E 7129 11 ~< 0 57 E 7207~73 N 0 42 E 7286~27 r: 0 39 E 7364 63 N 0 39 E 7442'.95 N 0 39 E 7521.28 N 0 39 E 7547.91 FEET FEET FEET DEG MIN 0.60 0'39 0,21 0,54 0,63 0.75 0.79 0.56 0.70 0,88 .5666.30 N 905.47 E 5738 19 N 9 4 E 5749,87 N 917.69 E 5822:64 N ~ 4 E 5833.53 N 930 60 E 5907,29 N 9 3 E 5916,97 N 944:37 E 599~,8~ N 9 4 E ~000.15 N 957'32 E 6076,04 N 9 ] E 6083 02 N 9~9 01E 6159,7! N 9 3 E 6~65 50 N 979 30 E 6242,7~ N ~ ! E ~2'47 70 N 988 46 E 6325,41 N 8 59 E 6329 71 N 996 52 E 6407,67 N 8 56 E 6411 41N 1003 70 E 6489,50 N 8 53 E 0 70 I 42 1 14 0 35 0 44 0 32 0 57 0 46 0 48 1.88 0492 9'1N 1010,01 E 6571,06 N 8 50 E 6574 23 N 1015,07 E 6652 13 N 8 46 E 6655 17 N 1018,92 E 6732 72 N 8 42 E 67~5 75 N 1022'00 i 6812 84 N 8 37 E 6815 88 N 1024,71 E 6892 48 N 8 32 E 6895 65 N 1027 04 E 6971 71 N 8 28 E 6975 23 N 1028 93 E 7050 7~ N 8 23 E 7054 58 N 1030 58 E 7129 46 N 8 18 E 7133 91N 1032 13 E 7208 19 N 8 13 E 72~3 24 l~ 1053 ~9 E 7286,86 N 8 9 E 0,00 0.00 0,00 0,00 7292,40 N 1034,09 E 7365,36 N 8 4 E 7371.54 N 1035,00 E 744],85 N 7 59 E 7450,68 N 1035,90 E 7522,35 N 7 54 E 7477,58 N 1036,20 E 7549,04 N 7 53 E 3H-22 KUPARUK COt~PUTATIOtl DA~E= ~-~A¥-88 PAGE 4 DATE OF SURVEY: 24-APR-SB KELLY BUSHING ELEVATION{ 76,00 FT INTERPOLATED VALUES FOR EVEN 1000 FilET OF ~EA6URED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZI~UTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/~EST DIST, AZIMUTH FEET DEG/iO0 f'EET FEET FEET DEG MIN 0 O0 lO00iO0 9~0 2000 O0 1772 3000 O0 2372 4000 O0 2932 5000 O0 3498 6000 00 4014 7000 00 4553 8000 O0 5083 0 O0 '76.00 0 0 22 904.22 22 20 37 1696.37 44 23 84 2296.84 57 31 O0 2~56.00 56 28 49 ]422,49 60 7 55 3938.55 57 ! 20 4477.20 57 22 25 5007.25 57 39 9000,00 5635.28 5559,28 54 42 0 0 E 0 00 N 10 24 E 743.60 N 8 59 E 1539.44 N 10 12 E 2368,27 h 10 47 E 3191.77 N 7 54 E 4048.09 N 8 58 E 4890.30 N 8 22 E 5738,15 N 3 59 E 6571,05 0,00 3,78 0,79 0,67 0.35 0.82 0.65 0,47 0.60 0,70 o.00 N 0.00 E 0,00 N 0 0 E 144 25 N 23,22 E 146.11 N 9 8 E 733 O3 N 125,36 E 743,67 N 9 42 E 1520 35 N 241.71E 1539 44 N 9 2 E 2337 44 N 381,21E 2368 33 N 9 15 E 314~ 61 ~ 524.65 E 3191 92 N 9 26 E 3993i92 N 661,02 E 4048 25 N 9 2~ E ') ~828 47 N 775.45 E 4890 34 N 9 E 56~6 ~0 N g05,47 E 5738 ~9 N 9 4 E 6492,97 N 1 ~0,01E 657~ 06 N 8 §0 E 10000.00 6235.28 6159.28 52 19 10234.00 6378,32 6302.32 52 19 N 0 39 E 7364,63 N 0 39 E 7547,9! 0.00 0,00 7292,40 7477,5~ 1034,09 E 7365,36 N 8 4 E 1036,20 E 7549,04 N 7 51 E ARCO ALA~KA~ INC, 3H-22 KUpARUE NORTH SLOPE~ALASKA CO~:iPUTATION DATE: 4-MA¥-88 PAGE 5 DATE OF SURVEY{ 24,.APR-88 KELLY BUSHING ELEVAT~ONt 76,00 FT ENGINEER{ T, · E$~ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG M~N 0 O0 76 O0 176 O0 276 01 376 04 47~ 52 57 71 679 75 783 22 888 41 0 O0 -76,00 0 0 N 0 O E 76:00 0.00 0 17 iV 73 18 W 176.00 I00.00 0 17 $ 76 lo W 276.00 200.00 0 19 N 47 21 W 376,00 300,00 3 14 N 3 18 E 476,00 400,00 7 26 N 8 37 E 576.00 500,00 9 55 N 9 16 E 676,00 600.00 13 11 N 8 50 E 776,00 700,00 16 24 N 9 47 E 876,00 800.00 ~9 40 N 11 2 E 0.00 -0,07 -0 09 -0 14 2 O6 11 58 26 97 47 19 73 72 106,28 0,00 0,00 N 0 O0 0,22 0,01 S 0:42 0 38 0,05 N 0,91 0:53 O,Ob N 1,31 5,01 2,32 N 1,53 3,48 11,76 N 0,25 1,78 26,9U N 2 13 3,71 46,93 N 5~34 3,19 73,14 N 9'46 2,70 105,1~ N 15,39 0,00 N 0 0 E 0,42 S 88 54 W 0,91 N 86 43 W ,31 N 87 9 W ,78 N 33 18 W 11 77 N I 13 W 27 04 N 4 31 ~ 73 75 N 7 22 E 106 28 N 8 19 E 995.45 976,00 900.00 22 11 1105,13 1076,00 1000,00 26 35 1219,36 1176,00 1100,00 30 56 1337,78 1276.00 1200.00 33 29 1459 83 1376 O0 ~300.00 36 46 1587 17 1476:00 1400,00 39 30 1721 03 1576i00 1500.00 43 56 ~863 60 1676 O0 1600 00 45 46 2005 08 1776 00 1700:00 44 21 2145 10 1876.00 1800.00 %6 12 Nll 28 E 144,41 3,51 N 11 12 E 189,34 . 4,68 N 10 57 E 2~4,45 3,43 N 10 3 E 307.83 1,91 N 8 39 E 377.78 2.90 N 9 3 E 456.59 2.13 N 9 31E 545.50 2,72 N 9 36 E 647.10 1 82 N 10 24 E 747.15 0:87' ~ 9 53 E 845.12 4,97 142 59 N 186 67 N 240 79 N 303 14 N 372 12 N 450 07 N 537 78 N 637 99 N 736 832 22 88 E 144 4I N 9 7 E 31:77 E 189 35 N 9 39 E 42,42 E 244 50 N 9 59 g 53 95 g 307 90 N 10 5 E 65 55 E 377 85 N 9 59 E 77 ~9 E 456 64 N 9 43 E 91 72 E 545 55 N 9 40 E 108 51E 647 16 N 9 39 E 53 N 126,00 E 747 23 N 9 42 E 9~ N 143,33 E 845 22 N 9 45 E 2299 73 1976 O0 1900,00 52 25 2473 O0 2076 O0 2000,00 56 35 2653 2822 3005 3187 3367 3544 3717 3897 05 2176 O0 2100,00 55 0 86 2276 O0 2200,00 54 15 89 2376 O0 2300,00 57 29 71 2476.00 24o0,00 56 10 36 2576 O0 2500,00 56 08 2676:00 2bO0,O0 54 55 11 2776,00 2700,00 54 45 98 2876,00 2800,00 5b 57 t~ 9 10 E 962 94 ~ 6 55 E 1104:33 ~. 7 0 E 1253,95 N 8 50 g 1391,15 h 8 59 E 1544,41 N 9 44 E 1696.24 N 9 37 E 1845.47 N 9 ~9 E 1991.16 N 9 25 E 2132,36 ~ 10 13 E 2283,02 2.26 0 39 2 57 3 56 0 74 0 25 0 5O 0:44 1,47 0,59 949,18 N 1~2 82 E 963,04 N 9 44 E 1089,32 N 181 85 E 1104,39 N 9 28 E 1238,00 N 199 45 E 1253,96 N 9 9 E 1373,88 h 218 55 E 1391,16 N 9 2 E 1525,20 N 242 48 E 1544,42 N 9 I E 1675,05 N 2U7 36 E 1696,25 N 9 4 E 1822,1b N 292.51 g 18~5,49 N 9 7 g 1965,79 N ~17,01E 1991,19 N 9 9 E 2105,10 N 340,01 E 2132 38 N 9 10 E 2253,53 h 366,05 E 2283:06 N 9 13 E 4079 40 2976,00 2900.00 56 13 4258 22 3076,00 3000.00 55 46 4436 1! 3176.00 3100,00 55 36 oo.oo 4777 58 3376,00 3300,00 53 52 4955 36 3476.00 3400.00 58 53 155 82 3576.00 3500,00 59 59 ~354 09 3676.00 3600.00 59 22 5548 69 3776.00 3700.00 58 53 5740 31 3876,00 3800.00 58 20 !~ 10 7 g 2434.35 N 10 8 g 2582,55 h 9 28 g 2729 65 N 9 31E 2872:2] N lO 12 E 3006.34 ~ 10 36 E 3153,22 N 10 4 E 332b,8~ N 9 31E 3498,07 ~ 8 50 E 3665,01 N 8 41E 3828,46 0,29 0,30 1,19 56 0,16 2402,50 N 392.~7 E 2434,42 N 9 17 E 2548,4~ N 418,92 E 2582,64 N 9 20 E 2693.37 N 444,13 E 2729,75 N 9 21 E 2834.02 N 467,60 g 2872,33 N 9 22 E 2966 15 N 490 69 E 3006,46 N 9 23 E 3110 72 N 516 85 E 3153,37 N 9 26 E 3281 53 N 548 56 E 3327,07 N 9 29 E 3450 24 N 577 72 E 3498,28 h 9 30 E 3615 07 N 604 20 E 3665,22 N 9 29 E 3776 65 N 628 93 E 3828,66 N 9 27 £ ARCO ALASKA, INC, 3H-22 KUPARUK NORTH SLOPE,ALASKA CUi~PUTATION DATEI 4-NA¥-88 PAGE 6 DATE OF ~URVEY~ 24-APR-88 KEhLY BUSHING ELEVAT~ON~ ?6,00 FT ENGINEERI T, WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE: MEASURED VERTICAL VERTICAL DEVIATION AZIMUT!{ DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAI, DOGLEG RECTANGULAR COORDIi~ATE$ HORiZ, DEPARTURE SECIION $~VERIT¥ NORTH/SOUTH EAST/~EST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 5928 83 3976 O0 3900,00 57 26 oo ooo.oo 6293 48 4176 O0 4100,00 56 23 6476 6666 6856 7042 7228 7418 7608 78 4276 O0 4200,00 57 53 51 4376 O0 4300.00 58 18 78 4476 O0 4400,00 57 58 37 4576 O0 4500,00 57 25 03 4676 00 4600,00 57 53 80 4776:00 4700,00 58 {2 94 4876~00 ~800,00 58 13 N 8 15 ~ 3988.26 N 7 26 E 4142,07 N 6 38 E 4293 06 N 8 29 E 4446:60 N 7 53 E 4607,83 N 8 3! E 4769.67 N 8 57 E 4926 O1 N 9 14 E 5082:44 N 9 44 E 5244.86 N 8 27 E 5406.56 0.93 0,49 0,49 I 25 0:38 1.75 0,29 1,99 0,94 0,36 777989~ 51 4976 O0 4900,00 58 3 45 5076 O0 5000,00 57 46 5100,00 8173 8360 8543 8721 8896 9070 9240 9408 60 5176 O0 57 52 59 5276 O0 5200 O0 57 15 23 5376 O0 5300:00 56 13 47 5476,00 5400,00 55 40 92 5576,00 5500,00 55 4 22 5676,00 5~00.00 54 23 75 5776,00 5700,00 53 51 58 5876.00 5800,00 53 5 N 7 36 E 5567.b0 N 8 26 E 5726,70 N 9 6 E 5884,89 N 8 46 E ~042 89 N 7 9 E 6195:70 h 5 50 E 6343 11 a 4 47 E 6486:98 N 3 22 E 6628,03 N 2 11E 6765,36 t~ 1 44 E 6899,17 0,82 1,04 1,04 0,97 1,37 0,66 0,82 0,92 0,21 0,19 9574.29 5976 O0 5900.00 52 40 9738,63 6076:00 6000.00 52 29 9902,96 6176:00 6100.00 52 37 10234,00 6378 32 6302.32 52 19 16 E 7030 22 9 E 7159:47 43 E 7288.59 .39 E 7547,91 0 93 0i39 0o00 3934,68 N 652 62 E 3988 43 N 9 25 E 4087.0~ N 673 60 E 4142 21 N 9 21E 4237,02 N 692 02 E 4293 16 N 9 16 E 4389,3~ N 711 66 E 4446 67 N 9 12 E 4548 9] N 734 77 E 4607 89 N 9 10 E 4709 31 N 756 74 E 4769 72 N 9 7 E 4863 75 N 781 03 E 4926 06 N 9 7 E ) 5018 34 N 804:93 E 5082 48 N 9 6 E 5178 29 N 833,32 E 5244,91 N ~ 8 E 5337 98 N ~58,79 E 5406,62 N 9 8 E 5497,51N 880 88 E 5567 64 N 9 6 E 5654,97 N 5811,4u N 926 97 E 5884 92 N 9 3 E 903 80 E 5726 5967,4~ N 952 36 E 6042 6118,74 N 973 64 E 6195 6265,34 N 990 29 E 6343 6408,90 N ~003 48 E 6486 6550,06 N 1013 70 E 6628 6688,04 N 1020 21E 6765 6822,74 N 1024:91 E 6899,2~ N 74 N 9 4 E 93 N 9 4 E 72 N 9 2 E 12 N 8 58 E 98 N 8 53 E 03 N 8 47 E 41 N 8 40 E 8 32 E 6954,82 N 1028,48 E 7030,45 h 8 24 E 7085,21 N 1031,18 E 7159,86 N 8 16 E 7215,58 N 1033,21E 7289,18 N 8 8 E 7477,58 N 1036,20 E 7549,04 N 7 53 E ARCO ALASKA, INC, 3H-22 NORTH SLOP£,ALASKA COMPUTATION DATE: 4-MAY-88 DATE Off SURVE¥~ 24-APR-88 KEEL¥ BUSHING ELEVATZON~ 76,00 FT ENGINEE~ T, WEST TOP KUPARUK C BASE KtlPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD INTERPOLATED VALUES FOR CttO5EN HORIZ[~NS MEASURE[) DEPTH BELOW KB SURFACE LOCATION AT DR~GIN~ 957 FNL, 282 TVD RECTANGULAR COORDINATES FROM KB SUB-~EA NORTH/SOUTH EAST/WEST 9678.00 6039,08 5963.0B 7037.12 9678 00 6039.0B 5963,0B 7037,12 9678:00 6039,08 5963,08 7037,12 9821,00 6126,11 6050.11 7150,57 9970,00 6216,94 6140,94 7268,66 ~0234,00 6378,32 6302,32 7477,58 10 1030 22 £ 1032 39 Z 1033 82 E 1036 20 E ARCO ALASKA, 3H-22 KUPARUK NORTH SLOPE,ALASKA CO~PUTATIO~ DATE: 4-MA¥-88 DATE OF SURVEY: KELLY BU6HING ELEVATION: ENGINEER: PAGE 24'APR'8'~ 76,00 T, WEST MARKE[~ TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD ORIGIN: 957 FNh, MEASURED DEPTH TVD BEbOW KB FROM KB SUB-SEA 9678.00 6039.08 5963.08 9678.00 6039.08 5963.08 9678.00 6039.08 5963.08 9821.00 6126.11 6050.11 9970 00 621b.94 b140.94 10234:00 6378,32 6302,32 282 8URFAC NORTH/80 7037.12 7037 12 7150.57 7268.66 7477.58 E LOCATION AT AR12. TI2N RSE,UM COORDI~AT£S UTH EAST/WEST 1030,22 E 1030,~2 E 103 , 103 ,39 E 1033,82 ~ 1036,20 E FINAL ,Ebb LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10234,00 6378.32 6302.32 HORIZONTAL DEPARTURE DISTANCE AZIMUTH f'EET DEG 7549.04 ~q 7 53 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. WELL 3H-22 FIELD KUPARUK COUNTRY U.S.A. RUN 1 DATE LOOOED 24 - APR - 88 REFERENCE 7272! WELL' 3H-22 (957' FNL, 282' FWL, SEC 12, T12N, R8E, UM) HORIZONTAL PROJECTION NORTH 12000 REF 72721 10000 8OOO SOO0 4000 2000 -2000 ~:~T H -4000 WEST SCALE : 1/2000 !N/FT i-i'*+i"l''t'!''i-i''!''+*~-+'t'T''?+~''+'-*'i''+!''i''~'*+*-+'+'' "+'i?t'l?'!"*?'"+,''~''?!'''t'i'''f*i'''i*'4.''+'' "+'i'*+'+'+'+"?"+"'+ ...... t"+'~'*+'~"i"'i'*+*'t ..... t"!"~'"T ....... t"t'"'t'"?' 'T'T'+~"~"~"~"?~"~"'+-++'?"~"'?~'+'~ "~"~'~-~-~+i"?- -?~"+'TTmT'~="='"t"T'~-~-'~"~'~"+'+'- "?*?'~'-~"'~"-?'+"+"'+"' '"?+"?'"j'?"'r"r"~ ...... ~"~"':"~ ....... :'"~'"?~":'" -~'-i'~?-~'-i--~'-id ...... F+-+---F-t'-i-~-"~-'*++!--~'-~'-ffl-i'-' -f~-fi'"Y!-~'?t"~"~'*~"i"i'"t"~"~d'-? "+'~"~"'H-"+"'+'+'~-' "+'H"~"~'"f"br'~ ..... i"i*'i"~"'~'"~"~"i"*? ~...~.~-~.,.~ ~ ~ ~,.~..~..~-.~..,~ ~ ..4,.~..~..4-.~ ~ ~-.~..~..4-~..-~ ~ ..4..~..~..+.~ ~ ~ ..~..~..~-.~-~ ~ ~ ~ ~ ~ ~"~-~'~-4"'~"~"'~"'~~ ~ ~ . ~ ~ ~ ......... ~..+.~..4~ ~ ~ ............. ~ ~"4~ ...... ~...~,..~,..~ ~ ..........~ ~ ~..~...~...~ ~ ..,~ .......... ~ ~ ..............~ ~"~"' ~..?.?.?..~..~..~?~..-..?~?...?~?.?~..-..?.~..~.?..~.?-~-?*...~..~...?~4.~-~..~ ..... ??~..?..~..,.-~---?.-?.-?-~..?-?.]--?.~.? ...... ,.-.~..-~ ........ ,.?.~..~...~..??~...~ ...... ~.?..-~...~..- 4-+~---.-~--~-~-.~--.-J.-~-;.~.-I---~.-~.-~--~---~-~4-~.-~-6~.4--- qq.~.4-4.-~.-~-- .-~.4---~-4-.~+.~4.--...~.44..~..~-.4-4-~--.~.-..-4.-~.4..~..-.-4.-+4-.~ ...... ~..;...~.+. ~-.+-.~.~...~ d~-~-.i..-..~..~.J...L-..-L.~..J..~... -~..~...~..-.i-..,..~..+.~..~..~-~...~-L-.~ ...... ~-~--~-J-- -~4.-+--~--- ,-;-;--~-..~-..;..J..~..--~-.~..~.-+--.-+.-~..~-..; ...... ~.--~..~..~.,--.~,.~...~..~ ....... ~..~,,.~..4 ....... ~--4--~-~-----~-;-~..~----~,.~-~..~]-;.~-~,.~.--..i.-~.-~-+-~--~..J- .-~q-.~--~.-~4.-+-;-- ..~..~..~.-~..~-;-~...i.4..-..~...i..~..-k-..~...L.~...~ ....... ;...;..L...L....~...~..i...~ ....... ~.4-~.--+.--L.~.;...;...~... -~"t"T'T'" "T'T'T'T" "'~"?'?'?"~"T'T"?'"?-" "'!"T'T'T'T-~-T'T"?'" "T?"?"? ~"%d"?~ ...... ~"T'T'T'~"T'T'T'% ...... ~"%-%"'!"- "T"T'T"~ ....... ?'"?!'-?"" '"i'"~-~"~ ...... ~"T'T"~ ....... ~"T'?'"~ ~..4.~.~ ..~_~_~_.. ~_ ~ ~.~._ ~..~.~.....~_~-~.~-. ~-~..4-~.. -~ ,-.~-~..- k..4-~~,.~-~..~ -4..4~-4....~-.4..~..4..., .'+--~-e- -4-'~'4"4- ..4..4.,~4... -,.~-4..4..,~..- ~ ~ ' · ~ ~ ' · : : ~ : ........ ~ ............. ~ ......... 4 '~ ' '~ ....... ~ t~ ' t ~-'~.-~--~,d ,.~..~-~-t-~ .-~.-~-?.~-.-, .--t.-?.--?.?~ ,.~-~'-~--?., ..?-??.-'t--- t"~?--??-- -'~--~-'?"t ...... t'-?'~-~"-~"~-?-~---t---~ '-~- . '~ ...... ?"? "'t-' "'t'"t'm'T'" "?"?~ ............ 4-~+--~--~ .-~--~-~-.-~--. -~-.~-~-.~--- -4-~.-~-~ .-4--~.-4--. ~--+-4.--~.4--,-4--4--4-%-'4-+-~.~---,..++-~4--~-+-+4-q--.'-~--4~-4-- -+.4-4.-+.- -4.-.~+-? -4~--+.4.,. 4-~qq.--~ ,-~-4-~--~-~ -~-4-4.--~- .4.-~q.--~-',-4-.~-~-?~ --??-?+--.-+-+-~?.-.-.+4--F-+.-,--~-4.-+~--++-~--~-~- -~.'T4',+.~ -?.~.-~.-+--.~"-~-+--~-~ .-~"+-~-'~"- -~q"~'--~ ...... ~-'+'~-'-~'-- ~..~-~-~..-~-~-~.4.-k, ,.~...~-~-.~.-. ,-.~..~-~...~ ..... ~--+-+-+--..-~.-~..--i.-+-,.-+.4--4--+--,..+-+4-4.--,-4--4--+-4..-~,.4..4-+~.-- 4.-+.~.-~.q q-.~..~q ...... ~-.+.~.-4-. -+4--i..+,-,--.~..+.~.-~ ...... +..+.++.~ q-~.4.-~4.-~.4..~.., -~q.4..~... ..~..+4q-. '..++4-4.-. .-+-++4--- .-.++++- ..+++.+-- .--+-+++--~..+-i.~ ~+.4-~.4.,.F~q-~...p -+'+-~..~- '+-+~-+----~--+q"4"" ..+q...~..+.. ~-~-~4... ~.-~,.~-~... ~.--~.-~-~,.4- ..4,.~-4..~..- ..~..~.,~-+-, ...~-~..~-~---+~4-+-,..~-~..+.+.-..+.~+.- ~.+.?.+~.....~-~-~-+,..74-~..-~- -.+...~4..~- ..~.~-~--+,.-~..~..~-~- ~m~4---L+4.+4... 4-~.-~..-L 4.t~..~-q-4..4..4-.~--~-4--4-.4-.-,--+.4q.+-~+-4.-++--.4.-4.-+.4.-~-4..4..4-.4-.. L..4.q..4..4-. ~.~-q...{ ...... {'"~'q"4"' [..4-4.q~-...+-).-q-....-b~...~.-.*... ~-4,-~--f--~-4--+4--,..4.-4-~-4---.-.4.-+-4--~-.-.-i--!-i-i-t..+-?i..i---.-~-d..i--., .~i.-~-t--l-?i.-!.-?-~ -i-~ ~.-+-i.-i--?-i-%-f?--f.- I?"??'T" r~'i'T'+"'--f' :d"~"" '"i f"t"~'- ~:"~"4-+"i ,.~4.,4..l~.,,4 ,--4.-4-4lW-.- .................................... .-~-4--~-.4~-i ,..4..41.4-4.. ............ --4-.4.-4-.4---...~.4--4--~--.--4-~: ...... i-4.-~.-4~;::: ......... -4...*l.4..~-. =4..4..~-~.,.lb +"*"l '-.4-- -4.--:l.: F~]]'"+'4--'4.- '.- '"4 ........... -T'~"?'r'"'T'?'~ ........ T'Y?"~'"""??"?'T""'T'T'?'?]"??'?'t" d"?~"T'" "?T'T-?' "~d"?'~n"d"?'T'?"q"??'T" ??'Y]-'~ ..... brT'1'" "T'~d"t ...... :"T'~'~ ......... t ........ -~-~ ........................ ~-~- 4 ~-~-~. -~ ~ ~ ~ **~-~-~. ~-* ...~..~..4..~- ..~..~..~...~-..~*~*-~..~.-~ ....... ..~..4..~...~..--4..~. ' i ~ '"'~' '..-,..~.~..~,. .............. ~--~..~...~..--W..*~-+.. ,..4.,4 ...... ~ ~-~., .~'..~.,-..&~.4.,*~- ~'~"~**~"' "~"~'"~-~'" "'~-~"~"~"~"'~'"~-~"~"-'"~"~-'~"~"t"~"~"~'"{- "~"~"~"~"* "++'~"~"- "~"~"+~fl "~"~"~'~-* "'~"~-~*~"'-~'~'"{-' '"'~'*'~*~-i'" '*-i--i-~"~'- --+-~'+'~-'* '"fi"T'i'- ~-4~... ,-4~-4-4... ,-~-4.*~-~..4-~.-~.~..4......4.-4..~**~-~-4..4.-p4.- -~*~.~..q-~.~*-~.- ,.4-4.~-~- ~.~-~--,~..~.~... ,-4-~..4..4-~-.~--+.-~--,..~-~4..~-*-~.~-+*+-.. **~-.~-, ~-~.4.4,..-~..~..~-.~ ....... ~.-~.-~.4,..J...~..4..~.-~..-...~..~,.~..~..J.-~..~..~-.;.-..4..~.-~..~-~,.~,.~.-~-.~..- ..4..~.~..J.....-~. ~.U~.--,-4-~.~-~...,..~...~..~..,~ ....... ~...,..4..~...,.~,.~..~..4..--.~,,~..~..~ ......... 4-..$ ...... -+~?*..- .-+-+-+-~ ...... ~-.++-+q"+-??--+ ...... ~..?..~-?~..?.~?.?..~..?.~..~..+.?.~..~.~.~..~..~..~..~.~......~..?.?~..~...~...i.~"~...~..+..?.?+. ?,"?'4"'"'I"~"~"~ ...... ~"~"~"~"'~'"~"?+' -~.-~,-~.-F---4.-~-R-.+---4-4..~-4-q----F.~-~.-4----4..4..~-~--~-~q.4..+---.+-+-~-+t-+-+--~+--.+..f-i~---..-+-+-~.-+--.-+-i-+.+--~.4--~.-~-.i-. '-H"~"~-"t"~'t"t"" %--~4q J~-+++-- ~--+-+.+-.;--+.+.+..+ ....... ~.-+-+.~ ..... ~-+.+.+.--.~-+,+.+....+.+.+-+..-..~..~....+. ,.~.4,.~-~..-..+.i..+.+..-~-.~...~-...~..4..+.~.....~.J ...... ~ ....... ~..'...~.?.+-.~- ~i'~'~ ~ * ..... ~ ~--~-Q-.4--~ -4-4~ ~ : : ~ ~ * ~ i'~'"+'" ..-*.-+-.i..4.--..-4--4--4.-4-.~ ~ ~ ~ ..4-.4--4--4..-i~ ~i~"4"4'4 .... ~-4.-4...i-.-i ~ .{~-~: ,"4"4' -4-.-- -.4.--*..~.-4.... 4.--4..4-4..-~ i i ~4-.4-~...i: ~ * ......... i I *~* .... '~- ..~.-4.~ { ..4-.- ---4-~..t ! I [ ~ ~ ~ I/";"' ~ ...... * ....... ~-~4"~'-- '~+"+"~-' -~-~'"??*-?"?'??- "?"W-~"2"' "???'? "?'~"~"*'~'~"?'?~-~ ...... r~-. ~"' "+'~"~'W-' -~--+"~-'+ ....... ~"W~ ....... *~?~"T- "T'~-~''' r"~T'T- =.-+-~--~ ...... ++-+---~-..~.~--+--L+-,--+-+---.+-??.-,.-.~.-++-,..?~-.-,..?.-?~.-+.~--~..-?...?-il?-?~.-~-?..+.-~--..+.+.++-- -+'+'+"t ...... ~'"?'~ ........ ~"+-~'-~-~'-'~"~'-+'?'" '..~4~.-..~.4..+.~..~...-t4~...~ ....... ~..~...~.4.......~..~..-~.-~..~ ..-~4.4~.~...I..~-~..~..~.- ..~.4..+4-...4...~-.~..~ ..~..+.~..~-. ~..~..~..~..- ..~...~...~ ....... u~..~..~.._ ..~..+.~.. ,q...~_+.~..~......+-, , · ~::4`~...~..'..~`~.+~..~.~..+.~...~...j...~..~...~...~.....~..~...~..~..~..~'~`+.~... 4..+.~.-~:~..~.~+~.....~.:~ ~+.~.-.~..-...+.~..~..~-....~...~..~-.~.......~...,-~+-.+++.~......~-~..+~... ~++.+--+~..+--.-4..+++++-+-++~-+-+++-~..++++- ~-+~.~+-+~-~ ~-+-. -+++~d ?+++- +~%--~.... ?'i'++-"T~t't- -'~'~"~m' .~..t- ~ ~ ! ~ :~ q ~ : : ;~ ~ ~ : : -~ ~- :~ :-: : : ' ; : : : ~ ' ~ ~ ~4 '~ -~ 4-4- '~-~ , ~" ~" '%-%-% .... "T'T~-T' ~'T'?T'?' "T' "%-%- "~T'T r , : T~-'J ?: ~ t · ,-~ ~"T'~-' "%~"~?" '~"~'T. ; : ~ . ~ ~ ~r , : ; ~..~ ....... $.~..~..~..~ ................. ,...~...,.~...~ ........... ~.~J ................ ~..~..~ ........ ~..~..~...,.~ ~_~..~ ............... , ......... ,..~..~.....~...,..~ ......... ,...,.~_~ ........ ~_~_.,.]..~..~..4......,...,..~...,..- ~ ' ' i ! ~ i ! i i i i i · i i : ~ i i ~ ~ ~ ~ ~ ~ ~ ! i i i i i iiL t i ~ ~ ~ ~ ~ i ~ : : i ~ i; I i I : i~iI 'i~i ,-+-~-,.-~q.-~-?-t-~-?-?-~,.-?-t--?-?-+-+, -??-?~q-?-?~-?- -'?-~-??~"~'"? ~-~-~'--t"?'~'-~'-?" '?+'++-. -?'+"~"-~ ...... ?'-?'+'q'T -~"~-~,4.,?. ,-?- ~-~-J.-~.-~.~-~..~4.~.-Jq--i.-~6.~..~..J..~..+J-~-6J-~..~..-.%iq..~-~-~q-q~ ~ ~q.-J.~--,~-.~q... -~..-~ ...... L~q.-~..~.--~qq..~--qq-J-~..-..~-~ ~-~-~-+.+.+-+.4-.-~-~-+-~-4-~-+--~..~.-4-.4.q ~-4-.+4-4.-~q..++-~--+-+-+-+--~+-++-- ~-+-+.+--~-+-+-~4.-- .-+-4.q--4--- .4--~-+.-~ ...... ~...+-+-~.., ,~"-~-+'+--'+'+'~'"~ ...... +"~'"~"'r"~ · ~..~. ~ ~ ~-~.~.4-..~-q ~ ~-..~...~...{...~.4, ~ ~-4-~..~-~.-~-4.-~-~.-+-.~-- -+-~..+4.--~-.~-~-4-+..- ++--+-4.-- --+4.-+-~..- .-+--~.-+.+-- 4..+.~...~ ...... ~...+,.+..?....+.+,.{..~ ....... +,.~...+ .......... ~..+,i..,~.- .... / . . , ~ ........ ~ ....... -- .. '..~, ' '-.... ' 4..~. ~-, '- ~ ............... · . 4..~..~ ....... $..~.- ..-~ ...... *.--~.*~..*~--~ -?~?.?.?~-?..?.?~-~...?~...~..~-?.+.-?-~..~..?.~..~-~.**~,.?*?~,..~ , ~ .?-~ ~. ~ ~ .?.?-?.~..-..~..?..?.?.. ,.~.,.~.?.?. ,~ ~..~ ~ . ~ . ~ , ++.+4-.~4-~--~--, q.4-~-4---~-~---~ ..... F~.44---,4-~4--+-.--~+.~-~ ~-+?--~-~ -+~.-??.-,-??~..+-.,-+-+-+?-~..+-+-+.+.. ?+?+.+.- .-'?~'~"i---d'"~"~"'~"" '-'~"'~-?d"' -~--~..~-.~..~-~.-~.-~...~--....~.-.;..-~-.-L..~-~--~..-~..~,-, --~--~-~-~-.-..-~-~-~---~-.-~-~.-~-~-..~--~-- .4-~-~--~---,..~.~..~..-~.--~..~...~..~.-L..+.-~...;..~...~... F,-~.-.L--.L--~ ...... ~-.-~..~..+.-,---~-.+.+.~ ....... ~...~,.-~--+.' ~-~q-4.4-4-~--~---~-..-~..~--~---~-4q-~,.~-4 ....... k~-.~4..`.`..~q-~.-,~.~.4--.~++.~`..4.4-~....~-~..~-~...~.4...~..~.~...~-~..~..~-.~ ...... ~--.~.4..-~ ...... ~-4-~.4--,...~..~-+4.....4-.~..~..,~... ~-~+~q..~-.~-~-. ~-~..~-~...~-~-~- ,.+~-~-~-~ =~ ~ ~ ~=: ~ ~--~--,-~-~.~----~.-~,~-~ -~; ~-~.- ~ ~ ;-; 4 ...... ;...~-+.~-.-+-++..~-.-~..,~,.+.+.~ ...... ~--,~.-+.+., . . , .~_+.+.?~..,..?+..?~.+.+.+.+.+..+~+.+.+.....~+++.....+~.+.+..~?.+~..~.~'''' ........ ~ ~..~..~..-...~...~..~..~...L~..~..~...~..~...L.L.~ ...... L.L..L~ ...... L.L..LL......L.L~...~ ....... ~...~...~..4... -~--~+4--+~-~-+.+-...~-+.4qq..+.+4.4...~..4..+.~.`..4~-~.-~-~-.~-~-`...~-~...~-~....-~...~-~...~"....~..~..~..~... ]...~.-.~...L..~ ....... ~...~...~,..~ ....... ~..4..~..~,.-..4..4..~..4 ....... ?~...~...~-. ~-+-~4-~-+~---~-+4--4-~-++-4-.-,-4-~4q-,-44'~--~ ~ ~ ,-~-~..~-~...,.~ ~ ~-.-~-Li~.-.,-~..~-.~-.~ ..... L..~..~..~ ..... ~.-~-~..~---.-~-~..4-~-.....-~..~-~-~... ~-~'" '~-'~-~-~-' "~'?~"'T- ~"T'T'~-T" "~ '-~"TT' ~'~ ,'~- .... ~...~-~-~......~...~-4..,4 ..... ~..4.,.~..~.., -.........~.,,~-....~..~.,~.-4 ...... ~...~,..' ,~-+?+--..~.~,~ .......... ,...~...+...~... -?.??..-~-- -~-~...~-..,.~?.~..?..- ~.-~ ......... ~-.-~-,-~.--~ ....... ~'-'~...~ ........ ~"'?~'", ....... ~"'r'~-?' "~ .... ~qd"'? ~-T-'~"~-' ?'?"?'"?'"T'~'T'T" ?'T"T-T~"?'Td-T-' "T'T?? "~-~'"~? "~"??~"-'d'-?'~d ' ........ ~ ' ~ ~ ~ -l-~-~i.. d--i'-i-~--'-~d-~-'f-~?'~-+'+--"~--%'-~-4~+'+'-?+'~-+'~"+'++~--"++++'~-~'~-4-4"-~++4-+--~.-4-+.+-.~ ...... ~'.+.+-+..~-.+-+-+-'~-"-?~"~-+" ~"++'t"+- ~-.~-~-~-~..4.-~.-~..~-. -.~..-~-~-~...~-~ .-~--~..~-- ...~-~.~ ~-.+-~- ~...~--~- -~-~--~.-~-~-~-~,-.~-~ ...... ~_~...~...~...~_~.,.~..~...~._ _~..~..~_~..~...~...~,,.~-~ ....... ~,,,~...~...~..., ...~...~..~ ,W...~, 4 ,,J...~ ..,~ ...... ~..-~.-.~,,,~ d..~i...f..i.~?d......f.~d...~..i?.H.+-..i....?..H.i..~..~d...b.i-H...~..id...H...~ ....... H"'H't"H"'H ....... H"~"'~'t'i'-H"'~ ....... .'"H"~ ........ ?"H"'~'" ...~.-.f??..r~-?-r'~ -8000 -6000 -4000 -2000 0 2000 4000 S000 8000 ERST WELL' ' ( 957' 3H-22 FNL, 282 ' FWL, SEC 12, T12N, R8E, UM) VERTICAL PROJECTION -4000 -2000 0 0 Z000 4000 6000 8000 !0000 !2000 i i ~ i ' i i i i i i i i i i i i ; : i : .... T ?"1."1.'" ~ ? !' :t i ? 'T ?".'?'"'Fl'"'?'"-7'1. ? ; ,'-~' ?"? .... ~'? ; +"',' ? ','":' ~' "/'7'"?'"? ...... ?'"¥'l"'?'" -?--?:.?-t..-~-??-r-~--t-.-r. -?.---t--? .... ?+".+'"?'" "?.4"'+"+-. -'4-+'--+.-* ..... .'i-.+- .-i-+-- -.+--+'-P; '+ ..... +".+'"';".4-' i"'+'"+'.4"+" ""~".+'"+"+"('"+'"+"'+'"+ ....... i'-+"+--'+ ...... +.'.+'"i'"+ ...... +'"+'?.+-" '"+'"*."+",~'" '.4..-.+.-,...+~. ~ , ..... +.--+..+-.4.--.,,: , --i---+--?--i--,: , ~ 'i'"'+'-4'"';'"+:: ~ , ....... ?, .+..4..4-1..4,-..;..4..4.-.:: , ~ ~ i ~ ' ..}..-}---~.4--.I.-.-}..4..4--.}-~ ~ ~ ~ } ! i ~ ..4-}-4..4...! ~ ~ ~ I-}'";'-4."4'-~ ~ ~ { ....4...4.4..4~ ~ ~ ~ ...... }.4....~...,,~ ~ ~ ~ ...... 4,..4....~..4~:: ~ ...... J...,~..4...4~ ~ ~ ~ ...... t-~.-i--f-'f-t-.-5-i--??..?i---?.-+-4.-+--f--i-.--?+.-~-~,~h~-.~-.- t-..~-..;:.--+--+-.f.-+--'+.-.b-+" .--+--..*.'..3-+.. k.~-..~--.+-..4..-..4-.+.+..i.-+--.~..-*~-..~-+ ...... f.-f.-f-+-+-.+...¢...{..+.....7"..-~...4..3 ...... L.i'4-4'-'4'"i'" ..-~....i.--4.---.~i I ~ i ~ ~¢"4"4"'} ...... 1 ~ ~ ~!*--.4....4,..¢ ........ !~.~i[~1~ ~ ! 1 !' ' ' ' 4.--~.~...~... ¢--4.-..4..--;...;~ ..... 1 4.'"4.'"4.'"¢ ..... ...... ~....4..-.4.---4...-~....4.-..4....,i...} ..... }...4....4..-*...1~..4.-.;.-.i..-x ...... ;...;...;...4. .... ....... ;...¢..~;....:i ...... ~'"-;i } .4 - ¢ .--~. } .} · ~"++-i-i"i-+'+'.+'" -+'"+-+'~"'~"+'+e-+-"'4."+'.+".+--~'"i-+o n-m~-~.+.-.~-.+.-+-..+--+...t.+--+...+..+--t-+--+-+...*-.-+--+..?.'.+-t-+--+-+.-+ ..... +--.+.--+--+ ...... +--4...+...+ ....... ,..+..+-?,..-f...+...+..+- ....'-4---4-.4.--7t.'-.4.4.,4,-4- ........ .-4--~.-4--4 ..... -[ 4.--4---4.--4..--..... -.4.--4--4.-4.-t~..4..--.+-..~--."~: --.4....4--J,-~-......~....$..-4.--4.-.. ~;"4'"4"4"'41: i'~-4'"4-4""$'- ............. --4.-.4--4-.4 ..... +.-.*-4--4-- ...~,-.-~.4.-4-- .-4---,;--.4....~. ...... ;...4...4..4...i ""~"'~"-~--4' ' ~"i-?'?7i?? .... ~"?"?'T'T"?!'"? ..... .:*."i'-'..;"T".t'?"t"'??~i~?"t"?"!"!-'.?"T"F"";.'-T-';.'?'"T";: ....... Ft'?'i"".."-t ..... r'T"t"~ ....... !'"?t'".? ....... r"t'";"*...' ....... ?'t"'~"' --Y'-+-+"i +-+-+-.+- k-?f-++- ..-*-.¥--*.-+- .-+.+--+- .-+ -.+-+---.~; .... ~.~---~: --~.--.~-4..+.4-,. ,-4..4.-+-+- ..+-+-+- i .... ., ..-.~.-..~ ..4-4-;.4.........'..$4.-½- _.}-..~..4..4.....-~..4,....4._ ?+'-4.4--.4-,..'.44..-...4q-+.4.- ..4.4.4..4.....4..4...~-.~ ...... ~.-~..-~.-4.." ...... ~...~.4-¢-...~....~....~.-i.--...4-4.--~-~ 4..?...*...'-~4-..'4 .... ! .+...i.4- -;...+.-i..' ..... '-'-.7:.-+ ....... ~--i.. '.-i; ........ :...i.-.r.,. -f..;"f'±'i--'-,+-'i-i"!--d-i'?i"!"i-'i'-i?' 'i'i-i-'i"-'i---hhf ..... f'i.-i---f ....... f--...*-.::-+--~'-+~i-~k21 ..... i'-'f--';---!- -i"'h?f ...... i-'i'7i'"'--i'?i-i--' -.Jk4.--i---!---~---~-4.-.~------i---i-4..4--'...4.-4.--i---i--4.-4---~-4...i.4...k:~..~ ...... ki..4.4 ....... L.L4...~ ....... L.LL-~-.-ki.-.i.-~ r¢-~.~.-4..-..-i---~..4..-¢ ..-~-.~--4--4-,.¢.4.-.4.-.{---.-4-.-¢q.-- --h-t--?f.---..*--..~?+--.4...i.-~--~ ....... t~.~.-..,.- .-~--77'-±-~--+++.~ ...... :*>-+-.~-{-.+-~..+H ..... .;:-.-~-+.-~..~--?'-.-i-+.-i-. "-~-+H'a ~--t-+-;..+.+.1.'-+-- ..1.'~-.*~...,~--~.--e~-+±--.-t-1-~-.4.- ?"~'?"1-~-*'"1-t"+'"-.4--~-~.~ ...... ~.-?i---?- "?i'"~"?t.4'"*'.4'"+'"' '"+'".*"'+"+- -+-+".+'"+ ..... ?'"'+"'+".+"-~-*'"'+'"+"'+"- '-7'-7"~?~ ~.+-+'" ~"1-?+'.+ ...... ?'+"?.+'"q ".+,'"+~"-~"~ --4-k+.+...--4---+.-~--~--.4...'?-.+-.4 ....... *..+.-I :~ "' ' ' 'lgFIFID~"4-'."'"4"4 ....... 4-.-~--¥4 ....... +'---.*..4-.4-.-..-.;-}.--}--4.., '1'"¥4-}'"'["'i ~'~:'":*.'~"~"4'"*" ' ...... +.-4-.-i...4-..-.-4..-.+-4-..I...'...+-. L-.*.-.+~ ~ ........ ~ ~.-.~ ......... -~ -~ *-..+..-1- --,-.4-4-.+ ..... ,.--~-..+.-+----+.+-4-.+.-..-+..4----~--!--.+-+-4.+-4.4-.4..4-..+ .... +...+,.4-.+..~..+..+--+.4- .-,-+"..+..+J-.+.4.+.~..--+...~.-+J,.~..~.l~'~nn J-i ..... +..+..+...~ .... +-.-f-.4-k. - ..4.--,'.-.f4.-, ~½'"I'-~'!, i ~ -4'-'L'4"4--~ ~ ~ : -4....;.4-.4.-~ ~ ! ~ --P-~.-i~&,.~ ~ : ~ ~i'"'i-4'"'J'"'-~Jr4'-}-4'-}'"~ ~ ~ } i ~ ~ ..-~."-~..4--~: ~ ~ i ~ .4-4-.~4...i~ ~ ~ i , .-.4-"4-4..4-., ~ ~ i ,~r-}'.4-&'4-~i ~ -4..4--;.-4~, ~ i ...... ~"'~-'-~ ~ s ~ F'J~' '~"'4':,: , ..... ~---~-½'"~,,,, ...... }"-+-4-4-~._~ -t-.'-~'-_~ ?'" · "f" ,'f-7-7'- "'f'-T"-f.."1"- -i'"1.'~..-1'-" ---f-'1''-' .~,~t,t-!'"?-I'"1."I'"' "-f:'"'?"'* ....... -t,---t.-?T-'] ---t.---T'1.'-1.-,--t.--,-'-.-m~- ;-.~--t-?-?-'-'-?.--1-?"~..'-' '-?"T'"f-?- ""?1'-"f.' '":* ....... ?-:*'"1'"1. ...... T"t'-?'1"' "l-1.'"~r"?''' '-h~I--i.:..-¢*....'"i ..... 7!:'"i-"?'f-~' :"i"?"?!i!-?'t'~E R~-!'¢ ~"~-~'¢ E'¢~i't i-O'S'"":-?'%? '"~-h?"~?'?"'.:. ...... ?t?'-t- '-Ti-?-t'- 4..4...~....~-.-;.'...i..4..-}.-....4...i..4..4......4.-4...¢....~.:. ,~.-4.-.~.--4-t-.4---44;'-.~ ...... }...i....Lm..q...~_4'._4..~... -;.4..4-4... i..4...&+..I......4...!....i~4 ...... }-..~-..;~...4.---4.-4---4.-4 ....... 4-.4...4...¢....-¢.--!..4--4..- ..4.~...i...4 · 4..4-?*.-..4;-.4;..-?-4-...?.?..4..., ...... ..-4..-.~.~....??...¢..4...~..4.4.4.4.....4...4.¥-.*...~...¥.+'.4-,-....4..4..4.4.-.,-~..-~--+.4.....4...+..4..?......?..4.-?..?-?,-,'--? ....... ~...,....~...? [..4...~...?.~.....4-,...+...¢.. --4--4-4.4..-. .............. .-i-}..4..4....-.4.-}.-4..-} .....~ 4~'4'" = '~'~ i'-,.-4...}..-:..4.,. .......... ..4..-;..-}-4.-..-4-..}... .*',1'4'"' .W...~4..4 ...... ..... ~...4 ..... 1'~' ....{ }..-;-.4~: :7 ......... 4.-*..4..4 .... .... ?:..4-}-~.- ....... -4-4---~..4.1 ...... .~' '''½''':1I ...... }-"~'~'-'"-"' ..4...'t ~ ......~ }'"' ~,--4. ..... *--*--~--'- '-4.--*---, ..... *.' ~ .' .... ' ' ' ' ~ ' ~ ...... ~ ........ * ' ' * ' ' '-* ....... *-I-~ ..... 4-.., .... ............ :,,, ,,~'? ~.,,,,,*...~ nnnn~t ??--?t..,.~?7.? ?'T'?',-'?t,"'?"'~,~, ..... ..,,,, ,,,,,,,,, ,..?f.?..+.+..+..,_r..4...,_+..+...+++.+....~..+..+-~ ...... ~..++.4..._,...+..+.4......i...i..4._; ..... ~...,...7..-~ ..... L.4...L..}... .... .-¢-~-.~-.-ki 4-..~4.-4---+:--.~.-4.4-.+4....~."-. .4.-.+..++-.--+-4--4---+.--¢--4--4--.~--~ ...... 4.-4...P;---~ +4;.-4.-4-.-.-4--4..4;-..~---4--.*-4.-4.......i.4...~...i-.-.*.-4...+..-+ ....... f4.-1...-t ........ · -+-4---.~--1.".-~...*;.-i'.-+.+-i--+--;.:..+-+--.-i.-+--..~- "+'+'+'+~'"'+"'.:'"+'~ ....... ~"+'+"~ ..... +"++'+"' !'-;.:-'.*.'"'+"3'" -h+'+"~ ...... k+'+'-~ ...... ¢-.+"-'~'"i"-'"4-'}'.4'4."~ i i~ztl i . . . ...-1-f-f.1'... ?'~?fi"'i-?.+..- ??'??" d"i"'~' '++'.4'+-".4-.4-.4--.+ ....... +-.4'-+.4 ....... +"+++-' :-+'-t++'-+'-~-+'?-+.+--+-~'-'"1'--:--'7-"7""-$'+",:"i ....... *'-~'-~"'~ ...... .,...,..., .......... -* ............. ~ ................... ...,..~ ...... ........................................................... 4._.* ............ ~ .......... , ........... ,._4. ................ ,..., ....... ..+_?,.., .... · 'i"+"f".+ ....... *-'1-+"'*.' ....... +...+.-4-.+.- ..i...+_f..+.-4.--i-..,;..$-- ..+--.;-.4-.+"-'.--.~.--.;--4-4.-],...~:.-4.-4..-; ....... ~.4....~..4-..t..4.-.~....k; ...... ~.-.;..-.~...+".....-;...~.4..~-. 4..-~...;....;.....-.~...~-.-.~...4 ....... .;.-;.-.~.4-..-~.4.4...k~'"~-f"~t'"'"l'":*"i'"'"' ' ....... .... ......... ...... 'i ................ -h1.-.~-:.; ....... H'-4--+--?4--H'-4"t'-4'++-.+.'---i--?".'.4'--,:'-4d--4--:*:'.--~---~: ..... .+"--':---,:....~ ...... 6--.~4..¥--.,~-.k+.4.-.f--4;.-4-+-~-..-4.-.:-++-F4.-++--,'.- -'+'"H--4 ..... H'"f'-h' '++'1.-4- -t--m-,- '=-'?-..-r--m'~-1'--F~-~'-~-'1."- -':-:*'m ..-~ '-?..--?.-.t ...... t-~-??----?'?"*"1'-~-*"~'"L:"?m--."1'--,*'-r"?~'-t' .-,?"? -r..--r'-t--r-'-'+-?,'"t-t"-t"l'-,-m~-1'"','"..'-1."- ,~. '--}-..-.-i.-~--4.-4- -..+-4--4..-4.-4;--.4.-4..4-..4......4.-4.--4-..4..4 .-J..4...-4-..~- ...... 4.---4.-.J,..4 ..... }--4--}-4..-. ,-4..4-4-.4..-J -4---;-4.-;- .--*...4...4--4---4.-4-4-4..- -.-~--.+.-.~.--4..- ;'"~'4."4.".+'"4 ..-4..-.*-..;..4...q -.~...L..+-.+... -t..-,..-?-i ...... 7..-7---?k.---m.-?..1'-q--1'-?--1.---~ ...... i'--~'--t'-: ...... ~.--~-4-..~ ....... ~.--.~---~.4 ...... ~.~4~..~4~.~k;~i~;~i~i~+.~¥+-~.`*~4 ...... ~"i"+"? ....... ?'".+"+"!'"t'"~'"f'"I'"¥'l'"i"';'"+'"? "T"f"fl ....... 7:.--t'i'"?--t'i"'i"?'T'!'"?'f ...... h'.~trf~-f"f"f ....... f"';'"'?i'"'"i"i'"f'+..'''''''?'f''f''f'''~''+''..*.'''ti''''-?.''''f'i-'i ....... t"i'-i'"f ....... t"~'"'.."!"'t"';'"';'"'.;'"t ...... t"t'" "~"'~'"?'i'"t'"c' -Jr.-e-*-+.-.H--+-i'-?....+.-+-.+'-+--~"+'+.4.-+ ...... +-++-+-.---+.4.-+.--+ ....... +-.4---+-+.---.+--.+-f--+ ..... +-.+-.-+--+--.4-+-.+.--.~-.+-. !-+-1-+"i"'-"+".+"+"~ ....... +'"f'i"1. ....... r"f'-f"f ...... f"?'f'i"'t"'7"'f'"t"'?'" -4..4..4-..~,- -..;...~..4..4-..-4..4..4...,~.....4..4-;.-.; ..... ~J,..-;..4-.- ..4.-.;.-.}.--~....-}...;...:;-4-- .-4-';.4.4.-.. -4-;-4--4-.4 -.;...;..4..4-. ~-;-..4.-4...*... -.4-4...~,...4..- ...4...~...~...4. ....... 4....~...~...f ...... ~...*...4...+.4 ...~...*...~...~... --t-'i--?'"+ ...... +-??"+--'-I"-T-~-?]L?.+'.4-+ .... *--*-*--~".! '.+-+.-+.-.+--.' '-'6"*"'6"*"-'-+-"+--i--r"~ -+--.+-'+'-+-'1 -!:--.+---?-+- --r. --?..1.-? ....... 't...!..-,---,......?..!..-,.-., ....... l'"r"?'"? ...... %'+'-?"?" "1'"'+'"?"1.'" --$..4;--4:--.+.- ,..+.-".,.4.'....*--.-+--+-F~---:--+-4.-~-4;- .-4..4;.---:4---, .--F-$-4--4--Fh .-F-~4- -4-.*-~--~--4-~- .4--. -k-1-~-i-,-4.'...4-+.4-. -~-F4.-.+'--}.-+-4;-.4. ....... +..4;.-+.4 .... +.-.~---,.'-+.- .-+4--.f-f..- -~...~...~-.~.-.......................... ,-.*..4--~-..4...- ,-.4.-4--~...4 ....... ~-.4,..4,..4 ...... 4...4.,..4...4.,....4...4.,..~..4 ..... ~..-~..1-.4....-~-.4..-~-4.-~i ...................... -4-~..4,.~... -.~...4.-~-.~... ,....,..~...4..4 ....... 4..4-4....~.,. ,..4,,.4...~,..~ ....... 4..-~...~,.4, ..... ..... ~,..~,..~ ......... 7 '~, ? ...... ~'"~"', -4-..'-~..4-,...;.4..-i..4-,..4.4..4...}-,.-4..4...~....~-.. -4..-L..}.-4-.~ ,.4-'.. ' ;.., ..4-4-.' .' ..... ! 4 -W~~ '- ' 4..4,.. ,4..4-4..4,,. ,.-;...;--~-~-.-.4--L.;...~-...4...~...}...} ....... }..-~.,4,4... [..4...~..4-4. ...... ~...~...l...~'... · . ........ · .~-.~ ~.~. . ~ -~-~- ................ ~--~, -t.---r-- ~--t-7--T-1'- -I-..1'-1'..-:*..-.--%1.---r-.:*- -*..-1.--*..-r-t -t-~ ~ ~ i ---t-~,- t ~.:: i i ..-I- .'r---t,- '-r'.. -, ,*--T',',',',',',~- ~"-1--..'r-t..-?-.-.1.-F--r-?-' '-~.--t..--~'--r- ---r-T'1.--'~ ...... !'--r'-..*"'r'-~'"r'1.'--r'-r-- -~-~-.*-..-+-+-++---.4-.4.-+.e ..... i-+-+.-.+- -e~e~,i, wn .~+....*.4-.'-4~."..-~.'--~..4-+.'-+-t- ~-~--+-.+-+-+---+.-+..+-4 .... ,:-.+-+..4....+.4...+...f ...... +..+..+...+ ....... +-.+..4...+-...4...+...+...,.'... · ~ ! - -,e--.~-..e--~,....i I i i -"~'"+'"+'"~ ~ ~ ~ ..... .~..~,..-e...~.~.i: ~ ~ :-'e-"~"+"'et ~ ~ ~ .... .~-*--4,-: i ~ 4.-~ -4.-~ e.--,,-l.f ~ , .-4~ ~ -! ~ ~ I f ~"t --~"'*""~: ~ -.~.-.,: .-+-.-4--.-~....,: i ' ~ ~'~-'~'"'~'""! ~ ' ~ ~'""'"'"'~'"'! ~ ~ i '"*"-~'"'~'"'*~: ! ~ ....... *'"~'"~'""~ -i'"7'"' "-r..'"t":*'-?'- '-r-r-t."-f "1.' ..'ff-f-'ff-'--':*'--.*;-¢i ....... f-?---f-7'-'-F-f"1-f-ff .'?+--f-f- ~-f..'"-.+"- -f-*.:-1-1- -'-1-r-h?'-'1.-"1-f'-'.': ...... 7-:"-t"1' ....... f"f'"F'T ....... r'f'-ff--'r ...... r"T"?"~ .... --i-.+..+-f- -+--f-f.-+- "'i-+-f-f.'-l-f'*:".+-+.--*'-f'-+"-h; '-...-.+~.'- .,b-f- i-.+.4-,.+--?'-1-f..' .-4-¥+~ .-+..4..4.4.-- ---+.--+-4-..+--.--.h.+-~-+ ..... ~;.-H-....-P.+- -.+..+...?..? ....... +-'?r'i ...... .+".+'-+'.4"' "'1-?'-+'"f .... -.~..J~}...} ...... .~....*...4....}-.....4.-~....4...4...4.....4.-.~...-}._; ..... ;..4-.}-4.~ ...4.-4,...}..4 ...... }...;..4...;-4...}-.;.-}...}..- -4-.+-4...}.-_..L..4....~,....~_.....-~..4..4..4....I....~.4...4....¥- ....~...¥..~...~....~...4....+...?...+ ...... .f-.~...;...+ ...... +...+...+...+ .... +i44..-:-4.-{---!..+----4-4.4-..+ ......~ H--4---h.+4+4 ....... Li---&-4 ....... &--+..-Li ....... H--H---4--i+i..-. +.H.+----++H ......~ +--H..-h.-+'-H"'¢..'FH"+'"+ ...... i'--H...H"4'-.H --*"-~*"~'m -?~'?"f'"* ..... ~'"?"?-'?'~-?-%~'?'"*--' "~-~"'*~.'" '--*--+".+'~.' ...... +.'?'-+-'.+ ...... +--*--?r" "'+'.+'"??' "*'"*'"*'-2'"' "~.--'r'"r~. "T?"?'r"? ..... T"T'w'"?'"'~'''?''r '?'"~ ....... ??"~:'"?"T''?'''*'''T''? .... , · . : : : : . . ; : : : : : : : : : : : : : : : , : : : : : t ~ : : : ' : : : : 4. 4. 4 ~'"r:'"f'"~'-i "'T~"'T"'~"' "i-FI'"I'-i"T'T"T"? ....... T't"'?T" "-t'"'F'r1.'" -'..'--r'-r-1'- '"1'"'r-T'-T" ""?'r'T"T'?'T"??"T'" -'i'-F'T"T"'f'"?FT"? ..... !"'?'T'"?"'!'"m'";-'? ....... ~"';'"..'." "~"?"?:?"~"'?"t"?~'"?"m'"~"l'"¥'¥?'? ....... ~tl::;nr~t-jt'-t'"t'i ....... t-'~'"~'"~ ....... t'-t"'.¥'? ....... '"'f'?'"?"l"'¥'?"T"? ....... ?'"'.."'"m"T"?".~-T"? ..... ;'"'¥'?'";"T";'"'?'? ...... ?'?"'~"T"~"T'!'";' .... PROJECTION ON VERTICAL PLANE S. - IB~. SCALED IN VERTICAL OEPTHS HORIZ SCALE = 1/2000 IN/FT -"-~, STATE OF ALASKA ~-' ALAS, OIL AND GAS CONSERVATION COMI. .SION 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 Po0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 957' FNL, 282' FWL, Sec.12, T12N, R8E, UM At top of productive interval 800' FSL, 2364' FWL, Sec.35, T13N, R8E, UM At effective depth 1032' FSL, 2368' FWL, 5ec.35, T13N, R8E, UM At total depth 1241' FSL, 2370' FWL, 5ec.35, T13N, R8E, UN 11. Present well condition summary Total depth: measured 10234'MD true vertical 6378'TVD Effective depth: measured 9970 'MD true vertical 6217 ' TVD Casing Length Size Conductor 80 ' 16" Surface 4313 ' 9-5/8" Producti on 10017 ' 7" 5. Datum elevation (DF or KB) RKB 76 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3H-22 8. Approval number 8-226 9. APl number 50-- 103-20097 10. Pool Kuparuk River Oil Pool Feet feet Plugs (measured) None feet feet Junk (measured) None feet Cemented Measured depth 250 sx A5 I 115'HD 1500 sx AS III & 4348'MD 500 sx Class G 1280 sx Class G & 10052'MD 175 sx AS I Rue Vertical depth 115'TVD 3127'TVD 6267'TVD Perforation depth: measured 9754'-9774'MD true vertical 6085 ' -6097 'TVD 12. Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ¢ 9606' Packers and SSSV (type and measured depth) HRP-1 pkr @ 9531' & TRDP-1A-SSA 55SV @ 1789' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Compl. We..11 Hi story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associate Enqi neer (Dani) SW03/82 Date 5- · Submit in Duplicate~ ARCO Oil ~.,,d Gas Company Daily Well History-Final Report ? Instructiolls: 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. Accounting cost center code District ICounty or Parish State ARCO Alaska, Inc. I NORTH SLOPE-KU?ARUK AK Field iILease or Unit I Well no. KUPARUK RIVER FIELD I ADL: 25523 3H-22 l ittle I COMPLETION Auth. or W.O. no. AK2653 Operator l A.R.Co. W.I. ARCO I 55.8533 Spudded or W.O. begun ~Date ACCEPT I 04/19/88 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prlor status if e W.O. I 0730 ERS Date and depth as of 8:00 a.m. 04/27/88 ( TD:10234 PB:10234 SUPV:SC/WM Complete record for each day repo~ed NORDIC 1 - ~ ) RELEASED/RIG 7"@10052' HW: 0,0 RAN-o~'~'7'Z'' COH?LETION ASSEHBL¥ WITH TAIL @ 9606', SSSV @ 1789', PKR @ 9531'. TESTED TOEING TO 2500 PSI - OK. ND BOPE. NO TREE & TESTED TO 5000 PSI. DISPLACED WELL WITH 360 BBLS DIESEL. SET BPV. SECURED WELL & RELEASED RIG @ 2400 HRS, 4/26/88. DAILY:S144,045 CUM:$1,531,399 ETD:S1,531,399 EFC:$1,670,000 Old TD New TD PB Depth Released rig Date K nd of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method I Official reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest 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 ~'- 4-__F~ AS~3ClATE ENGINEER For form preparati~Jand distribution, see Procedures M{l~l~ual, Section 10, Drilling, Pages 86'~ind 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage no. Dlvtaion of AtlantlcRIchfleldCompan¥ ARCO Oil and Gas Company 4~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnl®rim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District IIC°unty or Parish IState ARCO Alaska, Inc. ~ NORTH SLOPE-KUPARUK AK Field ILeaso or Unit [Well no. KUPARUK RIVER FIELD I 3H-22 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. NORDIC 1 The above is correct TO RUN COMPLETION ASSEMBLY. DAILY:S84,033 CUM:$1,387,354 ETD:S1,387,354 EFC:$1,670,000 For form preparation.~lnd distribution see Procedures Maq~l Section tO, Drilling, Pages 86 a~ 87 AR3B-459-2-B IDate ITitle ,5'-4-~ A~OClATE ENGINEER INumber all daily well history forms consecutively IPage no. as they are prepared for each well. I ARCO Oil an~. 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 ere started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District County, parish or borough State ARCO Alaska, Inc. I NORTH SLOPE-KUFARUK AK Field ILease or Unit KUPARUK RIVER FIELD I ADL: 25523 3H-22 Auth. or W.O. no. ITme AK2653 I COMPLETION API: 50-103-20097 Operator I^RCO W.I. lWell no. ~CO Spudded or W.O. begun IDate IHour ACCEPT 04/19/88 0730 Date and depth Complete record for each day reported aa of 8:00 a.m. NORDIC 1 ) 55.8533 Prior status if · w.o. 04/20/88 ( TD:10234 PB:10234 SUPV:DL 04/21/88 ( TD:10234 PB:10234 SUPV:SC/WM 04/22/88 ( TD:10234 PB:10234 SOPV:SC/WM 04/23/88 TD:10234 PB:10234 SUPV:SC/WM 04/24/88 ( TD:10234 PB:10234 SUPV:SC/WM 04/25/88 ( TD:10234 PB:10234 SUPV:SC/WM 04/26/88 ( TD:10234 PB:10234 SUPV:SC/WM The above Is correct For form preparetion/~nd distribution, see Procedures Marl~JII, Section 10, Drilling, Pages 86 a~d 87. DRILLING CEMENT @ 8283' 7"@10052' MW:10.0 NaCl/NaBr MIRU. ACCEPT RIG @ 0730 HRS 4/19/88. ND LOWER TREE. NU BOPE AND TEST TO 3500 PSI. LOAD PIPE SHED WITH 3-1/2" DP. RIH WITH 6-1/8" PDC BIT AND BHA TO TOC @ 8192'. DRILLING CEMENT @ 8283'. DAILY:S70,672 CUM:$1,154,915 ETD:S1,154,915 EFC:$1,670,000 POOH WITH MILL 7"@10052' MW:10.1 NaCl/NaBr DRILL CEMENT TO FROM 8283-8295'. POOH. RECOVERED JB FULL OF METAL SHAVINGS AND PIECES OF CHAIN. SLIP AND CUT DRILLING LINE. MU MILL AND 3 JUNK BASKETS. PU JARS AND BUMPER SUB. TIE. MILL ON CEMENT AND JUNK FROM 8295'-8301'. PUMP HI VIS SWEEP. CBU. POOH. DAILY:S25,951 CUM:$1,180,866 ETD:S1,180,866 EFC:$1,670,000 DRILLING CEMENT 7"@10052' MW:10.1 NaCl/NaBr SERVICE RIG. POH WITH MILL. RECOVERED 7 GALLONS OF METAL SHAVINGS AND A DOUBLE HAND FULL OF CHAIN LINKS. NO NOTICEABLE MARKS ON MILL. TEST 7" CASING TO 2500 PSI. TEST 9-5/8" X 7" ANNULUS FROM 500-750 PSI. BLED 7" TO 0 AND 9-5/8" X 7" TO 500 PSI. MU 6-1/8" BIT AND TIH. TAG UP @ 8295". ATTEMPT TO DRILL WITH NO SUCCESS. REVERSE CIRCULATE 2 DP CAPACITIES. DR'ILL CEMENT FROM 8295'-8790'. DAILY:S27,-434 CUM:$1,208,300 ETD:S1,208,300 EFC:$1,670,000 RIH WIT~ BIT 7"@10052' MW:10.1 NaCl/NABR DRILLED CEMENT TO 9083' CIRCULATE BOTTOMS UP. DRILLED CMT TO 9301'. REV. CIRCULATE OUT. POH. TIH WITH BHA. SLIP AND CUT DRILL LINE. TIH WITH BIT. DAILY:S27,295 CUM:$1,235,595 ETD:S1,235,595 EFC:$1,670,000 POH WITH BIT 7"@10052' MW:10.0 NaC1/NABR DRILLED CMT FROM 9301'-9968' POH TO RUN LOGS. DAILY:S34,760 CUM:$1,270,355 ETD:S1,270,355 EFC:$1,670,000 CIRC. & FILTER COMPL. FLUID 7"@10052' MW:10.0 NaCl/NABR POH. RAN CET F/9970'-7962' & GCT F/9970'-SURFACE. RIH. TESTED CASING TO 2600 PSI. CIRCULATE AND FILTER COMPLETION FLUID. DAILY:S32,966 CUM:$1,303,321 ETD:S1,303,321 EFC:$1,670,000 RUN COMPL. ASSY 7"@10052' MW:10.0 NaC1/NABR SERVICED RIG. CIRCULATE AND FILTER COMPLETION FLUID. POH. LD 2000' DP. PULLED WEAR BUSHING. RU SOS. RIH AND PERF 9754'-9774' WITH 4-1/2" GUNS, 4 SPF. RAN GR & JB TO 9752'. RD SOS. T~RTAT.T.~D 2--7/~" RAMR A~D TRST~D TO 3500 PSI. RU Date ] Title 5-4-~3 A~8OCIATE ENGINEER AR3B-459-1-D INumberall daily well history forms consecutively no, as they are prepared for each well. IiPage I ARCO Alaska, Inc. Date: RETURN TO: May 3, 1988 Transmittal #: 7156 ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles 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. Cement Bond Log 4 - 1 9 - 8 8 Cement Evaluation Log 4 - 2 4 - 8 8 6995-9059 7962-9964 Anchorage · .~ If you have any questions concerning this or any other transmittals, please call me at 265-6835. Receipt Acknowledged' DISTRIBUTION: NSK · Drilling Date- State of Alaska(+sepia) ~ STATE OF ALASKA '~. ALAS...~ OIL AND GAS CONSERVATION COM,..,;SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon © Suspend © Operation Shutdown ~ Re-enter suspended well ~ Alter casing CJ Time extension © Change approved program ~ Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 76' feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 957' FNL, 282' FWL, Sec.12, T12N, R8E, UM At top of productive interval 896' FSL, 2449' FWL, Sec.35, T13N, RSE, UM (approx) At effective depth 1037' FSL, 2307' FWL, 5ec.35, T13N, R8E, UM (approx) At total depth 1247' FSL, 2306' FWL, 5ec.35, T13N, R8E~ UM (approx) 11. Present well condition summary Total depth: measured 1 0234 'MD feet Plugs (measured) true vertical 6378 'TVD feet 7. Well number 3H-22 8. Permit number 88-11 9. APl number 50-- 103-20097 10. Pool Kuparuk River Oi] Pool None Effective depth: measured 9970 ' MD feet true vertical feet 621 7 ' TVD Casing Length Size Conductor 80 ' Surface 4313 ' Producti on 1001 7 ' 1 6" 9-5/8" 7" Junk(measured) None Cemented 250 sx AS I 1500 sx AS ill & 500 sx Class G 1280 sx Class G Measured depth 115'HD 4348'MD 10052'MD ~ue Verticaldepth 115'TVD 3125'TVD 6267'TVD Perforation depth: measured None true vertical No ne Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Wel I Hi story Description summary of proposal [] Detailed operations program BOP sketch 13. Estimated date for commencing operation May, 1 988 14. If proposal was verbally approved Name of approver approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ,~j Title Associa~;~ ~ngineer ~ Commission Use Only (Dani) 5A3/68 Conditions of approval Approved by Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI ~,~n: oved Copy Date ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 / NO. Returned Commissioner by order of the commission Date Submit in triplicate ARco Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Repozt" 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 ARCO Alaska, Inc. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK2653 ICounty. parish or borough NORTH SLOPE-KUPARUK Lease or Unit APT,: 25525 Title DRILL I Sta~K 3H-22 no. API: 50-103-20097 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 02/18/88 ( TD: 1030' ( 1 SUPV: JP 02/19/88 ( TD: 2110'( 1 SUPV:JP 02/20/88 ( TD: 3476'( 1 SUPV:JP 02/21/88 ( TD: 4363'( SUPV:JP 02/22/88 ( TD: 4373'( SUPV:JP 02/23/88 ( TD: 5200'( SUPV:JP I ARCO W.I. IPrior status if a IDate IH°ur I 55'8533w.o. 02/17/88 1900 Complete record for each day reported DOYON 14 ) 3O) DRILLING 16"~ 115' MW: 9.0 VIS: 67 MOVE RIG FROM 3H-21 TO 3H-22 WITH 60 STANDS OF DP IN DERRICK. ACCEPT RIG 1100 HRS 2/17/88. SPUD 1900 HRS 2/17/88. NAVIDRILL 12-1/4" HOLE TO 1030'. DAILY:S64,382 CUM:$64,382 ETD:S64,382 EFC:$1,670,000 ) 80) TIH 16"@ 115' MW: 9.1 VIS: 82 DRILLED 12-1/4" HOLE TO 1854'. DROPPED SINGLE SHOT SURVEY. POOH. MU NEW BHA & ORIENT. TIH. NAVI-DRILLED 12-1/4" HOLE TO 2110'; DROPPING ANGLE. POH. MU BHA ~3 & ORIENT. TIH. HIT TIGHT SPOT @ 1939' AND WORK SAME. DAILY:S46,492 CUM:$110,874 ETD:$110,874 EFC:$1,670,000 66) DRILLING 16"@ 115' MW: 9.2 VIS: 94 FINISHED WASHING TO BOTTOM. DRILLED 12-1/4" HOLE TO 2457'. PUMPED SURVEY & MWD SURVEY. POOH AND CHANGED BHA. TIH TO 2200'. REAMED TO 2457'. DRILLED TO 3094'. SHORT TRIP. DRILLED TO 3476'. DAILY:S60,521 CUM:$171,395 ETD:S171,395 EFC:$1,670,000 ) 87) RUNNING 9-5/8" CASING 9-5/8"@ 4348' MW: 9.4 VIS: 90 DRILLED 12-1/4" HOLE TO 4363'. CIRCULATE BOTTOMS UP. SHORT TRIP TO HWDP. CUT DRILL LINE. TIH. CIRCULATE HOLE CLEAN. DROPPED SURVEY AND PUMPED SLUG. POH & LD BHA. RU AND RAN 110 JTS 9-5/8", 36.0#, J-55, BTC CASING WITH SHOE @ 4348'. DAILY:S126,887 CUM:$298,282 ETD:S298,282 EFC:$1,670,000 ) 10) PERFORM LOT 9-5/8"@ 4348' MW: 8.5 VIS: 31 CIRCULATE & CONDITIONED MUD. CMTD 9-5/8" CASING WITH 1500 SX AS III & 500 SX CLASS G. DISPLACED & BUMPED PLUG TO 2000 PSI. FLOATS HELD. FULL RETURNS THROUGHOUT ENTIRE JOB. LD LANDING JT. ND 20" DIVERTER SYSTEM. INSTALLED BRADENHEAD & NU 13-5/8" BOPE. TESTED BOPE (HAROLD HAWKINS, AOGCC, WAIVED WITNESSING THE TEST). INSTALLED WEAR RING. LDDP. MU BHA & TIH. TAGGED FC @ 4267'. TESTED CASING TO 2000 PSI-QK. DRILLED FC, CEMENT, FS AND 10' NEW FORMATION. SWITCHED OTM TO POLYMER MUD. PERFORMED LOT TO 12.5 PPG EMW. DAILY:S128,417 CUM:$426,699 ETD:S426,699 EFC:$1,670,000 27) DRILLING 9-5/8"@ 4348' MW: 8.9 VIS: 32 DRILLED 8-1/2" HOLE TO 4719'. MWD SURVEY AND PUMPED SLUG. POOH. MU BHA ~6. TESTED TURBINE & ORIENTED. TIH. DRILLED 8-1/2" HOLE TO 4738'. CIRCULATED & PUMPED SLUG. POOH. CHANGED TURBINE. TIH. CONTINUED DRILLING 8-1/2" HOLE TO 5200'. DAILY:S48,112 CUM:$474,811 ETD:$474,811 EFC:$1,670,000 The above is correct Signature For form preparation and dts~butlon, see Procedures Manual, Se~_~n 10, Drilling, Pages 86 and 87. A88OCIATEENGINEER ARco Oil and Gas Company ~' Daily Well History--Interim Instructione: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District County or Parish IState ARCO Alaska, Inc. I NORTH SLOPE-KUPARUK Field ILease or Unit IWell no. KUPARUK RIVER FIELD I ADL: 25525 3H-22 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. DOYON 14 02/24/88 ( TD: 7350' ( 2 SUPV: JP 02/25/88 ( TD: 9286'( 1 SUPV:JP 02/26/88 ( TD:10234'( SUPV:RB/SB 02/27/88 ( 1 TD:10234' ( SUPV:RB/SB 02/28/88 TD:10234' ( SUPV:RB/SB 7) 150) DRILLING 9-5/8"@ 4348' MW: 9.1 VIS: 34 DRILLED 8-1/2" HOLE WITH TURBINE FROM 5200'-7350' DAILY:S42,565 CUM:$517,376 ETD:S517,376 EFC:$1,670,000 ) ,36) DRILLING 9-5/8"@ 4348' MW: 9.3 VIS: 34 DRILLED 8-1/2" HOLE TO 7985' PUMPED DRY JOB. POOH TO CASING SHOE. CUT DRLG LINE. RIH. CONTINUED DRILLING 8-1/2" HOLE TO 9286'. DAILY:S46,152 CUM:$563,528 ETD:S563,528 EFC:$1,670,000 948) )) 0) SHORT TRIPPING 9-5/8"@ 4348' MW:10.0 VIS: 40 DRILLED 8-1/2" HOLE TO 10234' TOOK MWD SURVEY. PUMPED DRY JOB. POOH FOR SHORT TRIP TO SHOE. DAILY:S54,732 CUM:$618,260 ETD:S618,260 EFC:$1,670,000 RIH AND REAM AT 10084' 7"@10052' MW:10.0 VIS: 38 FINISH SHORT TRIP. CIRCULATE. DROP SURVEY. SPOT DIESEL PILL. POOH. RU SOS AND LOG W/ DIL/GR/SP/SFL F/ 9832' TO 4348' LOG W/ FDC/CNL F/ 9832' TO 4348', 4750' TO 4348'. CAL F/ 9832' TO 4348'. RD SOS. MU BHA AND RIH TO SHOE. CUT DRLG LINE. RIH. DAILY:S67,094 CUM:$685,354 ETD:S685,354 EFC:$1,670,000 CIRC AND COND MUD 7"@10052' MW:10.1 VIS: 44 REAM TO 10234'. CIRC AND SPOT DIESEL PILL. POOH AND LAY DOWN DP. LAY DOWN BHA. RUN 7" CASING W/ PAYZONE PACKER. CIRC. DAILY:S142,005 CUM:$827,359 ETD:S827,359 EFC:$1,670,000 The above is correct Signature I Date For form preparation and distr~,6J~tion see Procedures Manual Sectic(n~/10, Drilling, Pages 86 and 87 ITitle ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Pre~3are 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. I Accounting cost center code District ICounty or Parish State ARCO Alaska, Inc. J NORTH SLOPE-KUPARUK AK Field Ihease orUnit [Well no. KO?AROK RIVER FIELD ADL: 25525 3H-22 Auth. or W.O. no. ITitle AK2653 I DRILL API: 50-103-20097 Operator I A.R.Co. W,I. ARCO J 55.8533 Spudded or W.O. begun J Date SPUD J 02/17/88 02/29/88 ( 1, TD:10234' ( SUPV:RB/SB Date and depth as of 8:00 a.m. Complete record for each day reported DOYON 14 o) I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prlor status If a W,O, I 1900 RIG RELEASED 7"@10052' MW:10.0 VIS: CIRC AND COND MUD. CEMENT 7" W/771 SX OF 50/50 POZ AND 509 SX OF CLASS "G" CMT. CIP AT 1045 HRS 2/28/88. PU BOPS. SET SLIPS. ND AND NU TBG HD. TEST FLANGE. INJECT 60 BBLS DIESEL DOWN 3H-21 AND 3H-22. RIG RELEASED AT 1930 HRS 2/28/88. DAILY:$256,884 CUM:$1,084,243 ETD:S1,084,243 EFC:$1,670,000 Old TD New TD Released rig Date Classifications (oil, gas, etc.) Producing method Potential test data IPB Depth Kind of rig JType completion (single, dual,, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gas Test time Production lOll 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 Signature I Date I Title For form prel3aration and (~"~ribution, see Procedures Manual, S{~tion 10, Drilling, Pages 86 and A~DOIA~ ENGINEER ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 7, 1988 Transmittal # 7109 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. 2" Dual Induction 2-26-88 4344-9824 2" & 5" Raw FDC 2-26-88 4344-9798 2" & 5" Porosity FDC 2-26-88 4344-9798 Cyberlook 2- 26-88 9400-9775 5" Dual Induction 2-26-88 4344-9824 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Franzen D & M State o~: A~aSka(+sepia) Lucille Johnston(vendor pkg.) ARCO Alaska, Inc. is a Subsidiary of Atian.'.icRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March ~, 1988 Transmittal # 7113 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. OH Edit Tape and Listing 2-26-88 #72620 Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany XEROX TELECOPIER 295 ; 2-21-88:8:07 PM; ' 907 659 7464 FROM 987 659 746~ ~ ~ STATE OF ~AS~ OIL f GAS CONSERVATION B,O.F.E. Inspection Report Inspector _ 9072767542 28:13 - ' Location: Sec_'3 Drilling Contractor ft, RepresentattvenB}q.!2k g. ~6[~0[ Lbcation, General General Housekeeping____ Reserve Pit ~U Mud Systems Trip Tank - Pit Cauge Flow--Monitor Gas Detectors Well Sign Visual Audio ACC~JLATOR SYSTEM Cn .~, ~ sure Pressure After Closure [COO Pump ~nar~ clos, pres. 200 pslg. Full Charge Pressure Attained: Controls: Master ~ Blinds switch cover _Ke__~ and Floor Saf~e~ Valves .ROPE Stack Annular Preventer Test Pressure Upper 000 .. ,, e .,_ .,.. :,, Test Pressure Test Pressure Test Pressure Test Pressure Adjustable Chokes ! 0C ~drauic~erated choke Blind Ram~., {___~~~~ Inside BOP Choke Line Yalves ~_~_~_ ZQ~_ Choke Manifold H.C.R. Valve No. Valves Kill Line Valves ~ O~ _ No. flanges Check Valve Test Results: Failures ., Repair or Replacement of fa~led equtpmen, to-be made Co~ission office notified. days and Inspector/ Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor January 29, 1988 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Imc. P. O. Box 100360 ~chorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3H- 22 ARCO Alaska, Inc. Permit No. 88-11 Sur. Loc. 95-7'FNL, 282'FWL, Sec. 12, T12N, R8E, UM. Btmhole Loc. l145'FSL, 2488~FWL, Sec. 35, T13N, RSE, UM. 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 permits 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. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation s° that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ver~, truly:y~ou~s, Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ~- ALASKA OIL AND GAS CONSERVATION 3MMISSION PERMIT TO DRILL 20 AAC 25.0O5 I la. Type of work Drill ,l~ Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test Lq Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone j~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 76', PAD 39' feet Kuparuk River Field Kuparuk River Oil Poe 3. Address 6. Property Designation P.O. Box 100360, Anchorage, AK 99510-0360 ADL 25523 ALK 2559 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 9$7'FNL, 282'FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (~ target) 8. Well nu.mber Number 896'FSL, 2449'FWL, Sec.35, T13N, R8E, UM 3H-22 #8088-26-27 At total depth 9. Approximate spud date Amount l145'FSL, 2488'FWL, Sec.35, T13N, RSE, UM 02/14/88 $500,000 12. Distance to nearest 13. I~il.~t~nlce to nearest well 14. Number of acres in property 15. Prop. osed depth(MD and TVD) property line - 1 0139 'MD 1145'@ TD feet 25' ~ Surface feet 2560 (6312'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAO 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole angle 56 0 Maximum surface 1 845 psig At total depth (TVD) 2958 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) 24" 16" 62.5¢ H-40 Weld 80' 35' 35' 115 115' +200 cf 12-1/4' 9-5/8" 36.0~ J-55 BTC 4351' 35' 35' 4386' 3116' 11~,0 sx AS Iii & HF-E~W 400 sx Class G blend 8-1/2" 7" 26.0¢ J-55 BTC 10105' 34' 34' 10139' 6312' 200 sx Class G(minimu HF-E~W TOC 500' ab(va top of Kuparuk 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 [~ Diverter Sketch [] Drilling program Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements 21. I hereby ce,,r, ttf~ {hat 'the foregoj~g,,is true and correct to the best of my knowledge Signed . .f,¢~/¢,~,_/ Title Regional Drilling Engineer Dat ~_;-// "/' ~'-'~ Commission Use Only (AWM) PD2/70 ,, 9'~ --u 50--~o ~ - z ooq 7- 01/29/88 I for other requirements I Conditions of approval Samples required [] Yes E~¢-I'~o Mud Icg required _Fl Yes Hydrogen sulfide measures [] Yes [~!f'"No Directional survey required Ei~'Yes [] No Required working pressure for B~OPE []2M; J~3M; [] 5M; [] 1OM; [] 15M Other: ~/_~ by order of Approved by i ~/~'"'~*~ ~'~-'~' Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate GENERAL DRILLING PROCEL~,~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install FMC diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" 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 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. 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. ~ 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21'. Secure well and release rig. 22. Fracture stimulate. SHALE _ SHAKERS · -'~DEGASSERI' -'~ STIR~-~' STIR --'~' STIR TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casin~ to Weigh..t Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 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 Drillin~ Fluid Syste~: - 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 using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5/ih~ In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids nacessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by a~ctic PaCk upon completion of the fluid disposal. ~:~' ...... KUPARUK RI VER UNIT 20" D IVERTER SCHEMATIC iJ I. OESCRI PTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD FMC DIVERTER ASSEMBLY WITH TWO 2-1 / 16" 2000 PSI BALL VALVES 4. 20" 2000 PSi DRILLIN8 SPOOL W/10" OUTLETS 5. 1 O" HCR BALL VALVES W/1 O" DIVER'I'ER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER .ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 2 UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 11-3-86 7 6 5 4 3 2 L. DIAGRAM #1 13-5/8" 5000 PSI RSRRA BOP STACK I. 16' - 2000 PSI TA/~ STARTII~ I-lEAD 3. II' - :~300 I:X3! X 13-5/'8' - 50130 PSI SPA(:E~ Sptr~3___ 4. 13-5/8" - 5000 PS! P!PE ~ 5. 15-5/8" - 54:X30 PSI DRILL/NS SPOCL W/O'IOKE ~ KILL LINES 6. 13-5/8" - 5000 PSI DOLeLE RAM W/PIPE ~ ON TOP, ?. 1~-5/8." - 5CX30 PSI AhN~AR A~LAT .(jR CAPACITY TEST I. CI-ECK ~ FILL A(~TOR RESERVOIR TO PROPER LEVEL WITH HYDRALI. IC FLUID. 2. ~ THAT ACCLMJLATI~ ~ IS 30(X) PSI W/TH 1500 PSI ~TREAM 13:' TI-E REGULATDR. 3. OBSERVE TIldE, TFEN CLOSE ALL UNITS SIMJLT~OLE~Y A~ RECORD 'THE TIldE AI~ PRE~ REI~INING AFTER ALL UNITS ARE CLOSED WITH CHAR~I~ ~ OFF. 4. RECORD ON I~ REPORT, T~E ACC~~ LO~ LIblIT IS 45 SEC(~ CLOSINS TII~ AI~ 1200 PSI REI~ININ~ 13-5/8" BOP STACK TEST I. FILL BOP STACK AN3 O..13KE lvIqNIFCLD WITH ARCTIC · DIESEL. 2. CI~CK TNAT ALL LOCK DO~ SCREINS I N ~Lt-E/~ Ai~ FULLY i~TRACTED. SEAT TEST PLUG IN Ii~.LLHEAD W/TH i:a.I~ING JT ~ I~N IN L~ 3. CLOSE ~ ~NTER At~ ~ KILL ~ LINE VALVES ADJA(:ENT TO B(~ STACK. ALL OTI.-~R VALVES AI~ Q.IOKES SHOU..D BE OPEN. 4. PRESSI.J~ UP TO 250 PSI AI~ HOLD FDR I0 M~N. IN.- ~ PRESSI. RE TO ~ PS:[ AI~ HOLD FOR I0 BLEED PRE~ TO 0 PSI. LINE VALVES. CLOSE TCP PIPE RAMS ~ NCR VALVES ~ KILL AI~ Q..ICKE LINES. 6.TEST TO 250 PSI /~D 3COO PSI AS IN STEP 4. 7. CCNT!N.[ TESTINS ALL VALVES,, L:[NE&, ~ ~S W/TH A 250 PSI LOW ~ 3000 PS] HIGH, TEST AS IN STEP 4, DO 1~3T i::~~ TE~"I' ANY ~ TNAT NOT A FULL CLOS:[N~ POSITIVE SEAL (;~ll;~KE. CN.Y FUNCTICN 1-ESl Q-E~E$ THAT CO ~ FUI.~LY CLOSE. 8. OPEN TCP PIPE RAMS AI~ CLOSE: Bo'r'fOM PIPE RAMS. TEST BOTTOM PIPE RAMS TO 250 PSI AI~ 3000 PSI, 9. CPEN BOTTOM PIPE RAbI~ BACK OUT RUI~i:[NG JT ~ PLI..L OUT OF' NOLE. I0.CLOSE BLII~D P. JU~ ~ TEST TO 250 PS:[ AAD 3(X33 II, CI:~N BL]I~ ~ ~ I~TE:[EVE TEST ~ MIU(E MI~:[FCLD AI~ L:[NES ~ FLI. L OF NCN-Fl~EZING FLUTD. SET ALL VALVE5 IN CRILL]NG POSITI~ 12. 'rEST 5"T~IPE VALVE.~ KELLY, KELLY CO(:X~ DRILL PIPE SAFETY VALVE, AI~ INSIDE BOP TO 250 PSI I$. RE~ TEST II~'DRI~TION ~ BLON:XJT PREVENTER TEST FORM, SIGN, AI~ SEI~D TO DRILL:[NG SM3ERVISI3R. 14. PEI~ ~TE BCPE TEST AFTER N~PPLtNG UP YEEKLY THEi~AFTER FLt~TICNALLY OPEPATE BOPE DAILY. 00~4001 AROO~jALASKA, liNC, I~-I- Kupm~uk F_le!d.,!~Nor'~:h Slop. o I KOP' TVD"":300 TIgD,,:300 DEP-O : K-12 TVD-2916 TIgD-4025 DEP-2:388 9 5/8' CSG PT TVD'$116 TMD-4:386 DEP'2687 COLV[LLE TVD-:3166 TIgD-4476 DEP-2762 ..... 4000.. K~'5' TVD-4576-TI"ID-?014 DEP"4872 AV. ERAGE A. NGt~E .... 56 DEG 15 MI!N 6000, T/ ZONE D TVD-6071 THD-9705 DEP-7110 T/ ZONE C TVD-608? THD-g?:34 DEP-?1:34 T/ ZONE A TVD-6115 THD-9784 DEP-7176 TARGET CNTR TVD-6144 TMD-98:37 DEP-?220 B/ KUP SNDS TVD-6201 THD-99:39 DEP-7:305 TD (LOG PT) TVD-6:312 THD-101:39 DEP-7471 70.00 O. i ! 000 2000 i I i :3000 4000 5000 6000 VERTICAL SECT[ON I 7000 HOR I ZON T AL PRO,;-'~CT I ON SCALE 1 IN. = 10 FEET ARco ALASKA, !NC, Ped 3H, Well Kupe~-uk Field Nor.~:h Slop:, Aleeke 8000 ............................. ZOO. G... 6000 5000 _ z 4000 i := 3000 _ 2000 _ 1000 _ 0 .. 1000 . WEST-EAST 2000 1000 0 1000 2000 I I I i 3000 TARGET CENTER TVD,.~144 NORTH 7133 EAST ! 1 IS TD LOCAT£ON ~ 114~' F~I.,. 24~8' FIK. gee. 3,5. T13N. R~E TAIIIII~ LOcATIOII_~, ~ F'gt.. ~t44g' ~O~ 35. T13N. RS~ SURFACE LOCATION t 95'/' FNL. 292' ~ gEO. 12. T12H. R8E N 8 DEG 53 MI N E 7220' (TO TARGET) 150 200 250 ,.300 350 400 450 800 1150 2500 1300 I I I I ;I,.050 I t I 300 301 900 I00 21 O0 100 300 300 1100 ~0 1100 i iO0 2500 1 FO0 800 850 l OOC 105C 110C 115( 120 1 50 200 250 300 ;55O 400 450 ARCO Alaska, Inc Post Office =ox 100360 Anchorage, Alaska 9.9510-0360 Telephone 907 276 1215 january 15, 1988 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT' Conductor As-Built Location Plat - 3H Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG'pk GRU1/86 Enclosure If you have R CEIVED JAN J. 9 0il & ~as Cons. Commissi~[t Anchorage ARCO Alaska, Inc. is a Subsidiary of AllantlcRichfleldCompany VICINITY MAP SCALE I", 2 MILLS S ALL WELLS LOCATED IN SEC. 12, T. 12 N., R.8 E., UMIAT MERIDIAN. I. ALL COORDINATES ARE A.S.P., ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. 4. REFER. FIELD BOOK L-87-19, 35-441L-87-11, 29-32. 5. O.G. ELEVATIONS FROM CED-RIXX- 3471Z~.~ 6. HORIZONTAL POSITION BASEDON 3H CONTROL MONUMENTS PER LOUNSBURY~ Assoc. Y' ASPs 'X' 6,000,110.73 6,000,135.51 6,000, 160.57 6,000, 185.28 6,000,210.66 6,000,235.50 6,000, 260.34 6,000,285.82 6,000,310.30 6,000, 335.43 6,000,425.37 6, 000,450.51 6,000, 475.46 6,000,500.41 6,000, 525.44 6,000,550.46 6,000,575.45 6,000,600.44 6,000,625.20 6,000,650.45 6,000,675.40 6,000,700A2: 498,655.44 498,655.43 498,655.39 498,655.43 498,655.47 498,655.40 498,655.41 498,655.44 498,655.45 498,655.44 498,655.44 498,655.38 498,655.42 498,655.43 498,655.41 498,655.47 498,655. 55 498,655.59 498,655.52 498,655.49 498,655.65 49 8,655.73 LATITUDE 70° 24'41.531" 70° 24'41, 775" 70° 24'42.022" 70° 24:42 265" 70° 24 42.514" 700 24:42.758:; 70° 24 43.003 70° 24'43.253'; 70° 24'43.494' 70o24'43.741'' 70024'44.626" 70o24'44.873'' 700:;)4, 4 5.119" 70°24; 45. 70°24 45.610 70024'45.856.. 70o24'46.102'. 70O24' 46.$48" 70o24'46.592" ?0°24'46.84d! ?0024'47.085" 70° 24'47. 331" LONGITUDE 150000, 39.416" 150000' 39.417' 150° 00' 39.418" 15 0° 00' 39.417" 150° O0° 39.416" 150° 00; 39.4181; 150° O0 39.418' 150° 00' 39.417" 150° 00', 39.41Y' 150o00 39.417/' 150°00' 39.418" ~50o 00'39.42d' 150° 00'39.419" 150° 00' 39. 150° 00' 39.41~ ! 50000' 39.417" 150000. 39.415" I$O°Od 3~.414" 150o00'39.417'' 150o00'39.418'' 15 0°00' 39.413" 150°00'39.410" D~$t F N; L. 1546' 1522' 1497' 1472' 1446' 142 2', 1397 1371' 322 1232' 1207' 1182' 1107' 1082' 1057' 1032' 1007' 982:' 957' Ois! F.W.L. ! 281 281' 281' 281' 281' 281~ 281 281' 281', 281 281' 281' 281' 28~', 281 281' 282' 282' 282' 282' 282' 282' O.G. Elev. 34.0' 34.0' 33.9: 33.8 33.7' 33,7: 33.6 33.6' 33.6', 33.6 33.?' 33.8' 33.8' 33.8', 33.8 33.8' 33.8' 35.8' 33.8' 33.9' 33.9' 33.9' Pod Elev. 38.8' 38.8' 38.8' 38.8; 38.9 38.?', 38.6, 38.6 36.7' 38.8' 38.8' 38.71 38.7 38.7' 36.8' 38.g' 38.7: 38.7 3 8.6' 36.6' I I HEREBY CERTIFY THAT lAM PROPERLY ! ARC0 REGISTERED ANDUCENCED TO PRAC- ..:~.~&~AII~I,._ aska Inc. Al STATE OF ALASKA AND THAT THIS "" i D S 3 H SURVEY MADE BYME ORUNDER ~eeee~eeeee eeeeeeee~ee~oee d DIMENSIONS AND OTHER DETAILS 0C. ONDUCTOR AS BUILT a.~..,,, .... ,.,..;~,,~,.,~ ~ ~,~;~,h~3~ · ~, ~-4545 ,/ LOUNSBURY A ALASKA REV.~ ADO COND. ,9 ,- 6-88 ---- t DWN BY: PJW . CHK~: dWT_ CHECK LIST FOR NEW WELL PERMITS Company ~CO Lease & Well No. ITEM APPROVE DATE YES NO (1) Fee w~(~ . J/2~i~ 1. Is the permit fee attached .......................................... REMARKS (2) Loc ~M l/~l~ (2 thru 8) (3) Admin ~'~ (9 thru 13) 10. ,.,,4 (10 and 13) 12. 13. (4) Cas~ ~'~, 2o~-~'~ (14 thru 22) (5) (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 23. 24. 25. 26. 27. 28. 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 ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~O~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER (29 thru (6) Add: 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 ............................................. Geology: Engineering: WWB ~ LCS .3'£~'~' BEW / rev: 01/28/87 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: 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. , , Scr~lumber~er page Co~pa~y i~ame ~ell ~ame Field ~ame County State Rtln Number Servlc~ Order API NQmDer Date [~o~ged [)ate Computed N ~mbe r 72620 ARCO AL.,A$~A, 3H,22 NORTH SLOPE 26-FE~-~B 2~AR-88 Schlumber.ger LIST Reel: er 72620 ~iTO: ['12620J L, ISA.,.AI~'; 2-~AR-88 J2:5!:57 Page 3 DATE : 88/03/ 2 OR! G I N : REEL ~'~""'::" · 72 ',,.~-~, , , 620 CONTI~UATION ~j 0,. PREV! .... !IS REEi~ : CON ENT , SCHSU~ERGLR LIS TAPE (gPl~. 50-103 20097)3H-22 ARCO Tape neadez- SERVICE Na;!:E : EDIT DA?,E" : 88/03/ 2 ORIGIN : FS].A TAPE ~ cal EOF recoro File header 5CHI.,UMHL~GEk i. IS APE (API~ 50 103-2uOgT)3H-22 ARC£ E [) I' T ,0 o I .001 ** FILE FILE NA~E : EDIT SERVICE ~A~ig VERSION # : DAT~ ~AX, REC. LEM.: 1024 ~ILE TYPE : P~EVIOUS FILM Table type 34gP t, istlno of set 2 type r~,]NAM 346P FM KUPARUK ~ANG ~ TCtW~ 12N SECT 12 C{]UN NORTH SLOPE STAT ALASKA E:nd of set 34SP f'blC comment FLIC comment FLIC comment $CHi,,U bIBERGER F'bIC comlaent : : FEIC ~o"~ment ~klC comment i C C ommen t FbIC comment FLIC :' comment FLIC co~ment FLIC comment Fb/C com,~ent FDIC: co~ment COMPANY : ARCO ALASKA INC, WEL6 : FIE ,D ~ KUPARUK Ci'}U~TY : NUR. Ti4 SLOPE RA f.~GE = BE FLIC comment FLIC COm~pent ~'l,,, I C comment FLIC Comment FLIC comment FLIC comment FLIC comme~t FLIC co~me~t FLIC comq'~ent F' b I C c o m m e n t F'LIC FLiC comment FLIC comment FbIC comment FLIC comment FLIC comment FLIC comment FLIC comment FbIC comment FLIC comment FLIC comment FLIC comment FLIC comment FLIC comment 72620 BAiSE LOG: Dlib ' RUN LOGGED 26-FEB"B8 BOTTOM LOG INTERVALm TOP LOG INTERVAL CASING-bUGGER BIT SIZE TYPE MOLE FbU1D DMI,~$ITY ¥ISCUSITY PH FLUID L085 R~ ~ ~EA$ TEMP. a~F ~ MEAS~ TEMP, k~qC O ~EA~ EMP, R~ ~ B~T 9 : 4 = : 10.O0 4.860 0 73 F 4,730 ~ 75 F 3.150 ~ 70 F 2,609 M ~42 F SANDSTONE TO[}b STRING bIL FDC/CNL F~C (HIGH RESOLUTION) GR IN CASING LDP: R, SINES Data format specification record Listing of set ~ t¥oe 64EB osject 0 ENTRY VALUE ?EPCODE SIZE -;...... 4 I 6O 1 ~ 6O 73 4 9 ,lin 65 4 0 0 I 1 4 68 0000000000 0 46 0 0 I 1. 4 68 0000000000 310 635 890 356 350 280 310 635 3~0 O1 0 0 1 I 4 68 0000000000 21 0 0 I 1 4 68 OOO0000000 O0 0 0 1 I 4 68 0000000000 Ol 0 0 1 I 4 68 0000000000 02 0 0 I ! 4 68 0000000000 O1 0 0 I 1 4 68 0000000000 O1 0 0 I I 4 68 0000000000 21 0 0 1 1 4 68 0000000000 O1 0 0 1 1 4 68 0000000000 End O~ set ~)ata record type 0 DEPT 9914 5 FT 3,)21 94 a P -2 ~ GR 8~ 1875 TENS 7 0 TENS 720. NPN1 32 ~425] TNR; 2 ~05093 RTNR 3 I.~253 RCFT 816.4355 ,CET 2601.628 CFTC 9{9 4293 CNTC ~633,15! GR ~9 1875 T~S 720. [)PHi 16 ~1327 D~HO 07 61783 RHOB ~80969 CALI 8.859375 GR 89:1875 TENS~~99 25 GR~99,25 Data record type 0 DEPT 9814,5 FT 2991,46 ~ DEPT 9814,5 SFb~i 10,2886b IbO ~19~b488 Ib~ 9 007282 SP -49.5 Ga 86~4375 TENSo~.52 TE~S 5952, ~C~T 26~1.g!5 CFTC 9~ 7437 Ct~TC 2664.092 GR 8 ~375 $chlumberge~ Data record type o I)EPT 971,4,5 FT 2'960,98 ~ [.EP~ 9114,5 IbD 9.577028 i~M 9.06'168 SP '45,:~5.. TENS 5544" TENS: 5544 NPH1 31.4548! RTN~ 2.~868132 RCFT 69 ~ RCNT 2191.19 CNTC 2238.719 GR DP~{I 14,33~()6 DRMO 0.01743644 RH08 2 3596 GR 95,5625 TENS '999,25 '25 Data record type 0 OEPT 9614,5::FT 2:93' 0,5: M e:..LO 2,237759 : :I:~D 2-732038 IbM 2,596326 oR 104.0625 TENS 5500, TEN6 5500' ~P '46, ~ r~R~ ].7~3923 :RTNR ],950713 R. CFT: 407,4077 PC~<~T 1.707.941 C~'T.. 493.3739 CNT(. 1850,866 GR 104,(3625 ~f.~S 550{., 9PHt 19,47187 DRHO 0'00.4183601 RHOB 2-32$~47 ~E.P~ 9514,5 SFL~.~ 3.005167 5625 SP -44, GR 10 . ~PHI 46,94865 "rNRA 365025 RC~T 1628.654 CFTC 4~4;~804 5625 TENS 5500. DP~i 18.~37511 DRHO 0,0063b~992 RHOB 1896 CAJI 9,734375 GR 109,5625 TENS -999,25 GR 5 Data record type 0 DEPT 9414,5 FT 2869,54 M ..... .... ~P -45 GR { TENS 5 04 TENS 5304, ~P~I 41 ~ TNRA 3.5 ~ RTNR ] 73~713 RCFT 468,2849 RC~T ~6~0, CFTC 500~19q6 CNTC ~717,371 GR ~14,1875 TENS 5304. DPH1 17 ~4 DRHO ~-009108346 RHOB ~.361413 C~LI 9,57031] GR 11~. 875 TENS 999,25 GR 999.25 ~~I~m~m~I~~m~Imm~l~m~m~m~.....~m~m~m..m.~mm.lm~..~m Data record type 0 D~]PT 9314,5 FT 2839,06 ~q '''''''''''''''''''''''''''''''''''~''''''''''''''''''''''''''''''''9314, $ i, 24 D 3.63 52 IbM 3.8138 SP -57. GR 1~2'875 TENS 5584, TENS -999,25 TN 5 RTNR 5 -999 RCF' ..999 5 25 Data record ty~e 0 D~.PI :9214 5 FT :280B,~58 M D~!~ta record type o L)~iPT 9114,5 FT 2778,! M SFLI) 4 091{~2~ ILl) ~.233994 IbM 4.2537~1 ~R i~9,25 TENS 5268, TNRA -999,25 RT~R -999,25 RCFT -999,25 CFTC -999,25 CN~C -999,25 GR -999 T~N~ -99q,~5 I)PHI -99~,25 D~HO -999,25 ~.HOS -999,25 C~LI-999,25 GR -~}99,25 TENS '999,~5 GR ~999'~5 ~ata record type o ..)~.,PT 901t.5 ~T 2747.62 N D~P~. 9014 5 SFLU 4,01 94* I~D 4.346432 Ih~ 4 3387 NPHI -99~ 25 T~RA:99 ,25 RT~R -999 25 RCFT -999,25 RCNT -qqq,25 CFTC 999,25 CNIC -9~9 25 GR -999~25 TENS -999,25 DPHI-999,2b DRHO -999 25 RHOB -999,~5 C~bI'qgq.25 GR -999.25 TENS -999 25 GR -999.25 Data record type o [~EPT 8914.5 FT 2717.14 a OEPT 8914.5 SP'LU q 865936 .ILl) 4.798636 IbM 4 82787 ~P -64.5625 (;R 1~0 5 TENS 5148 TENS -~99,25 ~'PHI -999,25 T~RA -99~,25 RTNR -999 25 RCFT -999.25 RCNT -999.25 CFTC -999.~5 CNTC -999 25 GR-999,25 ~l ' 25 DRitO -999 25 RHOB '999.25 C~5I -999,25 GR -999,25 TENS -9q9,25 GR -999,25 -999,25 .; tC -999 25 25 oata.record type 0 D[:.t.l [~714,5 FT 2650,18 [>:~.:!>T 8714,5 SFbU 4,146611 'I[,O 3'757737 IbJ~ 3'826188 N~HI -999,~5 TN~ -999 25 RTNR '999 25 ~CF~ -999,~5 CFq~'C-999 25 =CNTC "999 · CEN8 -999,~5 DP~{I -999 25 [)~HO -999 25 ~{OB -999;25 C~LI ~999'25 G~ ~999 25 =TENS ~999 Data' record type 0 D~P~ B61~,5 SP -35.5 ~R 97.8125 TENS 4920. TENS -999,25 NP~I -999,25 ~NRA -999,25 RTNR -999'25 : ~CFT -999':25 RC~'dT -999,25 C~TC -999'25 CNTC -999,2§ GR -999,25 TENS -999:,~5 9P~I -999,25 D'RHO -999425 CALl -999,25 GR -999,25 TENS -999,25 GR -999~25 Data record type 0 DEPT 8514.5 FT 2595.22 ~ SP -45 ~5 GR 75 TENS 48B0, TENS -999 25 ~PHI -999.25 TNRA . ~9,25 RTNR -999.25 RCFT -999 25 RC~ -999,25 CFTC -999,25 CNTC -999,25 GR -999 ~5 T~N$ -999,25 {)PHI -999,25 DRHO -999,25 RHO~ -999 25 CALl -999.25 GR -~99,25 TENS -999.25 GR -999 25 mm.mmmmmmmmmmmmmmmmmmm.mmmmmmmmmmmm.mmmmmmmmmmmmm.mmmmmmmm.mmmmmmmmm Data record type 0 DEPT 8414,5 FT 2564,74 M DEPTNpH! ~414.599q.25 SFLU~rNHA '4'298635 ILD 470~)98 IbM i 84561 112.6875 TENS 4~84 TENS 9,25 , _ .999,25 RTNR -999.25 RCFT 999,25 ~CNT -999,25 CFTC .999.25 CNTC -999.25 GR 999,25 ENS -999 25 DPHI 999.25 DRMO -999,25 RHOB 999,25 ~ Sc{~lumberger [,Ist ~To: [72620]LISA.DAT; i-~qAR-88 GR 5 TENS !5 57 GR -9' 5 SFI.LI 3 5 5 L~ 4 ~ RCFT -999 25 TF, I'~S -999,25 [)PHI-999,2b D~,H[3-9~,~ RHO8 999,25 CAI.~I '999,25 G'R -999'~5 TENS: ~':999.25: : =GR ~999.:25 Data~:record type 0 DEPT 8214.'5::FT :2503.78 Data record type 0 f)EPT 8~14,5 FT 2473,3 ~ SF -5 53125 GR 98.3 25 TENS 4544, NF'HI -99. ,25 TN~ -99q 25 RTNR -999 25 RCNT -999.25 CPT. ~999.25 CNTC ~999,~5 TS.~NS -999 25 DPHI -999,~5 DRHO -999.25 CALI -999~25 GR -999,25 TENS -999,25 )'~ '~ 5 f'T 2442 82 M Data record type 0 [£PI 8014, , SP -70 GR ~ 625 TENS 4452 TENS ~ 25 NPHI -99~.25 TNRA 9~9,25 RTNR -999,25 RCFT -999 25 RCNT-qgg,25 CFTC -999,25 Cf~TC -999.25 GR -999 25 TENS '999.25 DP~I -999,25 DRHO -999.25 RHOB -999 25 CALl -999,25 (;P -999.25 TENS -999.25 GR -999 25 Data record type 0 [)FiPT 791.4,5 FT 2412.34 ~ DI~'lPT 7914 5 SFI, h 3 682925 ILD 4 300138 ILM 4,201645 SP -36.~5 GR 1~4,31~5 TENS 4~72, TENS -999,25 · $cblumbergeI- t..~IST ~::'['(.~: 172620]LI$/:.DAT; 2-~-~AR-88 12:51:57 Page 10 ~-~I -99q,25 T~RA-99q.25 ~TN~ -999,25 RCFT 999,25 ..... ,25 : C[ rC 999.~5 CNiC -9:99,25 999,:25 T~j{~:~8 -999,25 [)~HI -999,25 [)~h~ -9q9,25 RHUB -999,25 C~[,I '999:~ GR "999;25: "999~25: Data record type 0 of;PT 7814,5.FT: 2381 '86: M Data record type 0 ~:~[ .... [ !714,5 S~L~ 3.~87558 ILD 4~427588 IL.~ 456 N~H.[ -999,25 TN~ -999 25 RTNR -999'25 25 C CAI,I -999,25 E S '999,:25 GR "999,25 Data record type 0 bi!',PT 7614. ET 2320,9 N "P , '" t N~itZ ~999.25 TNRA~"99~.25 RTNR2999"25 RCFT '999 25 RC;~T -999,25 CF'rC 999,25 CNTC 999,25 6R -999 25 TENS -999,25 OPHI 999,25 DRH(] -egg,25 ~OS -999 ~ CALl -99g,25 GR 999,25 TENS -999,25 GR -999..~5 Data record type 0 {>~;PT 7514,5 FT 2290,42 M DSPT 7514!5 Sf'bU 3.662219 I~D !21051 IL~ 4,142713 SP -36, 8125 GR 97,875 TENS 694, TENS -999,25 NPMI -999 25 TNRA 2999,25 RTNR 999,25 RCF'r -999,25 RCNT -999,25 CFTC .999,25 CNTC 999,25 GR -999,25 .----~'----------.--..... .~ . ......--..... .. . ..... .~.~.. 5 <;R 9 25 999 CAbl -999,25 GR -999 25 DEPT 7 5 FT 46 ~ SFbb 3 70 8 ILD 4 .66 4 NPH -99 5 TNRA 99 25 RTNR -' ~9 25 RCFT -999 25 295 CNTCDRHO ' CALf -999,25 25 GR '999 25 Data record type 0 DEPT 7214,5 fi 2198-98 D~PT 721~-5 SF'L~} 3.235721 I~D 3,8,~,9374 I:bM ~.683845 P - GR 97.3125 TENS 386 S.. 44 5 TENS -9 25 NP}~{I -99~.25 TNRA -999,25 , 25 RCFT ~T ~ ,~ CN~C RCi~T -999 25 Cf ,(~-999 25 G~ -9 25 T~.~MS -999,25 LPM1 -999'25 D~HO '9~9 ~5 RM00 ~999 25 C~{~I -999.25 <;R -999.25 TENS -999 25 GR 999 25 Data record type 0 b~i.PT 7114.5 FT 2168.5 M , SF 2!0 25 GR ! 4375 TENS 80, TENS -999,25 NP~{I g~,25 TNRA -99~ 25 RTNR 09 25 RCFT -999,25 RCNT 99.25 C I'C ~999. 5 CNTC '999, GR -999,25 T~i~S '999,25 DPHI 999, 5 DRHO '999, RHO~ -999.25 CAbI '999,25 GR 999.25 TENS '999,25 GR '999,25 Data record type 0 b~:PT 7014,5 FT 2138,02 ~ CEPI 7014,5 SFbU 3.394997 ]LD 3 5 876 ILM 87 123 SP -45.5 GR II2.0625 TENS 3 4 T~NS ~99 25 NPHI -999.25 TNRA .999.25 RTNR -999,25 RCFT-999,25 ~CfJT -999.25 CFTC ,999,25 CNTC -999,25 GR -999,25 T~P. iS -9gg.25 DPHI 999,25 DRHO -999,25 RHOB -999,25 57 Pa. le 999 12 PT 69 5 SFL~'t 2 ~08~ IbD 3 266268 I'6~ 3 161013 -99 25 -999 25 RH 99 Data ¥ ~ ~' ~[,~U 2.651746 II~D 3.195677 I'L~ 3 090445 GR 112'4375 T,EN$ 3690, T~RA -999,25 RTNR -999,25 RCFT - ,25 CfTC ~g9~,25 CNTC -999,25 GR TENS -99g,25 DP~tI 2999,25 DRHO -999~ ~5 RHOB -999,25 CASI -999.25 GR 999,25 TENS -999~ GR -999,25 Data record type 0 DEPT 6614.5 FT 2016,1M DEPT 6614,5 SFLU 3 859942 I[,D ~ 513133 ILM 40386969 NPHI -999,25 TNRA-99~.25 RTNR 999.25 RCFT -999,25 RC~T -99g,25 CFTC -999,25 CNTC -999,25 G~ -999,25 TE~S -999,~5 DP!-~I -999,25 DRHO '999,25 RHOB -999,25 CALI -999,25 GR -999,25 TENS -999,25 G~ -999,25 Data record type 0 D~PT 6514,5 FT 1985,62 ~ D~PT 6514 5 S~'LU 4 ! 4912 ILO 4,18 474 I. LM ~99 25 SP -66,6~25 G~ 1~8 TENS 3410 TENS , -7 -999 5 GR 25 Oat~ ~ecord type 0 DF:PT 6314,5 FT '1924,66 ~ SFLU ~54 DRHO - 99;25 RMOB -999,~g CALl ~999.25 GR ~999 ~$''99:9,25 GR"999,2b Data record type ODEPT 6214.5 FTI894,18 ~ SFLU 1.992821 GR ~02.25 [~RA .999,25 RTNR "999,25 RCFT '999~ 25 RCNT -999 25 CFTC .999,25 CNTC -999,25 GR -999. 25 TENS -9~9' ' ~ CALl -9~9'25, 25 GRDPHI -999'25999'~5 TENsDRHO -999.999: GRRHUB -99919992525 Data record type 0 DEPT 6114,5 ET 1863,7 M SP~'2 125 GR!~5 1B75 TENS 3560, TENS -999,25 NP~! 'qD~ 25 TaRA 99~,25 RTNR -999,25 RCFT -999,25 RCNT ~999,25 CFTC 999,25 CNTC -999,25 GR -999,25 T~N$ -999,25 DP~ -999,25 ORHO -9~9,25 RHOB -999,25 CALl -999,25 GR -999,25 TENS -999,25 GR -999,25 ' 176 5 ..~R -999 CAL, I -999 25 e 0 D~I 5 FT 1802 74 ~ 5914,5 SFL(~ 2 41014 -999,25 TN 9,25 RC~T "999 ~25 -999,2~ DPHI -999,25 C~LI ]-~999,~5 G~ ~9'99,~5 I 5 D 7:1, ~ 5 RTNR '999,25 RCFT -999 CNTC "999~25 i. 999i DRHO -999,25 RHOB -999 2¸5: 5 ~' ~772 2:6 ~ Data record type o ~P..PT 5814, . DEPT 5814,5 SP -~88,125 25 999,25 RMOB ~999'25 TEgS ~999, DPHI ~ ' C~,I 999,25 GR -999,25 TENS -999,25 GR -999,25 Data record type 0 D~:PT 5714,5 FT 1741.7~ M SP -29, 4688 R ~3 4375 TENS 3200. ,~.EN$ -99'9 25 P~PH.I -99~ 25 TIARA 99~,25 RTNR ~999,25 RCFT -999 25 RCNT -999 25 CFTC -999,25 CNTC .999,25 GR -999 25 TE~S -999,25 DPHI -999,25 DRHO .999,25 RH{)B -999 25 CALI -999,25 G~ -999,~5 TENS 999,25 GR -999 25 Data record type 0 I)EPT 56~4,5 FT 1711.3 M '"'"'": ! iii'"'" !'"'". ii SP -42.06~5 GE .I2.B TENS 40 TENS -~99,25 NPHI -999,25 TN~A 999,25 RTNR -999,25 RCFT 999,25 RC{~T -999,25 CFTC 999,25 CNTC -999,~5 GR '999,25 T~NS -999.~5 DPM1 999,25 DRHO -999,25 RHOB -999,~5 D~;PT 5514,5 SS'[,U 2.809116 IbD 3.453~05 IL~ 3 SP -51,2t875 ~:~, 102.,5 TB~S 31: 40, ~P~(.I -999,25 II~RA -999 R']TNR 9 RCFT -999 25 R:CNT .,999,25 C~TC 9~9 GR ~999 C~bl -999'25 6~ ~999' Data r:ecord ty[:e 0 D~,FT 5414.5 FT' 165.0:'34 ¢4 DEPT 5414,5 S~"t:.,U 2,801261 7 ~ -55.53125 GR lOl TENS - 99 25 NPHI ~99g,25 TNRA -' 25 : RCf'T 9:99 25 RCN~[ -999,25 CFTC -999 25 CNTC GR -999 25 TE~gS -999,25 )[P}'{I -999 25 25 CAL, I -999,25 GR -gg9 25 TENS GR 25 DP;PT 5314 ~ SFLU 3,303178 ILD 4..1.304,11 I i4 8406 SP -53.~ 75 GR 104.25 TEN~ 2924. t~PHI -999,25 TN[{~ -999,25 RTNR -999.25 RCFT -999 5 ~(.~,~ 999,25 CFTC -999,~ CNTC -999,25 GR TENS '999.25 DPHI '999,2 DRHQ '999.25 RHQB CALI -999,25 GR -999,25 TENS ~999,25 GR ~999,25 Data record type 0 DEPT 5214,5 FT 1589.38 ~ DEPT 5214,5 SFSi.~ 3,30877~ ].DO 4 130275 I5~ 3 912278 SP -60 59375 GR I05.5 TENS 2~70. TENS -~99,25 NPHI -99~,25 TNRA 999,25 RTNR -999.25 RCFT -999,25 ~C{~T -999,25 C~TC-999,25 CNTC -999,25 GR -999,25 TENS 999,25 DPH] '999,25 - DRHU -9g9,25 RHOB-999,25 CALI -999,25 GR -999,25 T~NS -999,25 GR '999,25 Data record type 0 L)EP't' 51i4,5 FT 1558.9 .~ TNRA -~. :5 RTNR -999 25 FT 25 -999 25 999 5 99 5 '~ D..,PT ~914,5 SFL, lt 3-6~7225 l~O 4.549192 ibm 4.252(}] SP 26.23438 G{ql I69'06~5 TENS T~N~ ~999 NpH~. -999, 25 TNRA -999 .25 RTN~ '999;25 [~CFI -999 5 ].'~:NS -999,~5 DPH] -999 .25 D~HO -999'25 ~HOB '999 C~LI ~999~25 GR ~999 ~25 TENS -9992~5 GR ~999 Data record type 0 DMPT 4814.5 FT 1467.~46 M DEPT 4814.5 $[...,U 3.000553 ILD 4-051808 SP -11.91406 GR 97 TENS 2990, ~N$ '999,25 ~PHI -999,25 TNRA -9~9,25 RTNR :999,25 RCFT -99~'25 ~C~'.[ -99q'25 CFTC 2999,25 CNTC 2999,25 GR -99['25 TENS -999,25 9PSI 999,25 D~MO 999,25 RHOB Data record type 0 I~EPT 4714,5 FT 1416.98 ~ 6P -0 7 375 GR 9) 8125 TENS~ 40 TEN[ 2[40 ,CNT 17~6.129 CFTC ~ $1el CNTC i~72 176 GR 93.~125 CA=! 8.734375 G~ 93.8125 TENS -9~.25....GR ~.~ -9 5 GR 74 ~ T~ $ 2,.70 CALI 10 I G~;~, 7.4 99 ~ ~cord 0 DE',PT 451,4 1376 02 ~ : : T~RA 4 148 .CF~ 354 9989 Data record type 0 DEPT 4414, PT 1345,54 ~ DEPT 4414,5 SFL~ 3,014438 I[~D 3,6690:8:2 : IbM 3,42937 SP -3, GR 104~375 T~NS 2314. TENS 2314, NPHI 42,62699 ~N~. 3~35858 RTNR 4,244898 RCFT 455,5155 C~ 17al.289 CP'TC ~82.9103 CNTC 1789,0'7! ~R 104.375, TENS DP~{I 26.2799~ DRHO 0.04638205 R~OB 2,216502 CALl GR 104.375 TENS 2280, GR 99,3125 Data record type 0 D~i:PT 4314,5 FT 1315,06 DEPT 4~14.5 S~'Lt) -999.25 ILD -999.25 Ib~ -999.25 P -999.~5 GR -999,25 TENS -999,25 TENS 999~25 PHI -999.25 T~.!RA -999.25 RTNR -999.25 RCFT -999.25 RCNT -999.25 CFTC -999,25 CNTC -999.25 GR -999,25 TE~'~)S -999,25 DPHI -999,25 DRHQ -999.25 RHOB -999 25 CALl -999,25 GR -999,~5 TENS ~294, Data record type 0 DEPT 4214,5 FT 1284,58 ~ DEPT 42~.4,5 SFbU '999,25 ILD -999,25 Ib~ '999,25 SP -999.25 G~ '999,25 TENS '999.25 TENS -999,25 NPHI -999,25 TNRA '999,25 RTNR '999,25 RCFT -999,25 RC!~T-999,25 CFTC -999,25 Ci~TC -999,25 GR -999,25 TENS -999,25 DPHI '999,25 DRHO '999,25 RHOB -999,25 Data record t'yDe 0 b~][,! 4!14,5 F,[ 1.254,1 M ~f~PT 41!4,5 SFLU -99~ 25 ~,LD -999,25 ILM -999,25 P-9'99 ~ ~ · 25 {~R , -99 25 : TENS ~999~5: TENS .'9'99,25 NPH[ -999~25 T~RA-999 RCNT-.999~25 CFtC -999 T~2~{S -999'25 ~!PH~'999. CAbI ~999~25 . GR -999.] Data record type 0 DEPT 40i4.5~"FT'1223.62 ~ D~,.T 4014~ 5 SF1, U -999 "999,25 SP -999.25 ~R -999 25 TENS '999125 TEN~ -999'25 NPHI-!999.25 TNRA ~999 ~5 'RTNR -999"25 RCF~ -999;25 RCNT -999.25 CFTC -999 25 CNTC -999,25 TENS-999,25 DPHI '999 25 DRHO "999. CALl -999,25 GR -999 25 TENS 2184, 5 Data record type o DEPT 3914,5 FT 1193.14 ~q · ~L"! DEPT 3914,5 SF~t.] -99 I M -q9 25 .... TENS ~999 25 SD ~999.25 -99 , NPHI -999,25 TNR~ -999 25 RTNR -999.25 RCFT -999 T -. 25 RC~T -999,25 CF C 999 CNTC -999,25 GR 999125 TENS 2134, GR 60.4~ Data record type 0 DEPT 3B1~.5 FT 1162.66 ~¢ [)EPT 38i4.5 SFI,.~u -999 25 XLD -999 25 ILM -999.25 SP -999,25 GR -999 25 TENS-999 25 TENS-999,25 NPHI -999.25 TNRA -999 25 RTNR -999 25 RCFT -999,25 7' CF.C -999 25 CNTC -999 25 GR -999,25 RC~4T -999,25 TE~S -999.25 DP~I -999 25 DRHO -999,25 RHOB -9_99 25 C~[,I -999,~5 GR -999 ~5 TENS 2100. G~ 57.4,~75 Data recora type 0 i.)EPT 3714.5 FT 1132,!8 M DEDT ]714.5 SFI,,~t -999.25 ILD -999.25 ILM -999.25 SP -999.25 GR -999.25 TENS '999.25 TENS -999,25 5 -9!99 DPt, fi -999 25 GR 58 6 75 · T Data record type 0 OEPT 3414,5 F' 1040,74 ~ "P 3414.5 SFLt) -999,25 I~D.-999,25 DE.T SP'99g,25 GR -999.25 TENS -999,25 NPHi -999,25 TNRA.-999,25 RTNR-999,25 RCNT -999,25 CF...C -99g~25 CNTC -999,25 TENS -999,25 DPHI ~999,25 DRMO ~999 25 CALI -999.25 G~ 999,25 TENS 1910: Data record type 0 D~PT 3314,5 FT 1010,26 ~ D~;PT 3314,5 SF[,U -999.25 ILD -999,25 ILa -999,25 SP -999,25 GR -999,25 TENS -999,25 TEaS -999,25 NPH'I -g99.~5 TNRA~999,25 RTNR -999.25 RCFT -999,25 RCNT -999,25 CFTC 999,25 CNTC-999,25 GR ~99~,25 'fF;~,~$ -999.25 DP}ti -999,25 DRHO '999,25 RHOB-999 25 CALl -999,25 GR -999,25 'TENS ~865, GR 69.6~5 ;P RCNT -999 25 CALI -999 25 GR 999 25 52 5 :5 Data 0 OEPT 31 D 5 NPH '999 5 TF.N$ '999.25 CA[,][ ~999'25 5 F 996 M SFLt) -999 25 IbP - TNRA -999 5 RTNR -999 DPHI -999 25 DR GR -999 25 -TENS ! bM RCFT R GR~33, 0 '~ ~ 4 '' ' .... Data record type DE'P~' 301 ,5 ~'i' 918,8196 D£;PT 3014:.5 SFLU -999,25 ~bD ~9:99:,25 ~bM ~999,25 SF -999,25 G~ -999~25 TENS -999,25 YENS -999,25 NP~I -999,25 TNR~ -999,25 RTNR-999,25 RCFT -999'25 RCNT -999,25 CFT( .... 999'25 CNTC -9~9~25 GR -999,25 '5 TENS-999,25 ~HI -999;2 DRH:O -9~9,~5 RHOB -999,25 CALl -999,25 GR -999,25 TENS 1765~ GR 39,25 Data recoro type 0 DEPT 2914,5 FT 888.3396 a DEPT ~914,5 6FbU -999,25 ILD -9g9,25 ILN -999 25 SP 999.25 GR -999,25 TENS -999,25 TENS -999 25 NPNI -999,25 TNRA -999,25 RTNR -999.25 RCFT -999 25 RCNT -999.25 CFTC-999.25 CNTC -999,25 GR -999 25 TE~S -999,25 DPHI '999,25 DRHO -999.25 RHOB -999 25 CALl -999.25 GR'999,25 TENS 1740. GR 51,4 625 DEPT 2814.5 SFLt! ~999,25 IbD -999,25 IbM -999 25 SP -999,25 GR 999.25 TENS -999.25 TENS -999 25 NPHI -999.25 TNRA!999'25 RTNR -999,25 RCFT -999 25 RCNT -999.25 CFTC 999.25 CNTC -999,25 GR -999 25 TENS -999,25 DPhI 9991 25 DRHO -999,25 RHOB -999,25 ~A,i,A! 2-1~!AR-88 12:51:57 Page 21 CALl -999,25 GR -999,25 TENS 1750, GR 58,40625 £)~':PT 271.4,5 SFX~I.j -999,25 IbD -999,25 ILM -999 25 SP -999,25 G~ -999 ~25 TENS '999,25 TENS '999~ ~5 NP~ -g99,25 TNRA -999 RTNR-9 T-999 25 RCN~I -999'25 CF~'TC:' -999' " CNTC' -9 R 25 TE~S -qg9~25 DP'}.tI -g99 D~HO -9 25 RHO.6 ~5 CALi -999,25 GR -999.:2.5 T. EN8" GR ~0:,~ ~:3i3 Data record type 0 DEf'T 2614.5:FT 796.89:9~ :a DE~26~4~.5--`--------------------------------------------~--------~----------~$F~`U-` ' o.~ , 99,25 GR -999,25 TENS '999;25 TENS -999,~5 NP)~{I -9'99,25 TNRA -999'25 RCFT -99.9~25 RCI~T -999,25 CFTC -999,~5 CNTC -999~25 GR -999,~5 TEMS -999,25 DPk!I -999'~5 DRHO-999'25 C~LI -999,25 GR ~9q9,25 .TENS 1005~ Data record type o DEPT 2514.5 FT 766.419b ~ SPDLP' -999,25 2514,5 GRSFbb 2999,25 IbD -999,25 fh~ -999,25 999,25 TENS -999,25 TENS -999,25 N~HI -999,25 TNR~ -g99,~5 RTNR -g99,25 RCFT -999;25 - 25 CFTC 999, RC~T -999,25 C~TC '-999'25 GR -999;25 CALITE>')$-999.25'999~25 DPHI ~_~999,~ DRHO-999.25 RHOB-999,25. Data record type 0 DE..T 2414. ~ .... 241;';~. ..... ~''~''~'~FL - . ........ 5 IBD''''''''''''''''-999.25 Ib~ ..... -999,''''~; ..... SP -999.~ GR ~g99,25 TENS -999,25 TENS -999,25 NPHI -999,25 TNRA~999,25 RT~tR -999.25 RCFT -999;25 RC~)T -999.25 CFTC 999.25 CNi~C -999,25 GR -999.25 TENS -999.25 DP~ -999,25 DRHO 999,25 RHOB -999,25 ...m.~.m mmmm.mmm Data record type 0 L~EPT 2314.5 FT 705.4596 ~i D'~';''''''P 2314.5 ....... ~'-';';[i~°.~ .... '''''''''''''''''''''''''''''''''''i.i.~D.. '999.25 ILM -999,25 SP '999.25 GR '999.25 TENS '999.25 TENS '999.25 T -999 G~ 99 5 TENS 148 35 Data record type 0 D~t~PT 2114,5 iT 644,4996 ~ SFLIi -999,25 NP[!! -999 25 TNRA -999,25 RCN. T ~999 25 CF~'C -999;25 TE~S -~9 25 [)PHI -999,~5 CAiLI -999 25 aR -999~R5 Data recoro type 0 OEP DEPT 2014.5 6FLU -999.25 Sp -999.25 G~ -999 25 TENS -999~25 TENS -999 25 ~PMI -999,25 TNR~-999 25 RTNR-999,~5 RCFT - 25 RCb.ll' -999,25 CFT~ -999 25 CNTC-999,25 GR - 25 TENS -999,25 DPHI -999 25 DRHO -999 CAI.,I -g99.25 GR -999 25 TENS ~470 GR 38.8_5 Data record type 0 DEPT 1914,5 FT 583.5396 M DEPT 1914,5 SFbU -99q 25 ILD -999.25 lb~ -999.25 SP -999,25 GR -999:25 TENS -999,25 TENS -999,25 ND~I 99q,25 T~RA -999,25 RTNR -999.25 RCFT -999,25 ~CN'T ~999,25 CFTC -999,25 CNTC -999,25 GR 999,25 T~N$ -999,~5 DP~I -999,25 DRHO -999,25 R~OB ~999,~5 CALf -999,25 GR -999,25 TENS 1430, GR 41,125 SP -999,25 R('NT-999 -999 C A l~ I G~ 1405 ~ 0 15 -9 25 IL~ -999 25 NPHI -999,25 TNR -9~ RCFT -999 25 RCNT '999~;25 GR w999 ~5 TENS -999,~25 {)PHI -999 25 DRH. O -999 RHOB -999 ~5 CALl -99:9~25 GR -999 25 TEN8 ~350 56, 5 record type 0 D~PT 1614,5~FT 492,0996 M 1614,5 SFLU -999 2:5 II~D -999,25 ib~ ~999,25 -999.25 GR -999 ~5 TENS -999,25 TENS -999,25 2 25 RCFT -999,25 TNR~ -999 5 RT~-999, %999,25 CFTC. ~ .~ -999 25 C~¢.~. ~ '&9~ ,25 GR -999'~5 999,25 DPH[ -999 25 DRHO -999.25 RHOB "999~ 25 -999 ~5 G~ 999 25 T~N$ 1~60 GR 27,4~1~8 ~ata record type 0 DEPT 1514.5 FT 461,6~.96 M DF. r 1.514 5 S~LU -999,25 ILD 999,25 ILN 999,25 SP -999,25 GR -999,25 TENS -999,25 TENS -99i[25 NPitI -909,25 TNRA -999.25 RTNR -999,25 RCFT -99 25 ~CNT ~999,25 CFTC -999,25 CNTC -999,25 GR -99 25 T~.;?~S 999,25 [~PHI -999,25 DR~O -999.25 RROB -99 25 CALI :999,25 :R -999,25 TENS 1320, GR 32,7~125 Data recor~ type 0 DEPT 1414,5 FT 4~1,1396 ~ D~PT 1414,5 SFLU -999,25 ILD -999,25 IbM -999,25 SI~ -999.25 G~ 'qg~e~5 TENS -999'25 TENS -999,25 NJ'HI -999,25 TNRA -~99,25 RTNR -999,25 RCFT -999025 ~CNT -999,~5 CFTC -999'25 CNTC -999,25 GR -999,25 TE!~$ -999,25 DPHI -999,25 DRHO 0999,25 RHOB -999,25 I)EPT 1314,5 SF[,U-999 25 ILO -999, SP :~999:,25 bR : -999 25 : TENS '999- NPH..I -99g,25 '~(NRA -999 RC~ -999125 CFTC -999 TEP,~S -999,25 DP?II -999 DRHO C~LI-999'2:5 GR 999 TENS Data record t¥.pe 0 DEPT 1214.5 FT 370.I796 M D~{iPT II14 .... SFLL, -999,25 fi;~ 999[!5 GR -999,25 ~PHI '999'25 T~,~¢~ -999,25 RTNR -999,25 ~.,{~t 999'25 C~I-~ -999,25 CNTC -999~25 TELLS -999,25 DPHI -999,25 DRHO -999.25 CALl -999.25 GR -999;25 TENS ~155. File Data recor DEPT 1014. SP -999, ¢~8 -999, trailer EDI d type 0 DEPT I014,5 FT 309.2196 ~ 5 SFbU 999,25 ILD '999.25 IbM -999,~5 25 GR ~999.25 TENS -999,~5 TE~S -999,25 25 TNR~ -999.25 RT~R -999,25 RCFT -999,~5 T ,001 LIST ~T(): [72620]LIS,~,.t)AT; 2-i~,!AR-~t{ 12;51:57 Page 25 *$ FILE TRAILER, ** FILE NA~',, : EDIt O0 SERVICE 5tA~E VERSION ~ DATE ~AX, REC, LMN, F'IL~ TY:PM MEXT FILE Logical EOF record File he6der EOIT . O02 FILE NA~4E : b:D1T SERVICE 74 A~q E : VERS IO~ ~ : D h T F, ~hX. REC. LEN,: 10~4 FILE TYPE : PREVIOUS FILE : .0 0 2 FLIC com{nent FLIC co.:merit FblC comment FLIC com~ent FLIC com~ent FLIC commemt Ft.,lC commer~t i')at a f ort',~a t Ti!lS FIL[e2 I~tC[,UDE ,1" SAMPLED DENSITY DATA FIELO PRINT FILE ~ f'l. C (HIGH RESOLUTION) specl, flcat:l or: record Listing of set 3 type 64E ENTRY VALUE REPCODE Si 2 0 6 . 4 I 66 1 ~ 12 73 4 9 ,1I~ 65 4 16 I 66 1 ~ 0 66 End Of set ~ oDject ZE : iD [~DE;R ~ LOG TYPE (:,bASS MOD NUmB ELE~ 8A~P CODE HEX) GR FDH DPHI FDH PU 0 0 I 1 635 :21 O,; O' ' I =- I 890 oo 0 0 I 1 4 68 oo00000000 420 Ol 0 0 I - I 4 68 0 0 1 I 4 68 0000000000 0 0 I' 4 0 0 1 I 4 6B 0000000000 0 0 :: I: I 4: 68 0:00:0000:000 0 0 1 1 4 6.8 0000000000 310 Ol 0 0 I I 4 0000 0 0 1 1 4 0 0 I :1 4 350 02 o o I I 4 280 O1 0 0 1 I 4 68 000000000'0 310 Ol 0 0 1 I 4 68 0000000000 890 O0 0 0 I 1 4 68 0000000000 End o/: set Data record type o DMPT 986i,5 FT 3005,785 Oa~a record type 0 DLPI 9761. ", .... 5 FT 2975.305 ~PT 9761.5 TENS 480 NPHI ~2.264 5 TNRA 2,961158 i'?~ 3.512279 RCFT O~ ~1~9 RC~ 2253.591 CFTC ~21.3567 t!(]B 2,266986 CALl. , 18~ Ga 82,5625 OPHI 23,22062 DP:Pr,,N 9661~ TE~$ 5304~868 i~PHI 40 22929 TNRA 3 407~3~ R.[ a 4,04 78 RCFT 437.~ RCNT 18i4.879 CFTC ~[912808 Ci~TC 1993,5b~ GR 113.8125 TENS 5304. DRHO O, 02603651 R~i()B 2,29244 CALl 9,359375 GR 113,8125 DPHI 21,6'1814 2-5iA~{-88 i2:51, fe 27 Data recorct [ .... Pi 4 FT 2 i5 M b~.Pt 9451,5 ,f NP TNRA ~:NO:B 2,423'28 · CAI~'I 9~ 875 : .G'R t16,:4375 DPH.I: :13:~74924 File t. raJler F, D1T .002 ** Fi[bE. {..'{{A!LE; ,m; SERVICE i<~A ~L : DATE : ~AX. REC. bEN.: 1024 FILE TYPE : NEXT FILE : FILE SLIN~ARY :ENC #D.R #FM PI PI_UNIT~ MAXPI MINPI ''''''''''''''''''''''''''''''''''''"'''''''''''''''''''''''''''''''''''''601 602 0 591 4131 DEPT FT 9861'5 9448,; DEPT M 3005.785 2879,903 DEPT ,lin 1183380. 1~33820, Logical ~OF record (EOF) Tape trailer ** TAPE TgAIbER ** SERVICE ~A~E : EDIT DATE ; 88/03/ 2 OPIGIN : FS!A TAPE NA~E : COnTInUATION ~: O1 NEXT TAPE : CO~ENI~ : 5C?~LiJ~BERGER bis TAPE (API~ 50-103-20097)3i~-22 A~CO t$ch,lumberger hIST MTO: [72620]bIS/¢ r,:,~,, Reel trailer 72620 ** [~EEL TRA'[ LE~t SERVICE NA~,E :: EDIT DATE : 88/03/ ORi GIN : R~.,EL -;AM~, : 72620 ~/EXT REEL : 8CItbUMBERGER COM~.EMT :: '" ARCO 28 bo~lcal EOF ~ecord Logical KOF recor~ LU SUN~ARY 2 I 1 4224 4226 End of listing i'.,~To: [7262o] l,]