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Home My WebLink About193-193Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#13IͲ09 50Ͳ029Ͳ21561Ͳ00 909619414 Kuparuk River Multi Finger CaliperField & Processed 6ͲOctͲ24 0 123JͲ02 50Ͳ029Ͳ21398Ͳ00 ALSL770Ͳ15 Kuparuk River Multi Finger CaliperField & Processed 8ͲSepͲ24 0 133MͲ26 50Ͳ029Ͳ22431Ͳ00 909593342 Kuparuk River Plug Setting Record FieldͲFinal 28ͲSepͲ24 0 145678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39697T39698T39699186-055185-163193-19310/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:53:44 -08'00'3MͲ2650Ͳ029Ͳ22431Ͳ00 909593342KuparukRiverPlugSettingRecordFieldͲFinal28ͲSepͲ2401T39699185 163193-193 WELL LOG TRANSMITTAL #905563101 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record: 3M-26 Run Date: 3/16/2019 1931:,3 30 93 4 May 23, 2019 JUN 2 7 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS ANC@halliburton.com 3M-26 Digital Data in LAS format, Digital Log Image file 50-029-21431-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: (1/z7) I I Signed: r1V.%##a1Vt:LJ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 17 P019 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operatio Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: POGLM PATCH INSTALL 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number. Name: ConocoPhillips Alaska, Inc. Development O Exploratory ❑ Stratigraphic❑ Service ❑ 193-193 3. Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-22431-00-00 7. Property Designation (Lease Number): e. Well Name and Number: KRU 3M-26 ADL 25522, ADL 25523 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NIA Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9,625 feet Plugs measured None feet true vertical 6,534 feet Junk measured None feet Effective Depth measured 9,522 feet Packer measured 2942, 2965, 9205 feet true vertical 6,453 feet true vertical 2496, 2509, 6209 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 16 121' MD 121' TVD SURFACE 4,841 feet 95/81, 4,882' MD 3624' TVD PRODUCTION 9,576 feet 7 9,615' MD 6526' TVD Perforation depth: Measured depth: 2956-2956. 9324-9358 feet True Vertical depth: 2503-2503. 6299-6325 feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 9,237' MD 6,233' TVD Packers and SSSV (type, measured and true vertical depth) UPR PKR (ME) - P2P UPR PKR 2,942' MD 2,496' TVD LWR PKR (ME) - P2P LWR PKR 2,965' MD 2,509' TVD PACKER - BAKER FBA PERM PACKE 9,205' MD 6,209' TVD SSSV - N/A 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 0 60 1200 Subsequent to operation: 126 924 2157 835 140 14. Attachments (required per 20 A C 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 1] Exploratory ❑ Development O Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil O Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Name: JIII Slmek Authorized Name: Jill Simek contact Email: Jill.Simek@cop.com Authorized Title: Staff Wells Engineer Contact Phone: (907) 263-4131 Authorized Signature: Date. Form 10-404 Revised 4/20 lfiL ¢�/9 1!/ RBDMS 18 2019 Submit Original Only APR J 3M -26A POGLM PATCH INSTALL DTTMST/JOBTYP SUMMARYOPS 3/18/19 DRILLING PULLED TEST TOOL FROM P2P @ 2965' RKB. LAY DOWN FOR SUPPORT - WIND. IN PROGRESS. CAPITAL 3/19/19 DRILLING ATTEMPT TO SET 3 1/2 POGLM @ 2942' RKB UNABLE TO SUPPORT - PASS 2.81 W-1 NIPPLE @ 2021' RKB FOUND XO ON POGLM CAPITAL 2.86" OD, XO WAS REPLACED, LOSE COMMUNICATION W/ RELAY TOOLS SWAP OUT W/ BACK UP TOOLS UNABLE TO FIND PROBLEM IN TIMELY MANNER. IN PROGRESS. 3/20/19 DRILLING SET 2.72 P2P PACKER POGLM ASSEMBLY @ 2942' RKB W/ DV SUPPORT - INSTALLED, MIT IA 2500 PASS, PULLED DV FROM POGLM @ CAPITAL 2950' RKB, SET 1" BTM LATCH OV (1/4" PORT) @ SAME, GOOD DRAW DOWN ON IA. COMPLETE. 3/26/19 ANNCOMM (AC EVAL) TIFL (PASS) -� KUP PROD WELLNAME 3M-26 WELLBORE 3M-26 'Phillips Conoco Alaska, Inc Well Attributes Max Angle & MD TD Field Name Wellbore API/uWl KUPARUK RIVER UNIT 500292243100 1 Wellbore S[atus PROD ncl (°) 6.75 MD (ftKB) 7,333.56 Ad Btm (FIRE) 9,625.0 Comment H2S SSSV: NIPPLE (ppm) Date Annotation LAST WO: End Date KB-Grd (ft) 41.00 Rig Release Date 1/17/1994 310-26, M16/2019 3:55:16 PM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) End Date Wellbore Last Mod By - -- --- ..... --- HANGER; 36.6 CONDUCTOR; 456121.0 NIPPLE; 2,021.2 UPR PKR (ME): 2,942.0 POGLM; 2,950.0 SPACER PIPE; 2,944.0 PERFP: 2,956.0 LWR PKR (ME); 2,985.0 SURFACE; 41.14,882.2- GAS LIFT; 9,153.3 LOCATOR; 9,202.8 PACKER; 9,205.3 8BE; 9,208 8 NIPPLE; 9,228.7 SOS; 9,238.3 Ll -01 LINER; 9,220.0-11,395.0 WHIPSTOCK -THRU TBG; 9,313.0 --- Last Tag: RKB 9,357.0 I 1/262019 3M-26 Itergusip Last Rev Reason Annotation 1 End Date 1 Wellbore I Last Mod By Rev Reason: Ped Tbg/Set POGLYM Assembly Iw2biwig 3M-26 IbmHhi Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (RKB) 43.0 Set Depth (RKB) Set 121.0 121.0 Depth (NO)... Wf/Len (I... 62.50 Gratia Him, Top Thread WELDED Casing Description SURFACE OD (in) 95/8 ID (in) 8.92 Top IRKS) 41.1 Set Depth (RKB) ISO 14,882.2 13,623.6 Depth (TVD)... IMLen (I... 136.00 Grade J-55 Tap Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top(RKB) 38.7 Set Depth(RKB)SN 9,614.7 6,525.6 Depm(ND)... Mien O... 26.00 Brad* L-80 Top Thread BTC -MOD Tubing Strings Tubing Description String me... TUBING 31/2 ID (in) 2.99 Top IRKS) 36.8 Set Depth (ft.. 9,237.2 Set DeptM1 (TVD) I... 6,233.3 M (Ibdt) 9.30 Grade J-55 Top Connection EUE8rdMOD Completion Details Top (TVD) Top Incl Nominal Top (RKB) (RKB) I") Item Des Com ID (In) 36.8 36.8 0.26 HANGER FMC GEN IV HANGER 3.500 2,021.2 1,903.0 37.25 NIPPLE CAMCO W-1 LANDING NIPPLE W/SELECTIVE PROFILE 2.812 9,202.6 6,207.0 40.37 LOCATOR BAKER GBH -22 LOCATOR SEAL ASSEMBLY 3.000 9,205.3 6,209.1 40.39 PACKER BAKER FB -1 PERM PACKER 4.000 9,208.6 6,211.6 40.41 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 9,226.7 6,225.3 40.49 NIPPLE CAMCO D NIPPLE NO GO, (MILLED OUT TO 2.80") 2.800 9,236.3 6,232.7 40.52 SOS I BAKER SHEAR OUT SUB 2.992 Other In Hole reline retrievable plugs, valves, pumps, fish, etc.) Top(RKB) Top (TVD) Top IRKS) Incl V) Des Com Run Data ID (in) 2,942.0 2,495.7 56.13 UPR PKR (ME) P2P UPR PKR (# CPP35178) 3/20/2019 1.625 2,944.0 2,496.8 56.13 SPACER PIPE 21116'P-110 w/ Anchor Latch Assy (# CPAL3511) 3/20/2019 18.21' OAL 1.640 2,950.0 2,500.2 56.12 POGLM 120" from top of P2P packer to top of bottom latch Ov 3/20/2019 (1/4"port) 1.560 2,965.0 2,508.5 56.11 LWR PKR (ME) P2P LWR PKR (# CPP35209, 4' OAL, 1.625" ID) 3/17/2019 1.620 9,313.0 6,290.8 40.82 WHIPSTOCK- THRUTBG NS HEW Tubing exit 2/20/2019 9,450.0 6,396.6 38.40 FISH 3 X 6 7/8 X 7/8 SLIP Lost from Air SLIP, was never 4/26/1994 found; Could be i0 hole Perforations &Slots TOp(f KB) Top(TVD) Blm(ftKB) IRKS) Blm(TVD) IRKS) Linked Zone Date Shot Dens (shotsRl 1 Type Co. 2,956.0 2,956.0 2,503.5 2,503.5 3/172019 PERFP 2" CIRC CHARGE (2 SHOTS, 0° PHASE) @ 2956 RKB 9,324.0 9,358.0 6,299.1 6,325.0 A-1, 3M-26 4/26/1994 4.0WERE 4 12" BH Csg Gun, 180 deg. phasing Mandrel Inserts 31 all °^ N Top(ftKB) Top(TVD) (RKB) Make Model 00 (in) Sery Valve Type Latch Port Type She (in) TRO Run (psi) Run Date Co. 1 9,153.3 6,169.3 CAMCO MMM 11/2 GAS LIFT DMV RK 0.000 0.0 6/3/1994 Notes: General & Safety Eno Date Annotation 7/28/2010 NOTE: View Schematic w/ Alaska Schematic9.0 KUP PROD WELLNAME 3M-26 WELLBORE 3M -26L1 r'� ConociPhillips Well Attributes Max Angle & MD TD Alaska, Inc. Field Name Wellbore KUPARUK RIVER UNIT 500292243160 APIIUWI Wellbore Status nc1(') PROD 5.51 MD(ftKB) Act Btm(RKB) 10,094.95 11,676.0 Comment H2S (ppm) Date Annotation End Date KB-Grd IN) Rig Release Data LAST WO: 41.00 1/17/1994 3M -28L1, 4/1620193:55:1] PM Last Tag Vertical schematic (actual) Annotation Depth IRKS) 1 End Date Wellbore Last Mod By Last Tag: 3M -26L1 jennait Casing Strings ......... Lasing Description L1 LINER IOD (in) 23/8 ID(in) 1.99 Top(ftKB) 9,609.3 Sat Depth(RKB) 11,676.0 SM Depth (WD)... WULen(I... 4.60 Grade L-80 Top Thread STL HANGER; 313.8 Liner Details Nominal ID Top IRKS) Top(WD)(ftKB) Tupincl(°) Item Des Cam (in) 9,609.3 6,326.0 94.27 ALUMINUM Aluminum Liner Top Billet with Open Hole Anchors 1.920 BILLET 9,629.5 6,324.7 93.13 ALUMINUM Aluminum Liner Top Billet with Open Hole Anchors 1.920 BILLET 9,641.3 6,324.1 92.43 DEPLOYMENT Shorty deployment sleeve 1.920 SLEEVE CONDUCTOR; 43.0.1210 Perforations & Slots Shot Dins Top (WD I Stm(WD) I (shotslft Top (RKS) Stm (ftKB) IRKS) (ftKB) Linked Zone Date ) Type Com NIPPLE; 2,021 2 8,642.0 11,654.0 6,324.1 6,322.0 A-1, 3M -26L1 7/25/2019 SLOTS Slotted Liner Notes: General & Safety End Date Annotation 4/1/2019 NOTE: View Schematic w/ Alaska Schematid0.0 UPR PKR (ME); 2,942.0 POGLM; 2,950.0 SPACER PIPE; 2,946.0 PERFP; 2,956.0 LWR PKR (ME): 2,965.0 SURFACE; 41.14,882 2— GAS LIFT, 9,1533 LOCATOR; 9,202 8 PACKER; 9,205.3 SBE; 9.208 ,6 NIPPLE; 9,nS,7 SOS; 9,236.3 PRODUCTION; 38.6-9,614.] SLOTS; 9,435.0_11.371.0- ,438.0.11,3]1.0 1_1-01 L1-01 LINER; 9,220.0.11,395 .0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED APR 0 4 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Op a ZQ Performed: Suspend E] Perforate E] Other Stimulate E] Alter Casing El Change/ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CO261 B WHIPSTOCK El 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 17 Stratigraphic❑ Exploratory ❑ Service ❑ 193-193 3. Address: P. 0. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-029-22431-00-00 7. Property Designation (Lease Number): e. Well Name and Number. KRU 3M-26 ADL 25522, ADL 25523 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. FieldlPool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9,625 feet Plugs measured None feet true vertical 6,534 feet Junk measured 9450 feet Effective Depth measured 9,522 feet Packer measured 9,205 feet true vertical 6,453 feet true vertical 6,209 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR —78 feet 16 121' MD 121' TVD SURFACE 4,841 feet 95/81, 4,882' MD 3624' TVD PRODUCTION 9,576 feet 7 9,615' MD 6526' TVD Perforation depth: Measured depth: 9324-9358 feet True Vertical depth: 6299-6325 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 9,237' MD 6,233' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER FBA PERM PKR 9,205' MD 6,209' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA 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: 2 2 277 600 1 88 Subsequent to operation: 127 125 2172 805 158 14. Attachments (required per 20 MC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development O Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil O Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 319-039 Contact Name: William Long Authorized Name: William Lon Contact Email: William. R. Long@cop.com Authorized Title: Sr. CTD Engin e Contact Phone: (907) 263-4372 Authorized Signature: Date. / Form 10-404 Revised 4/2017 VTL 411011,7 RBDMS-I±'-/APR 0 5 2019 Submit Original Only � �el� 3M-26 Final CTD Schematic 16" 62# H-40 shoe @ 121' 9-5/8" 36# J-55 shoe @ 4882' MD IKOP @ 9313' MD via 7" wedge perfs 9358' MD F7-'726# L-80 shoe @ 9614' MD 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface 3-1/2" Camco W-1 Landing Nipple @ 2021" RKB (2.812" min ID) 3-1/2" Camco MMM gas lift mandrel @ 9153' RKB Baker GBH -22 Locator Seal Assembly @ 9202' RKB (3.0" ID) Baker FBI Perm packer @ 9205' RKB (4.0" ID) Baker SBE @ 9209' RKB (4" ID) 3-1/2" Camco D Nipple @ 9227' RKB (Milled Out to 2.80") Baker SOS @ 9236' RKB (2.992" ID) 3-1/2" tubing tail @ 9237' RKB 3M-2611-01 TD @ 11,395' MD Liner Top @ 9220' MD 3M-261-1-01PB1 TD @ 10,577' MD Billet @ 9703' MD W-2611 TD @ 11,676' MD Failed Billei @ 9630' MD Billet @ 9608' MD Conoco`Phillips Alaska. Im KUP PROD WELLNAME 31111-26 WELLBORE 3M-26 AST WO: a.-SE,1K3c0192,O866PM Last Tag vsreralWwmlc (eseyB Anlwtation oeptnlnKa) I End Dale Wellnore Lep Moe ey Last Tag: RKB 9,35)0 112612019 lnm,o Wrgusp ........_...... ......... ....... ... Last Rev Reason Annotabou EM Dah W*K Last Mad By NhYGEa; ffie Rev Reason Pell TbglSetPOGLVM Assembly 32Y2019 3M-26 bwoMi Geeing Strings Casin90e:e.ip4un oo 0n1 mOn) Top lmcel se, Ozpm lnKel Bp DepB11TVO1.. vNLen 0... 0eaae lop Tnrcm CONDUCTOR 1fi 1506 43.0 121.0 121.0 fi2.50 H40 WELDED Ceslnp 0eacriplion OD (ln) ID lin) Top IMLB) Set Death (IIBBI Set OepM IT/D)... WN.en D... GrMo Top TnrteO SURFACE 9510 8.92 41.1 4,862.2 3,823.6 36 On J-55 BTC tugs, Devoeptlal ODlin) IDen) Tol"Mup SplkpN(fiBBI aat Man IIVDITied en 11... 6,Ne TOPTM1netl PRODUCTION ] 628 381 9,614.] 6.525.6 26D0 L-80 BTC -MOD Tubing Strings Tubug Desnipbun smlq Me.TDian) TOPMKBI PS Deptn 1p.Sel DepM/ND11...V1yIWa1 eraee TOPconllection TUBING 312 2.99 368 9,23)2 Q2333 9.30 J-55 EUE6rtlMOD naxoucroS:4aa+mu Completion Details TOP(NOI Top Incl Nominel TOP(KKBI ('So) fl Item a- Cam ID lint 36.8 368 026 HANGER FMC GEN IV HANGER 3.500 NIPPLE: 2. 2,0212 1,903. 3725 NIPPLE CAMCO W -HANDING NIPPLE WI SELECTIVE PROFILE 2812 2026 6,20)0 40.37 LOCATOR BAKER GBH -22 LOCATOR SEAL ASSEMBLY 3.000 9,205.3 6,209.1 4039 PACKER BAKER FB -1 PERM PACKER 4.006 UPS PIw IME): 2,w2D 0208.6 6,211.6 4041 SBE BAKER 8040 SEAL BORE EXTENSION 4000 &226NI .] 6225.3 4049 PPLE CAMCO DNIPPLE NO GO. (MILLED OUT T0280") 2.800 9.2363 62327 40.52 SOS BAKER SHEAR OUT SUB 2.992 PGGLM,29500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) SPACES PIPE: 2,ab0 Top n V.) Topinel PERFP; 28%0 Top(..) To PI Des Cam pun M. IS (,a) 2,942.0 2,495.] 56.13 UPR PKR (ME) P2P HER PKR (M CPP351]8) 312012019 1.625 LwR VKa (MEk 29M.a 05613SPP-wlcM1aM1AssypAL 11)2,944.0 2 32612019 1,646 18.21' GAL 2,950.0 2,500.2 58.12 POGLM 120' hom lop .1 P2P paUeno tap of bpnom IatCM1 Ov3202019 1.560 (114 TOO) 2,965.0 2.5085 56.11 LWR PKR (ME) P2P LWR PKR (p CPP35209, 4' OAT, 1 625" ID) Y1712019 1 Uo 9,313.0 6.2908 40V WMITNTUCK- NS HEW Tubing exit 2/TM19 THRU TBG SURPACE41. 1y8622— 74500 6,396.6 38.40 FISH 3 X 6 718 X 718LIP Last from Air SLIP,was never 42N1994 found; could be in had, Perforations & Slots Wa LIFT; 9,1. u a- Dens TapamOl den mtel Top(NO) (nKBI Bnn (fV01 aBLB) t:nXedmne Saba Isnotam ) aide 27WO 2,95fi.0 ,503.5 2,5113.5 3112019 PERFP CHARGE (2 SHOTS, 0° PHASE) 2956 RKB LDcnioS: e.2oze 9,34.0 9,358.0 9.1 6,325.0 A-1, M-26 42Y1994 40 IPERF H ag On180 deg. Phasing PACKEK%aX,a Mandrel Inserts see... an aU H Top WIh Tep (TV01 pKS) Ma. MOMI OD(inl Sery Valve Type tatcM1 Type Pwt Size TFO dun (ln) leadpun no tom 1 9,153.3 6,169.3 CAMCO MMM 112 GAS LIFT DMY RK 0.000 0.0 613/1994 Notes: General & Safety End DaveAiinohl- P28I2010 NOTE: View Schematic el Alaska ScnemandviU xlwLe a.226.T SOS ', 8.26.9 L1,01 LAVER: 92A.611.395.0 WI-PSTCCK-THRUTEG', %S13.— 3130932404,3Mk0—FISH ..04,36h.— via.S PROI=I.KY.6B614.1 e Operations Summary (with Timelog Depths) } 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log $tariTMe End Time put (hr) Phase Op Code Activity Code Time P -T -X Operation Stars Depth (RKB) End Depth(XKB) 2/18/2019 2/18/2019 1.70 MIRU MOVE DMOB P Complete RD from 1J-10, load out 0.0 0.0 11:00 12:42 DTH trucks, secure rig landings and stairs, secure cellar 2/18/2019 2/18/2019 1.00 MIRU MOVE RURD P Trucks arrive at 12:45PM, load up 0.0 0.0 12:42 1342 shop & 1/2 -Way house, offload last of fluids 2/18/2019 2/18/2019 1.60 MIRU MOVE RURD P PJSM, pull sub & pits off well 0.0 0.0 13:42 15:18 2/18/2019 2/18/2019 1.00 MIRU MOVE MOB P Move from 1J -Pad to 3M -Pad (20.7 0.0 0.0 15:18 16:18 miles) 2/18/2019 2/18/2019 2.30 MIRU MOVE MOB P Hold up at J pad access road per 0.0 0.0 16:18 18:36 security 2/18/2019 2/19/2019 5.40 MIRU MOVE MOB P Continue to move from 1J -Pad to 3M- 0.0 0.0 18:36 00:00 Pad (20.7 miles) 21:00 @ the Y 22:00 @ 1Q 23:15 @ CPF3 BEGS turn at midnight 2/19/2019 2/19/2019 2.20 MIRU MOVE MOB P Arrive on pad. 0.0 0.0 00:00 02:12 2/19/2019 2/19/2019 1.00 MIRU MOVE MOB P Meet W DSO, receive permission to 0.0 0.0 02:12 0312 spot over well. Go on jack, drop assist & primary sows. De jeep. 2/19/2019 2/19/2019 0.90 MIRU MOVE MOB P While prepping herculile discover Ops 0.0 0.0 03:12 0406 has built two temporary well enclosures around stick built scaffolding that are narrower than our cellar and an gas line, Cat heater jumper, has been run between both adjacent wells that we can not clear with the cellar. 2/19/2019 2/19/2019 2.00 MIRU MOVE MOB P Spot sub over well 0.0 0.0 04:06 06:06 2/19/2019 2/19/2019 1.10 MIRU MOVE MOB P Spot service unit 0.0 0.0 06:06 0712 2/19/2019 2/19/2019 2.80 MIRU WHDBOP RURD P Work rig up check list, walkways, 0.0 0.0 07:12 10:00 Berming, RU PUTZ, steam, Duck ponds. 2/19/2019 2/19/2019 1.50 MIRU WHDBOP NUND P Nipple up, Check tree bolts, C/O 0.0 0.0 10:00 11:30 risers, harvest RKBs, 2/19/2019 2/19/2019 1.00 MIRU WHDBOP RURD P Complete rig up, take on sea water 0.0 0.0 11:30 1230 Rig Accept 12:30 2/19/2019 2/19/2019 1.00 MIRU WHDBOP RURD P Fluid pack and shell test 0.0 0.0 12:30 1330 2/19/2019 2/19/2019 8.00 MIRU WHDBOP BOPE P Test ROPE. 250/4000 psi, AOGCC 0.0 0.0 13:30 21:30 Witness Jeff Jones. Fail pass Tango #2- grease and retest, Romeo #2 Fail / Pass. 2/19/2019 2/19/2019 1.00 MIRU WHDBOP PRTS P Test PDL's and tiger tank line 0.0 0.0 21:30 22:30 2/19/2019 2/19/2019 0.50 MIRU WHDBOP PRTS P With PDL on stump, open master 0.0 0.0 22:30 2300 valve, WHP 1,400 psi, line up to tiger tank line, bleed off gas to 1,000 psi, shut in blow down tiger tank line, WHP back up to 1,400 psi. 2/19/2019 2/19/2019 0.75 PROD? RPEQPT PULD P PJSM, PU BHI tools and load into 0.0 0.0 23:00 23:45 PDL, 2/19/2019 2/20/2019 0.25 PROD1 RPEQPT PULD P PJSM, PU HEW 0.0 0.0 23:45 00:00 2/20/2019 2/20/2019 1.00 PROD1 RPEQPT PULD P Continue PU HEW 0.0 0.0 00:00 01:00 Page 1116 Report Printed: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stert7ime End Time our (hd Phase Op Code Activity Code Time P-T-X Oparabon Sfert Depth (WS) Eno Depth (WIS) 2/20/2019 2/20/2019 0.50 PRODt RPEQPT PULD P Slide cart forward, install float valves 0.0 73.5 01:00 01:30 into UQ, MU to CoilTrak tools, perform surface test (good-test) 2/20/2019 2/20/2019 2.20 FROM RPEQPT TRIP P RIH, with open EDC, pumping min 73.5 8,970.0 01:30 03:42 rate 0.39 bpm at 1,433 psi, WHP=1,304 2/20/2019 2/20/2019 0.50 PROD1 RPEQPT DLOG P Log formation looking for the HRZ 8,970.0 9,112.0 03:42 04:12 1 correction plus 3.5' 2/20/2019 2/20/2019 0.20 PROD1 RPEQPT TRIP P Continue IH 9,112.0 9,214.0 04:12 04:24 1 2/20/2019 2/20/2019 0.33 PROD1 RPEQPT DLOG P Attempt to log the K1, couldn't see it. 9,214.0 9,345.0 04:24 04:43 continue IH past setting depth to 9,345' 2/20/2019 2/20/2019 0.20 PROD1 RPEQPT TRIP P PUW 41 k, Pull up hole to 9,260' 9,345.0 9,260.0 04:43 04:55 2/20/2019 2/20/2019 0.25 PROD1 RPEQPT DLOG P Log CCL from 9,260'-9340', correlate 9,260.0 9,343.0 04:55 05:10 logs. 2/20/2019 2/20/2019 0.40 PRO01 RPEQPT WPST P RIH to setting deph, TOWS @ 9312'. 9,343.0 9,312.0 05:10 05:34 Close EDC, Online w pump, see tool shear @ 3899 psi. SID 5.3 k lbs, PU clean, 35.9 k lbs 2/20/2019 2120/2019 1.80 PROD1 RPEQPT DISP P Open EDC, line up on milling fluid at 9,312.0 9,227.0 05:34 07:22 2.45 bpm. PUH slowly as milling fluid is pumped to the bit. 2/20/2019 2/20/2019 0.20 PROD1 RPEQPT TRIP P POOH chasing milling fluid to surface. 9,227.0 7,539.0 07:22 07:34 2/20/2019 2/2012019 1.60 PROD1 RPEQPT RGRP T Stop, investigate marks on coil. Some 7,539.0 7,245.0 07:34 09:10 light gouging indicative of slipped blocks while pulling up hole. Observed out of hole torque fluctuating in an abnormal manor. Performed visual inspection of injector no obvious issues, some cracked elastomers. Roll out of hole slowly, observed new larger set of gouges, 7448' form EOP, filed and flagged green. Re Inspected chains, slowly pulled out of hole while power washing. One gripper block came out of it clip from the pressure washer force. Stopped, repaired. Found retainer clip smashed, no spring memory. PUH slowly, no indications of issues. PUH -200' with no pipe marks. 2/20/2019 2/20/2019 0.90 FROM RPEQPT TRIP P POOH, no indicaion of new marks, out 7,245.0 2,866.0 09:10 10:04 of hole torque stable. 2/20/2019 2/2012019 2.40 FROM RPEQPT RGRP T Sudden stop, SCADA System locked 2,866.0 2,866.0 10:04 12:28 out the storage reel and injector. Error code - Injector motor differential speed detected or possible slip. Investigated and found the right angle drive drillers side encoder had seized. The drive shaft to the encoder had sheared off. Parked, closed bag, replaced encoder PUH slowly inspecting pipe, all clear. 2/20/2019 2/20/2019 0.60 FROM RPEQPT TRIP P POOH 2,866.0 85.0 12:28 13:04 2/20/2019 2/20/2019 1.00 FROM RPEQPT PULD P PUD and LD BHA#1, whipstock 85.0 0.0 13:04 14:04 setting assembly. 2/20/2019 2/20/2019 1.00 PR0D1 WHPST PULD P PU and PD BHA#2 Window milling 0.0 76.0 14:04 15:04 assembly, V Weatherford fixed bend motor, string mill 2.79" no go, DSM 2.80 no go. Inspect pack offs - good. Page 2116 Report Printed: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Sten lima End Time Dat (ho Phase Op cme Activity CMe Tme P -T -X Operation (WB) End Depth (nKB) 2/20/2019 2/20/2019 2.60 PROD1 WHPST PULD P RIH, park @ 344', close EDC, 0.0 9,050.0 15:04 17:40 continue to RIH pumping 1.03 bpm, holding 12.1 ppg EMW maintaining 1 for 1 returns. Start encountering damaged pipe @ 7892 bit depth, 7822 Epic End of Pipe four whip end. Additional @ Set down @ 8001, 8250, 2/20/2019 2/20/2019 0.20 PROD1 WHPST DLOG P Log formation from 9,050'-9,084', 9,050.0 9,084.0 17:40 17:52 correction of plus 3.0', PUW 36 k 2/20/2019 2/20/2019 0.15 PROD1 WHPST TRIP P Continue IH, dry lag pinch point at 9,084.0 9,317.0 17:52 18:01 9,316.8', PUH, obtain pump parameters 2/20/2019 2/20/2019 3.80 PROD1 WHPST MILL P Start Milling window exit, 1.84 bpm @ 9,317.0 9,320.0 18:01 21:49 3.900 psi, Diff -596, WHP=551, BHP=3,997, IA=950, OA=888 2/20/2019 2/20/2019 1.35 PROD1 WHPST MILL P Stall motor, PUH and restart, 1.79 9,320.0 9,321.0 21:49 23.1Jj„ / bpm at 3,962 psi, Diff --649, WHP=535, IA=950, OA=889 (f� `•. Note: Bleed down IA and OA 20/20 2/20/2019 0.60 PROD1 WHPST MILL P Drill rat hole, 1.8 bpm at 3,883 psi, 9,321.0 9,327.0 23:10 23:46 Diff -630, WHP=553, BHP=3,953, IA=614, OA=723 2/20/2019 2/21/2019 1 WHPST REAM P TD rat hole 9,327', PUH 33 k, Ream 9,327.0 9,327.0 23:46 00:00 window exit @ HIS TF. / - 2/21/20192019 1.50 PROD1 WHPST REAM P Continue reaming window exit HIS, 30° 9,327.0 9,270.0 00:00 [� 0 '3 LOHS, 30° ROHS, 180°, perform dry y1/ P drift (dean), open EDC 1/2019 2/21/2019 0.30 PROD1 WHPST TRIP P Shut down pump, open EDC, 3,948 9,270.Q 9,270.0 01:30 01:48 1 1 1 psi BHP, 12.06 ECD 2/21/2019 2/21/2019 2.00 PROD1 WHPST TRIP P POOH, chasing sweep to surface 9,270.0 77.3 01:48 03:48 2/21/2019 2/21/2019 1.50 PROD1 WHPST PULD P PJSM, PUD 8 LD milling assembly 77.3 0.0 03:48 05:18 2/21/2019 2/21/2019 1.00 PROD1 DRILL CIRC T MU noule, Stab onand roll coil to 0.0 0.0 05:18 06:18 water. Crew swap 2/21/2019 2/21/2019 1.00 PROD1 DRILL DISP T PJSM, Halliburton N2 rigged up and 0.0 0.0 06:18 07:18 PT'd to 4000 psi. Blow down reel w 1500 SCF/min foor 10 min, trap pressure, Blow down surfce lines, R/D halliburton. 2/21/2019 2/21/2019 1.40 PROD1 DRILL CTOP T Prep grapple end and string wire rope 0.0 0.0 07:18 08:42 while bleeding down coil 2/21/2019 2/21/2019 0.30 PROD1 DRILL CTOP T R/D inner reel iron, unstab break off 0.0 0.0 08:42 09:00 Upper quick connect, cut off CTC. 2/21/2019 2/21/2019 0.50 PROD1 DRILL CTOP T Install grapple 0.0 0.0 09:00 09:30 2/21/2019 2/21/2019 2.00 PROD1 DRILL CTOP T Lock out reel break out inner reel iron / 0.0 0.0 09:30 11:30 bulkhead, Pull test grapple, PJSM 2/21/2019 2/21/2019 1.70 PROD1 DRILL CTOP T Secure coil, cut excess 0.0 0.0 11:30 13:12 2/21/2019 2/21/2019 0.60 PROD1 DRILL CTOP T Suspend reel, remove saddle clamps. 0.0 0.0 13:12 13:48 2/21/2019 2/21/2019 0.70 PROD1 DRILL CTOP T Skid cart,instal stripper pole, drop 0.0 0.0 13:48 14:30 stripper, lay over and drop cart. 2/21/2019 2/21/2019 1.20 PROD1 DRILL CTOP T Swap gripper blocks, elastomers, 0.0 0.0 14:30 15:42 clips, replace strippper brass, pick up stripper. 2/21/2019 2/21/2019 1.00 PROD1 DRILL CTOP T PJSM w crew and Peak truck drivers. 0.0 0.0 15:42 16:42 Drop od reel on truck. Page 3116 Report Printed: 4/312019 Operations Summary (with Timelog Depths) eT. 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time End Time our (ho Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth(Wtih 2/21/2019 2/21/2019 1.30 PROD1 DRILL CTOP T Prep and pick new storage reel # 0.0 0.0 16:42 18:00 52794 2/21/2019 2/21/2019 2.25 PROM DRILL CTOP T Secure reel into saddles, remove 0.0 0.0 1800 2015 rigging, shiim reel, torque to spec, install graple, remove reel wrapping, and pull test. 2/21/2019 2/21/2019 0.25 PROD1 DRILL CTOP T PJSM, stab coiled tubing through 0.0 0.0 20:15 20:30 INJ H, apply traction 2/21/2019 2/21/2019 2.50 PROD1 DRILL CTOP T Install inner reel iron, sim-ops load out 0.0 0.0 20:30 23:00 banding and material from bomb -bay door. install king pin. 2/21/2019 2/22/2019 1.00 PROD1 DRILL CTOP T Install Bolster, spill dikes, position reel 0.0 0.0 23:00 0000 for installing iron, remove grapple 2/22/2019 2/22/2019 3.00 PROM DRILL CTOP T Continued installing inner reel iron, 0.0 0.0 00:00 0300 CTES counter 2/22/2019 2/22/2019 1.50 PROD1 DRILL CTOP T Ream Seam from coil, install CTC, 0.0 0.0 03:00 0430 head up BHI UQC 2/22/2019 2/22/2019 2.50 PROD1 DRILL CTOP T MU High Pressure Bulkhead inside 0.0 0.0 0430 0700 reel, and test a -line, tighten & secure inner reel iron 2/22/2019 2/22/2019 1.20 PROD1 DRILL CTOP T Skid reel, PU pump in sub place on 0.0 0.0 07:00 0812 stump,BO nozzle, pull test 35 k good. Check CTC. MU nozzle stab injector 2/22/2019 2/22/2019 5.20 PROD1 DRILL CTOP T C/O pack offs, lock reel install CTES 0.0 0.0 08:12 13:24 counter, PJSM W LRS pump 5 MIS MethOH min rate, chase w water. 2/22/2019 2/22/2019 2.40 PROM DRILL CTOP T BO nozzle, cut off CTC, boot wire, 0.0 0.0 13:24 15:48 Line up to reverse circulate, PT inner reel iron, one leak, hammer up, test inner eel iron and stripper, bleed off. ramp to to 2.5 bpm X5, no indication of wire movement. 2/22/2019 2/22/2019 2.20 PROD1 DRILL CTOP T PJSM, unstab, start cutting pipe to 0.0 0.0 15:48 18:00 remove shipping dammage. "` Note: Trim 378' Coiled Tuibing, (New Length= 18,028745.7 bbl Vol) 2/22/2019 2/22/2019 1.20 PROD? DRILL CTOP T Test a -line (good -test), Dress coil, 0.0 0.0 18:00 19:12 Install CTC, PT 35 k 2/22/2019 2/22/2019 1.25 PROD1 DRILL CTOP T Re -head BHI UQC, test a -line (good- 0.0 0.0 19:12 20:27 test) 2/22/2019 2/22/2019 0.30 PROM DRILL CTOP T PT re -head to 4,500 psi, Break off pull 0.0 0.0 20:27 2045 plate 2/22/2019 2/22/2019 2.30 PROM DRILL CTOP P PJSM, PU/PD build section assembly 0.0 72.2 20:45 23:03 2/22/2019 2/22/2019 0.30 PROD1 DRILL CTOP P MU to BHI CoilTrak tools„ perform 0.0 72.2 23:03 23:21 surface test (good -test), stab INJH, tag up, reset counter depths. 2/22/2019 2/23/2019 0.65 PROD1 DRILL CTOP P RIH 72.2 5,035.0 23:21 00:00 2/23/2019 2/23/2019 0.75 PROD1 DRILL TRIP P Continue IH 5,035.0 8,885.0 00:00 00:45 2/23/2019 2/23/2019 0.70 PROD? DRILL DLOG P Log formation correction of plus 93.5' 8,885.0 9,085.0 0045 01:27 2/23/2019 2/23/2019 0.45 PROM DRILL DRLG P OBD, 1.9 bpm at 4078 psi, Diff=490 9,085.0 9,390.0 01:27 01:54 psi, WHP=489, BHP=3,979, IA=66, OA 25, stall motor twice getting started, 9,329' and 9,342' 2/23/2019 2/23/2019 0.15 PROD1 DRILL WPRT P t Stall motor, PUH and restart 9,390.0 9,390.0 01:54 0203 Page 4/16 Report Printed: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time our (hr) Phase Op Code AcbWy Code Time P.T.X Operaean (WS) End Depth(flKB) 2/23/2019 2/23/2019 5.90 PROD1 DRILL DRLG P BOBO, 1.85 bpm at 3,888 psi, 9,390.0 9,530.0 02:03 07:57 Diff -521 psi, WHP=349, BHP=3,976, IA=241, OA209, Stall motor, PUH and restart X2, BOBO, 1.85 bpm at 3,888 psi, Diff --521 psi, WHP=349, BHP=3,976, IA=241, OA209 Crew change. PU and restart, PU Wt 35 k lbs RIH Wt 15k lbs, C14010 psi @ 1.88 in 1.88 out WH 497 psi, IA 578 psi, OA 633 psi, OBD, diff 497 psi. WOB 31k lbs, ROP 3-5 fVhr, in ankerite, break out @ 9496' Drill ahead, stage 5x5 low high( of the bit in anticipation of TD. '• TD build - 9530' 2/23/2019 2/23/2019 2.10 PROD1 DRILL TRIP P PU Wt 34 k lbs. 9,530.0 77.0 07:57 10:03 Saw -2.4 and - 3.3k WOB tug @ 9405 & 9395' respectively. Widow clean, Park at 9241', open EDC, continue to POOH Park at 6071', inspect reel bolts, find saddle clamps a little loose on DS. - 8 min Continue to POOH, 2/23/2019 2123/2019 1.00 PROM DRILL PULD P PUD, holding 12.1 ppg EMW, well is 77.0 0.0 10:03 11:03 very tight. LD BHA #3 Bit came out 2/23/2019 2123/2019 1.00 PRODt DRILL PULD P PU and PD BHA #4, ).5'AKO under 0.0 78.0 11:03 12:03 an NOV agitator and hyc A3 bit. Skid cart, check pack offs - good. Inspect and retorque iner reel iron. Bump up and set counters. 2/23/2019 2/23/2019 1.70 PROD1 DRILL TRIP P RIH to 500', Park, Close EDC, Shallow 78.0 9,030.0 12:03 13:45 test agitator. 2123/2019 2/23/2019 0.50 PROD1 DRILL DLOG P Logged the peaks of tie in for+6' 9,030.0 9,380.0 13:45 14:15 correction Logged RA tag in BOWS - 2/23/2019 2/23/2019 0.20 PRODi DRILL TRIP P Continue to RIH through build 9,380.0 9,530.0 14:15 14:27 2123/2019 2/23/2019 0.30 PROD1 DRILL DRLG P RIH CT Wt 16.7 k lbs, CT 4704 psi, @ 9,530.0 9,580.0 14:27 14:45 1.88 bpm in and 1.88 bpm out holding 12.0 ppg EMW @ the vandow, Annular 3997 psi, Diff 1097 psi, OBD, CT Wt 1 k lbs, WOB 1.31 k lbs, ROP - 121 ft/ hr. 2/23/2019 2/23/2019 0.75 PROD1 DRILL TRIP T PU wt 32 k lbs, Issue with MWD, TVD 9,580.0 9,580.0 14:45 15:30 calculation has a glitch. Rebook MWD computer. PUH slowly to 9266'. Get restarted, all systems go, RBIH, 2/23/2019 2/23/2019 2.00 PROM DRILL DRLG P CT 3991 psi @ 1.88 bpm in and 1.88 9,580.0 9,695.0 15:30 17:30 bpm out, diff 1067 psi, BHP 4613 psi 12.0 EMW @ the window. CT Wt 13 k lbs, WOB 2.6 k lbs, ROP 150 ft/hr WH 430 psi, IA 631 psi, OA 683 psi, 2/23/2019 2/23/2019 3.25 PROD1 DRILL DRLG P OBD, 1.9 bpm at 4621 psi, Diff=1,068 9,695.0 9,987.0 17:30 20:45 psi, WHP=435, BHP=3,991, IA=988, OA=977, •" Note: On-site Geo calling fault crossing 9,900' 2/23/2019 2123/2019 0.40 PROD1 DRILL WPRT P Wiper to the EOB, PUW 35 k 9,987.0 9,530.0 20:45 21:09 1 1 2/23/2019 2123/2019 0.30 PROM DRILL WPRT P Wiper back in hole, RIW 14 k 9,530.0 9,987.0 21:09 21:27 I I Page 5/16 Report Printed: 413/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth StartTime End Time DU (hr) Phase Op Code Activity Code Lme P -T -X Operation (MB) End Depth rtKB) 2/23/2019 2/24/2019 2.56 PROD1 DRILL DRLG P OBD, 1.9 bpm at 4621 psi, Diff=1,100 9,987.0 10,113.0 21:27 0000 psi, WHP=443, BHP=3,997, IA=988- 435, OA=977-621, Bleed down IA and OA 2/24/2019 2/24/2019 1.00 PROD1 DRILL DRLG P OBD, 1.8 bpm at 4,817 psi, Diff=1,281 10,113.0 10,129.0 00:00 01:00 psi, WHP=443, BHP=3,992, IA=545, OA=725 2/24/2019 2/24/2019 1.00 PROD1 DRILL DRLG P OBD, 1.76 bpm at 4,834 psi, 10,129.0 10,139.7 01:00 02:00 Diff=1,281 psi, WHP=443, BHP=3,997, IA=617, OA=795 2/24/2019 2/24/2019 1.00 PROD1 DRILL DRLG P OBD, 1.8 bpm at 4,895 psi, Diff=1,281 10,139.7 10,297.0 02:00 03:00 psi, WHP=444, BHP=3,994, IA=618, OA=795 2/24/2019 2/24/2019 1.17 PROD1 DRILL DRLG P OBD, 1.85 bpm at 5,009 psi, 10,297.0 10,418.0 0300 0410 Diff=1,527 psi, WHP=424, BHP=4,004, IA=639, OA=809 2/24/2019 2/24/2019 0.55 PROD1 DRILL WPRT P Wiper up hole into the casing, PUW 10,418.0 9,330.0 0410 0443 35 k 2/24/2019 2/24/2019 0.40 PROD1 DRILL WPRT P Pull through window at reduced speed 9,330.0 9,246.O 04:43 0507 10 fpm @ 0.40 bpm, jogged the the 7 inch, 9,246'-9,300' with sweep, RIH to logged depth 2/24/2019 2/24/2019 0.20 PROM DRILL DLOG P Log the RA marker correction of+1.5' 9,340.0 9,370.0 05:07 05:19 2/24/2019 2/24/2019 0.40 PROD1 DRILL WPRT P RIH after tie in wiper, RIH Wt 32 k Has 9,370.0 10,418.0 05:19 05:43 2/24/2019 2/24/2019 2.50 PROD1 DRILL DRLG P Ct 48483 psi @ 1.88 bpm in, 1.88 bpm 10,418.0 10,816.0 05:43 08:13 out, BHP 3975 psi, holding 12.0 ppg EMW at the window. Diff pressure 1209 psi, WH 351 psi, IA 778psi, OA 891 psi. OBD, CT Wt 9.9 k lbs, WOB 2.3 k lbs, ROP PU 10640'35 k Ibs PU 10785'- 36 k lbs ROP 160 ft/hr 2/24/2019 2/24/2019 0.40 PROM DRILL WPRT P PUWt 34 k Has 10,816.0 9,816.0 08:13 08:37 Slight neg WOB tug @ 10200' with a - 40 psi increase in annular pressure 2/24/2019 2/24/2019 0.40 PROM DRILL WPRT P RBIH 9,816.0 10,816.0 08:37 0901 2/24/2019 2/24/2019 0.80 PRODt DRILL DRLG P CT 4867 psi, @ 1.88 bpm in and 1.88 10,816.0 10,924.0 09:01 0949 bpm out. BHP 3990 psi holding 12.0 ppd EMW @ the window. Diff 1213 psi, WH 391 pi, CT Wt 5 k lbs, WOB 2 k lbs 10925', 2/24/2019 2/24/2019 2.70 PROM DRILL DRLG P PU Wt 36k lbs, on something hard 3.8 10,924.0 10,959.0 09:49 12:31 Is WOB, 10f/hr Drill ahead in akente 2/24/2019 2/24/2019 2.40 PROD? DRILL DRLG P Break out of ankerite. Ratty 10,959.0 11,121.0 12:31 14:55 drilling,still hitting stringers. CT wt 9 k lbs, WOB 1.7 k lbs, ROP variable, OBD CT 5212 psi, @ 1.87 bpm in and 1.87 bpm out, BHP 4069 psi. 2/24/2019 2/24/2019 0.50 PROD1 DRILL DRLG P PU Wt 35 k lbs to allow DD to adjust 11,121.0 11,217.0 14:55 15:25 for stops, RBIH CT 5044 psi @ 1.88 bpm in and 1.87 bpm out, diff 1193 psi, WH 295 psi. CT Wt 3.8 k Has, WOB 1 k Has, Bleed IA to 6 psi energized fluid, Bleed OA to 32 psi all fluid. Page 6116 Report Printed: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start7me End Tim Dur (hr) Phase Op Code Activiry Code Time P -T-% Operebon Stan Depth (WB) End Depth (WB) 2/24/2019 2/24/2019 0.50 PROD1 DRILL DRLG P PU Wt 35 k lbs to allow DO to adjust 11,121.0 11,217.0 15:25 15:55 for stops, RBIH CT 5044 psi (03 1.88 bpm in and 1.87 bpm out, diff 1193 psi, WH 295 psi. CT Wt 3.8 k lbs, WOB 1 k lbs, Bleed IA to 6 psi energized fluid, Bleed OA to 32 psi all fluid. 2/24/2019 2/24/2019 0.70 PROD1 DRILL DRLG P PU Wt 38 k lbs, PUH wiping to the TT 11,217.0 9,040.0 15:55 16:37 to dean up the 7" and tie in for depth control. Hole clean, lots of solids at the shaker. Jog 7", PUH pumping bottoms up. 2/24/2019 2/24/2019 0.20 PROD1 DRILL DRLG P Tie into the HRZ for a +3.5' correction. 9,040.0 9,085.0 16:37 16:49 2/24/2019 2/24/2019 0.20 PROW DRILL TRIP P RIH and park at 9299.88 CTMD - 9,085.0 9,299.0 16:49 17:01 6244.06 psi, Measure BHP Trap 3950 psi, pressure slowly falling, bleed to 3837 psi, Observe pressure climb slowly to 3906 psi, 12.02 EMWand slowly climbing. 2/24/2019 2/24/2019 1.78 PROD1 DRILL TRIP P PU Wt 33 k lbs, RBIH, window and 9,299.0 11,220.0 17:01 18:48 build clean. 2/24/2019 2124/2019 0.35 PR0D1 DRILL DRLG P BOBD, 1.87 bpm @ 5,117 psi, 11,220.0 11,410.0 18:48 19:09 Diff --1,286 psi, WHP=371, BHP=4,059, IA=16, OA=96 2/24/2019 2/24/2019 0.40 PROM DRILL DRLG P Lower pump rate to drop angle, 1.5 11,410.0 11,446.0 19:09 19:33 bpm at 4,260 psi, WHP=413, BHP=4,080, IA=17, OA=98 2124/2019 2/24/2019 0.20 PROM DRILL WPRT P BHA wiper up hole,PUW 39 k 11,446.0 11,446.0 19:33 19:45 2/24/2019 2/24/2019 1.30 PROD1 DRILL DRLG P BOBD, 1.84 bpm at 5,022 psi, 11,446.0 11,604.0 19:45 21:03 Diff -1,238 psi, WHP=432, BHP=4,086, IA=22, OA=96 2124/2019 2/24/2019 0.20 PROD1 DRILL WPRT P BHA wiper up hole, PUW 40 k 11,604.0 11,604.0 21:03 21:15 2/2412019 2/24/2019 1.00 PROD? DRILL DRLG P BOBD, 1.31 bpm at 3,559 psi, 11,604.0 11,676.0 21:15 22:15 Diff=609, BHP=4,107, IA=17, OA=100 2/24/2019 2/24/2019 1.25 PROW DRILL WPRT P TO Lt lateral 11,676', PUW 38 k, 11,676.0 9,274.0 22:15 23:30 Circulate 1 0x1 0 TO sweep, chase sweep to the window, perform 300' jog back in hole from 9,530'-9,830' 2/24/2019 2/25/2019 0.50 PROM DRILL WPRT P Jog the 7 inch, with 5x5 bbl sweep 9,274.0 9,274.0 23:30 00:00 9,246'-9,305- 2/25/2019 2/25/2019 2.00 PRODi DRILL WPRT P Continue swab wiper, performing 500' 9,274.0 78.3 00:00 02:00 1 jog back in hole from 1,000' 2/25/2019 2/2572019 1.65 PROD1 DRILL TRIP P Tag up, reset counters, RIH 78.3 9,055.0 02:00 03:39 1 2/25/2019 2/25/2019 0.25 PROD1 DRILL DLOG P Log formation for depth control 9,055.0 9,257.5 03:39 03:54 correction of plus 7.0', RIH to above window 2/25/2019 2/25/2019 0.30 PROD1 DRILL TRIP P Perfrom static pressure survey above 9,257.5 9,257.5 03:54 04:12 window bit depth @ 9,297.54', Pressure sensor depth 6,242.21', 11.99 ppg/3,888 psi AP 2/25/2019 2/2512019 1.00 PROD1 DRILL TRIP P Continue IH 9,257.5 11,676.0 04:12 05:12 2/25/2019 2/25/2019 1.40 PROD1 DRILL TRIP P Confirm TO 11,676', reciprocate pipe 11,576.0 11,592.0 05:12 06:36 1 while finishing liner running pill. 2/25/2019 2/25/2019 0.40 PROD1 DRILL DISP P Start Liner running pil down the coil, 11,592.0 11,671.0 06:36 07:00 12.29 pb, 50 bbls Page 7/16 Report Printed: 4/312019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log SM DePlh SWa Time End Time Dur (hr) Phase op Cade Activity Code Time P -T -X Operation (flKa) End Deptlr (Mi 2/25/2019 2/25/2019 2.60 PROM DRILL TRIP P POOH laying in liner running pill and 11,671.0 87.0 07:00 09:36 panting flags 9668.34' Paint yellow TD flag 7178.26'Paint white window flag TOP of liner running pit @ 8170' 2/25/2019 2/25/2019 1.30 PRODI DRILL PULD P Flow check, LD BHA #4 over a dead 87.0 0.0 0936 1054 well. Pull checks and rebuild. Check pipe, 0.133, 0.175, 0.175, 0.176" @ A,B,C,D respectively.ODS, Reel, etc. Bit graded out 1-2-bt-s-x-i-nr-td 2/25/2019 2/25/2019 3.30 COMPZ1 CASING PUTB P Prep floor for running Lower L1 0.0 2,034.7 10:54 14:12 completion, PU 65 joints L-80 2-3/8" 4.6 ppf slotted liner +2 pups ( 20.76') over anon ported bull nose under a shorty deployment sleeve, Liner length, 2033.5', LOA 2034.73' Clear floor of liner running equipment. 2/25/2019 2125/2019 0.50 COMPZ1 CASING RGRP P Complete injector inspection / maint 2,034.7 2,034.7 14:12 14:42 2/25/2019 2/25/2019 0.90 COMPZI CASING PULD P PU BHA#5, Baker GS under Coil 2,034.7 2,080.0 14:42 15:36 Trak, Stab shorty, Inspect pack offs, replace checks, stab injector, bump up 2/25/2019 2/25/2019 1.20 COMPZ1 CASING RUNL P RIH W liner 2,080.0 9,190.0 15:36 16:48 2/25/2019 2125/2019 0.20 COMPZI CASING DLOG P PU Wt 35 k lbs, Tie into window flag 9,190.0 9,184.2 16:48 17:00 for +1.16' 2/25/2019 2/25/2019 1.20 COMPZI CASING RUNL P Continue to RIH with L1 lower 9,184.2 11,676.0 17:00 18:12 completion. Drive by HRZ for +0.5' correction. Land completion, PU 46 k lbs, RBIH stack 5 k WOB, 1.5 bpm, CT 3000 psi, PU 30 k lbs, letf liner on bottom. 2/25/2019 2/25/2019 1.70 COMPZI CASING TRIP P PUH, park and reset counters to 11,676.0 96.0 18:12 19:54 account for dropping off liner. 2/25/2019 2/25/2019 0.40 COMPZ1 CASING PULD P Flow check well, LD BHA over a dead 96.0 0.0 19:54 20:18 well. 2/25/2019 2/25/2019 0.80 COMPZ1 CASING PULD P PU Anchored billet, MU BHA 0.0 47.6 20:18 21:06 2/25/2019 2/2512019 1.90 COMPZI CASING TRIP P RIH, with anchor billet, BHA #6 47.6 9,046.0 21:06 23:00 2125/2019 2/25/2019 0.20 COMPZ1 CASING DLOG P Tie into the HRZ for +8.5'correction 9,046.0 9,089.0 23:00 23:12 2/25/2019 2/25/2019 0.50 Col CASING RUNL P Continue to RIH to 9259', PU Wt 35 k 9,089.0 9,637.0 23:12 23:42 lbs, close EDC, Run throug hwindow, clean, tag TOL @ 9637' S/D 2 k WOB, PU to neutral weight, on line with the pump, shear @ 2300 psi, WOB 4.6 k 2/25/2019 2126/2019 0.30 COMPZI CASING TRIP P PU W133 lbs, POOH 9,637.0 9,297.0 23:42 00:00 2/26/2019 2/26/2019 1.40 COMPZ1 CASING TRIP P Continue POOH 9,297.0 72.2 00:00 01:24 2/26/2019 2/26/2019 0.70 COMPZI CASING PULD P PJSM, LD setting tools on a dead well 72.2 0.0 01:24 02:06 2/26/2019 2126/2019 0.75 PROM DRILL CTOP P PU Test Joint, perform function test 0.0 0.0 02:06 02:51 2/26/2019 2/26/2019 1.40 PROD2 DRILL PULD P PJSM PU L1-01 lateral drilling 0.0 72.2 02:51 04:15 assembly 2/26/2019 2/26/2019 1.55 PROD2 DRILL TRIP P RIH, with build assembly 72.2 9,040.0 04:15 0548 2/26/2019 2/26/2019 0.20 PROD2 DRILL DLOG P Log formation correction of plus 5.5' 9,040.0 9,087.0 05:48 06:00 Page 8/16 Report Printed: 41312019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Start Time EM Time our (hr) Phase Dip Code Activity Code Time P -T -X Operation (Wll) End Depth (fiKa) 2/26/2019 2/26/2019 1.20 PROD2 DRILL DISP P Continue IH, displacing well to drilling 9,087.0 9,300.0 06:00 07:12 fluid 2/26/2019 2/26/2019 0.30 PROD2 DRILL TRIP P RIH, dry tag TOB @ 9,625.5', PUH 9,300.0 9,625.5 07:12 07:30 obtain pump parameters 2/26/2019 2/26/2019 0.90 PROD2 DRILL KOST P Kickoff billet, 1.85 bpm at 4,386 psi, 9,625.5 9,626.5 07:30 08:24 Diff --530 psi, WHP=276, BHP=4,012, IA=24, OA=31, time mill 1 Whir 2126/2019 2/26/2019 0.50 PROD2 DRILL KOST P Time mill 2 Whir, 1.86 bpm at 4,386 9,626.5 9,627.5 08:24 08:54 psi, Diff -503, WHP=280, BHP=4005, IA=24, OA=28 2/26/2019 2/26/2019 0.20 PROD2 DRILL KOST P Time mill 3 ft/hr, 1.86 bpm at 4,386 9,627.5 9,627.8 08:54 09:06 psi, Diff --501, WHP=283, BHP=3994, IA=24, OA=28 2/26/2019 2/26/2019 0.15 PROD2 DRILL KOST T Stall Motor, PUH, stuck on bottom, 9,627.8 9,627.8 09:06 09:15 work pipe no movement, notify Town Team 2/26/2019 2/26/2019 3.00 PROD2 DRILL OTHR T Bring pump online obtain pump 9,627.8 9,627.8 09:15 12:15 parameters, rotate TF between HS and 90° ROHS, work pipe no movement. 0.5 bpm/ DP=5491/CTP=2,569 1.0 bpm/DP=1,053/CTP=3,429 1.5 bpm/DP=2,067/CTP=4,756 1.8 bpm/DP=2,155/CTP=6,155 2/26/2019 2/26/2019 0.50 PROD2 DRILL OTHR T Circulate 5x5 sweep around, work 9,627.8 9,627.8 12:15 12:45 pipe 53 k, minus 15 k DHWOB, rotate TF to the left without much resistance, can not rotate TF right when pumping any rate. with low rate 0.69 bpm, it will rotate to the right with high amps. MU high lube high vis pill. 2/26/2019 2/2612019 0.85 PROD2 DRILL OTHR T Circulate High lube pill down coil, work 9,627.8 9,627.8 12:45 13:36 pipe 90° ROHS, move up hole 7.0', continue circulating lube pill down coil. 2/26/2019 2/26/2019 0.50 PROD2 DRILL OTHR T Shut down and let soak, worked pipe 9,627.8 9,627.8 13:36 14:06 with a 90° LOHS, 53 k to -7.5 k, pulled free in tention. 2/26/2019 2/26/2019 0.30 PROD2 DRILL TRIP T POOH, with HS TF 9,627.8 9,340.0 14:06 14:24 2/26/2019 2/26/2019 0.20 PROD2 DRILL DLOG T Log RA marker correction of plus 3.0' 9,340.0 9,356.0 14:24 14:36 2/26/2019 2/26/2019 0.30 PROD2 DRILL TRIP T POOH, jog the 7 inch clean 9,356.0 9,246.0 14:36 14:54 2/26/2019 2/26/2019 1.80 PROD2 DRILL TRIP T Continue POOH 9,246.0 72.2 14:54 16:42 2/26/2019 2/26/2019 1.00 PROD2 DRILL PULD T PUD, kickoff/drilling BHA#7 72.2 0.0 16:42 17:42 2/26/2019 2/26/2019 1.30 PROD2 DRILL OTHR T Inspect BHA/ Motor/ Bit / FVS. Prep 0.0 0.0 17:42 19:00 anchor billet to run 2/26/2019 2/26/2019 2.00 PROD2 DRILL PULD T PJSM, PD BHA#8 Open hole anchor/ 0.0 81.3 19:00 21:00 Billet. M/U to CT and surface test - Good. Stab on. OTS will not test. Unstab and replace O -Rings. run surface test and stab on. Tag up and set counters 2/262019 2/26/2019 2.10 PROD2 DRILL TRIP T Trip in hole, EDC open 81.3 9,060.0 21:00 23:06 2/26/2019 2/262019 0.20 PROD2 DRILL DLOG T Log Gamma lie in for +4'correction 9,060.0 9,098.0 23:06 23:18 2/26/2019 226/2019 0.40 PROD2 DRILL TRIP T Continue in well. Close EDC @ 9261', 9,098.0 9,621.0 23:18 23:42 PUW=33K Page 9116 Report Printed: 41312019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Tme Dur(hr) Phase Op Code Aottvlry Code Time P -T -X Operation Start Depth (110) End Depth (aKB) 2/26/2019 2/26/2019 0.20 PROD2 DRILL TRIP T Tag Billet#1 @ 9621.66 with 1.3K 9,621.0 9,629.3 23:42 2354 DHWOB. Push down and observe movement. Get to 9629.3 with 3.1 K DHWOB. Pull slack out of CT 9626.9' oriented to 30° ROHS. Pumps on .5 BPM. Observe tool shift @ 3950 PSI. Push down 2K. Looks good Estimate TOB @ 9606.5- 2126/2019 2/27/2019 0.10 PROD2 DRILL TRIP T Trip out of hole after setting anchor 9,629.3 9,550.0 23:54 00:00 1 billet #2 2/27/2019 2/27/2019 1.80 PROD2 DRILL TRIP T Continue trip out after setting ON 9,550.0 86.0 00:00 01:48 anchored billet #2 2/27/2019 2/27/2019 1.30 PROD2 DRILL PULD T At surface, Tag up and space out. 86.0 0.0 01:48 03:06 PUD BHA#8 billet set. 2/27/2019 2/27/2019 1.00 PROD2 DRILL PULD T PD BHA# 9 with 2°AKO motor and 0.0 72.2 03:06 04:06 RR HCC Bi center with Oynamus cutters. Make up to coil and surface test 2/27/2019 2/27/2019 1.70 PROD2 DRILL TRIP T Trip in hole BHA#9 72.2 9,040.0 04:06 05:48 2/27/2019 2/27/2019 0.20 PROD2 DRILL DLOG T Log formation correction of plus 5.0' 9,040.0 9,074.0 05:48 06:00 2/27/2019 2/27/2019 0.35 PROD2 DRILL TRIP T Continue IH, dry tag TOB at 9,608' 9,074.0 9,608.0 06:00 0621 2/27/2019 2/27/2019 0.15 PROD2 DRILL TRIP T PUH PUW 34 k, obtain pump 9,608.0 9,608.0 06:21 06:30 pressures 2/27/2019 2/27/2019 1.00 PROD2 DRILL KOST T Mill 1fph, 1.85 bpm at 4,445 psi, 9,608.0 9,609.0 06:30 07:30 Diff=530, WHP=258, BHP=3,963, IA=17, OA=21 2/27/2019 2/27/2019 0.90 PROD2 DRILL KOST T Mill 2fph, 1.85 bpm at 4,490 psi, 9,609.0 9,611.0 07:30 08:24 Diff --530, WHP=258, BHP=3,963, IA=17, OA=21 **Note: stacking surface weight, pump 5 bbl lube (2.5%12.5%) pill, continue milling ahead gaining 2.0 k surface weight with pill. 2/27/2019 2/27/2019 0.15 PROD2 DRILL KOST T PUH, PUW 33 k, restart with lube pill 9,611.0 9,611.0 08:24 08:33 1 1 exiting bit 2/27/2019 2/27/2019 0.50 PROD2 DRILL KOST P Mill 1-2 f fph, 1.85 bpm at 4,490 psi, 9,611.0 9,612.0 08:33 09:03 Diff --530, WHP=258, BHP=3,963, IA=17, OA=21 2/27/2019 2/27/2019 1.00 PROD2 DRILL KOST P Time mill 10 ft/hr, 1.85 bpm at 4,490 9,612.0 9,665.0 09:03 10:03 psi, Diff --530, WHP=258, BHP=3,963, IA=17, OA=21 227/2019 2/27/2019 0.20 PROD2 DRILL KOST P PUH for dry drift, PUW 34 k 9,665.0 9,665.0 10:03 10:15 2/27/2019 2/27/2019 2.25 PROD2 DRILL DRLG P Drill ahead, 1.85 bpm at 4,595 psi, 9,665.0 9,808.0 10:15 12:30 Diff --676, WHP=418, BHP=4,006, IA=23, OA=27, TD Build Section 2 It above plan "** Note: Avg DGLS 32.13° 2/272019 2/27/2019 0.50 PROD2 DRILL WPRT P Wiper up hole into casing, jog 7inch 9,808.0 9,235.0 12:30 13:00 1 clean 9,235'-9,300'w/sweep 2/27/2019 2/27/2019 1.50 PROD2 DRILL TRIP P Open EDC, POOH pumping 1.85 bpm 9,235.0 78.2 13:00 14:30 at 3,742 psi, following MP 2/27/2019 2127/2019 1.00 PROD2 DRILL PULD P At surface, spaceout, PUD build 78.2 0.0 14:30 15:30 assembly 227/2019 227/2019 1.10 PROD2 DRILL PULD P PU/PD, L1-01 Lateral drilling 0.0 80.3 15:30 16:36 assembly 2/272019 2/27/2019 1.70 PROD2 DRILL TRIP P RIH, Surface test agitator7.8 BPM @ 80.3 9,055.0 16:36 18:18 5244 PSI FS, - 1500 PSI Diff Page 10116 ReportPrinted: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End End Time Dur thin phase Op Ootle Ac fty Cme TiP-T-% me Operatlan Stem Depth n De End Depth (RKB) 2/27/2019 2/27/2019 0.10 PROD2 DRILL DLOG P Log gamma lie in for +4.5'correction 9,055.0 9,084.0 18:18 18:24 2/27/2019 2/27/2019 0.50 PROD2 DRILL TRIP P Continue in hole. Clean pass through 9,084.0 9,808.0 18:24 18:54 window. Tag up @ 9808' 2/27/2019 2/27/2019 0.90 PROD2 DRILL DRLG P 9808', Drill, 1.8 BPM @ 5196 PSI FS, 9,808.0 9,928.0 18:54 19:48 BHP=3990 2/27/2019 2/27/2019 0.10 PROD2 DRILL WPRT P BHA wiper, PUW=32K 9,928.0 9,928.0 19:48 19:54 2/27/2019 2/2712019 3.40 PROD2 DRILL DRLG P 9928', Drill, 1.8 BPM @ 5049 PSI FS, 9,928.0 10,208.0 19:54 23:18 BHP -3995 2/27/2019 2/27/2019 0.50 PROM DRILL WPRT P Wiper trip to 9810 with 5 X 5sweeps, 10,208.0 10,208.0 23:18 23:48 PUW=36K 2/27/2019 2/28/2019 0.20 PROD2 DRILL DRLG P 10,208', Drill 1.8 BPM @ 5109 PSI 10,208.0 10,233.0 23:48 00:00 FS, BHP=3992 2/28/2019 2/28/2019 3.70 PROD2 DRILL DRLG P 10,233 Drill, 1.8 BPM @ 5110 PSI FS, 10,233.0 10,529.0 00:00 03:42 BHP=4031 2/28/2019 2128/2019 0.10 PROD2 DRILL WPRT P Pull BHA Wiper, PUW=35K 10,529.0 10,529.0 03:42 03:48 2/28/2019 2/28/2019 0.70 PROD2 DRILL DRLG P 10,529', Drill, 1.8 BPM @ 5386 PSI 10,529.0 10,552.0 03:48 0430 FS, BHP=3993, RIW=3K, DHWOB=3K 2/28/2019 2/28/2019 0.10 PROD2 DRILL WPRT P BHA Wiper, PUW=38K, RIW=8.8K 10,552.0 10,552.0 04:30 0436 2/28/2019 2/28/2019 1.00 PROD2 DRILL DRLG P 10552', Drill 1.79 BPM @ 5393 PSI 10,552.0 10,577.8 04:36 0536 FS, BHP=4020 2/28/2019 2/28/2019 1.00 PROD2 DRILL WPRT P Wiper up hole into the casing 10,577.8 9,246.0 05:36 06:36 w/sweeps 2/28/2019 2/28/2019 0.50 PROD2 DRILL WPRT P Pull through window, jog 7inch, 9,246.0 9,055.0 06:36 07:06 excessive cutting on sharker, continue jogging, PUH for tie in. 2128/2019 2/28/2019 0.20 PROD2 DRILL DLOG P Log HRZ correction of plus 2.5' 9,055.0 9,096.4 07:06 07:18 2/28/2019 2/28/2019 0.60 PROD2 DRILL TRIP T RIH, set down bottom of the window 9,096.4 9,320.0 07:18 07:54 9,320'x 3 2/28/2019 2/28/2019 1.30 PROD2 DRILL WPRT T Discuss with town team, decision was 9,320.0 9,246.0 07:54 09:12 made to POOH for cleanout BHA, continue jogging 7" clean w/sweeps 2/28/2019 2/28/2019 1.80 PROD2 DRILL TRIP T POOH, performing 500' jogs at 9,246.0 80.3 09:12 11:00 7,000',5,000', 3,500', 2/28/2019 2/28/2019 1.50 PROD2 DRILL PULD T At surface, space out, PUD and LD 80.3 0.0 11:00 12:30 drilling assembly BHA#10 2128/2019 2/28/2019 1.60 PROD2 DRILL PULD T PU/PD, cleanout assembly 0.0 62.4 12:30 14:06 2/28/2019 2/28/2019 1.70 PROD2 DRILL TRIP T RIH 62.4 9,040.0 14:06 15:48 2/28/2019 22812019 0.20 PROD2 DRILL DLOG T Log formation (HRZ) correction of plus 9,040.0 9,067.0 15:48 16:00 2.0', close EDC 228/2019 21282019 1.00 PROD2 DRILL TRIP T Continue IH, dry tag 9,320.5', PUH 9,067.0 9,320.0 16:00 17:00 bring pump online 1.81 bpm at 4,382 psi, Diff --466, WHP=255, BHP=3,940, IA=22, OA=45 2/28/2019 2/28/2019 0.70 PROM DRILL WPRT T Wash down towards 9,900', Stack @ 9,320.0 9,900.0 17:00 1742 9326, 9410, 9415, & 9436 2/28/2019 2/28/2019 3.30 PROD2 DRILL TRIP T 9900', Pump 5 X 5 sweeps trip out 9,900.0 68.0 17:42 21:00 pumping 1.8 BPM, Jog 7" with additional sweeps. Jog @ 5000', 1000', and surface. 2/28/2019 2/28/2019 1.00 PROM DRILL PULD T Tag up space out. PJSM PUD clean 68.0 0.0 21:00 22:00 out BHA#11. D-331 out @ 2.79 No Go Page 11/16 Report Printed: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 ... Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log I Stan Depth Stan Time End Tim Dur (hr) Phase Op Code Activity Code Time P -T -x Operabon (MB) End Depth (W13) 2128/2019 2/28/2019 1.60 PROD2 STK PULD T PJSM, M/U and PD BHA#12 OH 0.0 72.7 22:00 23:36 anchor billet. make up to coil and surface test 2128/2019 3/1/2019 0.40 PROD2 STK TRIP T Trip in hole BHA#12 72.7 2,145.0 23:36 00:00 3/112019 3/12019 1.40 PROD2 STK TRIP T Continue in BHA#12 OH Anchor billet, 2,145.0 9,054.0 00:00 01:24 EDC open pumping min rate 3/1/2019 3/112019 0.20 PROD2 STK DLOG T Log gamma tie in for + 3.5' 9,054.0 9,094.0 01:24 01:36 3/12019 3/1/2019 0.60 PROD2 STK TRIP T Continue in with OH anchor billet. 9,094.0 9,716.8 01:36 02:12 Stop at 9277 Gose EDC. PUW=32.5K. Continue in. Clean pass through window set down @ 9343'. P/U work pipe down. Cleared up past 9355. Continue into set depth @ 9716.75 3/112019 3/1/2019 0.10 PROD2 STK WPST T 9716.8. At set depth. Pull slack out of 9,716.8 9,716.8 02:12 02:18 CT. Orient to 180" ROHS. Bring pumps on @ .5 BPM. See tool shift 3800 PSI. Set down 2.5K. Looks good 3/1/2019 3/12019 1.90 PROM STK TRIP T Trip out with setting tools. Open EDC 9,716.8 68.0 02:18 04:12 @ 9293 3/1/2019 3/1/2019 1.50 PROD2 STK PULD T Tag up and space out. PJSM PUD 68.0 0.0 04:12 05:42 BHA#12 billet setting tools 3112019 3/1/2019 1.50 PROD2 STK PULD P PD, kickoff/build assembly 0.0 72.2 05:42 07:12 3/1/2019 3/112019 1.70 PROD2 STK TRIP P RIH, with L1-01 build assembly BHA 72.2 9,040.0 07:12 08:54 #13 3/1/2019 3/12019 0.20 PROD2 STK DLOG P Log formation correction of plus , 9,040.0 9,068.0 08:54 09:06 Close EDC 3/1/2019 3/1/2019 0.30 PROD2 STK TRIP P Continue IH 9,068.0 9,704.0 09:06 09:24 j 3/1/2019 3/1/2019 0.20 PROD2 STK TRIP P Dry tag TOB, PUH obtain pump 9,704.0 9,703.0 09:24 09:36 pressures 3/1/2019 3/1/2019 1.00 PROD2 STK KOST P Time mill 1 ft, 1.86 bpm at 4,586 psi, 9,703.0 9,704.0 09:36 1036 Diff=520, WHP=237, BHP=3,953, IA=22, OA=24 3/1/2019 3/1/2019 0.75 PROD2 STK KOST P Time mill 2 ft, 1.86 bpm at 4,586 psi, 9,704.0 9,705.0 10:36 11:21 Diff --520, WHP=237, BHP=3,953, IA=35, OA=24 3/1/2019 3/1/2019 0.75 PROD2 STK KOST P Time mill 3 ft, 1.86 bpm at 4,586 psi, 9,705.0 9,706.0 11:21 12:06 Diif=520, WHP=237, BHP=3,953, IA=42, OA=58 3/1/2019 3/112019 1.50 PROD2 DRILL DRLG P Drill ahead, 1.85 bpm at 4.586 psi, 9,706.0 9,898.0 12:06 13:36 Diff --532, WHP=242, BHP=4,001, IA=51, OA=102 3/1/2019 3/1/2019 0.20 PROD2 DRILL WPRT P PUH, dry drift kickoff point clean 9,898.0 9,675.0 13:36 13:48 3/112019 3/1/2019 0.20 PROD2 DRILL WPRT P Wiper back in hole, RIW 13 k 9,675.0 9,898.0 13:48 14:00 3/1/2019 3/1/2019 1.25 PROD2 DRILL DRLG P BOBD, 1.85 bpm at 4,586 psi, 9,898.0 9,965.0 14:00 15:15 Diff=532, WHP=242, BHP=4,001, IA=51, OA=102 3/1/2019 3/12019 0.25 PROM DRILL WPRT P TD, build section, pull wiper to the 9,965.0 9,246.0 15:15 15:30 casing w/54 sweep 3/1/2019 3/12019 0.10 PROD2 DRILL WPRT P Pull through window, jog 7 inch x 2 9,246.0 9,300.0 15:30 15:36 with sweeps 3/1/2019 3/1/2019 1.50 PROM DRILL TRIP P POOH, with closed EDC pumping 9,300.0 72.2 15:36 17:06 1.87 bpm at 4,613 psi, Diff --547, following MP, performing jogs at 3,500' and 1,000' 3/1/2019 3/12019 1.70 PROD2 DRILL PULD P PUD, build assembly 72.2 0.0 17:06 18:48 Page 12116 ReportPrinted: 413/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Staft pth Start Time End Time Dur (hr) Phase Op code Activity Code Time P -T -x Operation (WEI) End Depth (iIKB) 3/1/2019 3/1/2019 0.40 PROD2 DRILL SVRG P Make up drillers side PDL and 0.0 0.0 18:48 19:12 pressure test - Good. Rack back DS PDL 3/1/2019 3/1/2019 1.10 PROD2 DRILL PULD P M/U and Pd BHA#14 with .5° fixed 0.0 80.2 19:12 20:18 bend iron side motor and rebuilt HYC Bi center 3211 M -A2 bit. make up to coil and surface test. Tag up and set counters 3/1/2019 3/1/2019 1.80 PROD2 DRILL TRIP P Trip in hole BHA#14. Surface lest 80.2 9,050.0 20:18 22:06 agitator @ 513' 3/1/2019 3/1/2019 0.20 PROD2 DRILL DLOG P Log gamma lie in for+3.5'. PUW=33k 9,050.0 9,252.0 22:06 22:18 3/12019 3/1/2019 0.30 PROD2 DRILL TRIP P Continue in well. Clean trip through 9,252.0 9,968.0 22:18 22:36 window and past 8347' 3/1/2019 32/2019 1.40 PROD2 DRILL DRLG P 9968', Drill. 1.8 BPM @ 5282 PSI FS, 9,968.0 10,017.0 22:36 00:00 BHP=4043 3/212019 3/2/2019 0.50 PROD2 DRILL DRLG P 10017', Drill ahead, 1.8 BPM @ 5297 10,017.0 10,037.0 00:00 00:30 PSI FS, BHP=4010 312/2019 3/2/2019 0.10 PROD2 DRILL WPRT P PIU to get pressures for reduced 10,037.0 10,037.0 00:30 00:36 pump rale, Very high downhole vibrations 3/212019 3/2/2019 0.90 PROD2 DRILL DRLG P 10037 Drill 1.65 BPM @ 4720 PSI FS, 10,037.0 10,054.0 00:36 01:30 BHP=4018. Low ROP with low differential 2K DHWOB 3/22019 3/212019 0.70 PROD2 DRILL DRLG P Unable to get differential pressure. Try 10,054.0 10,056.0 01:30 02:12 to stall motor. Vibration dropped to zero Pump sweeps 3/2/2019 3/22019 2.60 PROD2 DRILL TRIP T Trip out chaseing sweeps, 1.81 BPM 10,056.0 85.0 02:12 04:48 @ 5332 PSI FS. PUW=32K. Pre load Drillers side PDL 3/2/2019 3212019 0.50 PROD2 DRILL PULD T A surface, Tag up and space out. 85.0 85.0 04:48 05:18 PJSM PUD BHA#14 3/2/2019 31212019 0.50 PROD2 DRILL RGRP T On step #46 Roll chains "In the hole 85.0 85.0 05:18 05:48 direction", were unable to move chains, shut down operations, PJSM for planforward. 3/2/2019 3/212019 2.50 PROD2 DRILL RGRP T Inspect INJH, found half on bearing, 85.0 85.0 05:48 08:18 continue searching for second half, looks like there could be something in idler bearing. work chains to free up. remove few gripper blocks, plan toward is to pull chain link 3/2/2019 3212019 2.70 PROD2 DRILL RGRP T PJSM, pull link out of chain, inspect 85.0 85.0 08:18 11:00 for parts, couldn't locate any, put chain back together. 3/2/2019 3/2/2019 0.50 PROD2 DRILL RGRP T With gripper blocks removerd partially, 85.0 85.0 11:00 11:30 strip up INJH, re -install gripper blocks.secure coiled tubing 3/2/2019 312/2019 1.50 PROD2 DRILL PULD T PUD, Drilling assembly BHA#14, 85.0 0.0 11:30 13:00 inspect BHI, motor has failed. LD Tools 312/2019 3/2/2019 2.00 PROD2 DRILL PULD T Continue Inspecting drilling BHA, 0.0 0.0 13:00 15:00 break tools down in mouse hole, BHI CoilTrak tools, MU and suck up BHA #15 into lubricator. 32/2019 3/2/2019 3.00 PROD2 DRILL RGRP T Continue inspecting INJH, take INJH 0.0 0.0 15:00 18:00 chain apart, found broken chain bearing in sproket, MU injector chain 312/2019 3/2/2019 1.50 PROD2 DRILL RGRP T Injector ready to go. Install nozzle run 0.0 0.0 18:00 19:30 pipe down for inspection. Trim 12' for coil deformation and rehead. NAD NPT 10 His. Page 13/16 Report Printed: 413/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log star Time End Mme our (no Prase op Code AcWfty Cade Tme P -T -X operation star DePM (Pots) End Depth (WB) 3/2/2019 3/2/2019 2.00 PRO02 DRILL PULD T Prep floor PJSM M/U BHA# 15 0.0 78.3 19:30 21:30 with .8° AKO BHI motor, Agitator, and RB HCC TX25207 bit with dynamus cutters. PD. M/U to coil and surface test 3/2/2019 3/2/2019 1.30 PROD2 DRILL TRIP T Trip in hole. Stop at 500' PUH 300 and 78.3 4,236.0 21:30 22:48 inspect pipe with hands on injector. Good. trip in and test agitator @ 800' 3/2/2019 3/2/2019 0.20 PROD2 DRILL TRIP T Slop. PUH inspecting pipe, gripper 4,236.0 4,070.0 22:48 23:00 1 blocks, and chains. All good 3/2/2019 3/2/2019 0.70 PROD2 DRILL TRIP T Continue in well. 4,070.0 9,045.0 23:00 23:42 3/212019 3/2/2019 0.10 PROD2 DRILL DLOG T Log gamma tie in for +4' 9,045.0 9,084.0 23:42 23:48 3/2/2019 3/3/2019 0.20 PROD2 DRILL TRIP T Continue in well. Pull weight check @ 9,084.0 9,252.0 23:48 00:00 9263 34K 3/3/2019 3/3/2019 0.40 PROD2 DRILL TRIP T Continue in well, Clean pass through 9,252.0 10,053.0 00:00 00:24 window and past billets 313/2019 3/3/2019 1.30 PROM DRILL DRLG P 10053', Drill, 1.8 BPM @ 5218 PSI 10,053.0 10,215.0 00:24 01:42 FS, BHP=4029, RIW=12.5K, DHWOB=2.1K, ROP=120FPH 3/3/2019 3/3/2019 1.10 PROD2 DRILL WPRT P Wiper trip (Geo wiper), PUW=42K 10,215.0 10,215.0 01:42 02:48 3/3/2019 3/312019 1.50 PROD2 DRILL DRLG P 10245', Drill, 1.8 BPM @ 5204 PSI 10,215.0 10,311.0 02:48 04:18 FS, Trouble getting going. Hole taking fluid on bottom. Pick ups sticky 3/3/2019 3/3/2019 0.10 PROD2 DRILL WPRT P Pull BHA wiper up past 10215. 10,311.0 10,311.0 04:18 04:24 PUW=34K. Slight bobble RIH past 10215 3/3/2019 3/3/2019 0.75 PROD2 DRILL DRLG P 10311', Drill, 1.8 BPM @ 5227 PSI FS, 10,311.0 10,374.0 04:24 05:09 BHP=4093, RIW=12.3 3/3/2019 31312019 0.25 PROD2 DRILL WPRT P Short Geo wiper up hole to 10,312' 10,374.0 10,312.0 05:09 05:24 3/312019 3/3/2019 0.25 PROD2 DRILL WPRT P Wiper back in hole, RIW 12 k 10,312.0 10,374.0 05:24 05:39 3/3/2019 3/312019 1.00 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,200 psi, 10,374.0 10,460.0 05:39 06:39 Diff -1,160 psi, WHP=243, BHP=4,059, IA=94, OA=122 3/312019 3/3/2019 0.15 PROD2 DRILL WPRT P Wiper up hole, PUW 35 k 10,460.0 9,994.0 06:39 06:48 313/2019 3/3/2019 0.15 PROD2 DRILL WPRT P Wiper back in hole, RIW 12 k 9,994.0 10,460.0 06:48 06:57 313/2019 3/3/2019 2.50 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,543 psi, 10,460.0 10,638.0 06:57 09:27 Diff -1,400 psi, WHP=244, BHP=4,062, IA -95, OA=121 3/3/2019 313/2019 0.20 PROD2 DRILL WPRT P Short BHA wiper up hole, PUW 39 k 10,638.0 10,638.0 09:27 09:39 3/3/2019 3/3/2019 1.00 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,543 psi, 10,638.0 10,730.0 09:39 10:39 Diff --1,400 psi, WHP=244, BHP=4,062, IA -95, OA=121 3/3/2019 3/3/2019 0.20 PROD2 DRILL WPRT P Short BHA wiper up hole, PUW 39 k 10,730.0 10,730.0 10:39 10:51 3/3/2019 31312019 1.50 PROD2 DRILL DRLG P BOBD, 1.8 bpm at 5,543 psi, 10,730.0 10,860.0 10:51 12:21 Diff --1,400 psi, WHP=244, BHP=4,062, IA -95, OA=121 3/3/2019 3/3/2019 0.60 PROD2 DRILL WPRT P Wiper up hole to the window w/sweep, 10,860.0 9,300.0 12:21 12:57 1 1 1 PUJ 37 k 3/3/2019 3/3/2019 0.30 PROD2 DRILL WPRT P Circulate bottoms up, while jogging 9,300.0 9,246.0 12:57 13:15 1 1 the 7inch. x 4 3/3/2019 3/3/2019 0.15 PROD2 DRILL WPRT P RIH for tie in 9,246.0 9,340.0 13:15 13:24 1 1 1 Page 14116 Report Printed: 4/3/2019 Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartTime End Time Dur (hr) PhaseStart code AcMy Code Time P -T -X Operation Depthop (aKB) EM Depti (WB) 3/3/2019 3/312019 0.20 PROD2 DRILL WPRT P RIH, log RA marker correction of plus 9,340.0 9,367.0 13:24 13:36 3.0' 3/3/2019 3/3/2019 0.60 PROD2 DRILL WPRT P Contime wiper back in hole, RIW 14 k 9,367.0 10,860.0 13:36 14:12 3/3/2019 3/3/2019 1.00 PROD2 DRILL DRLG P BOBO, 1.8 bpm at 5,543 psi, 10,860.0 10,973.0 14:12 15:12 DiR=1,400 psi, WHP=244, BHP=4,062, IA -95, OA=121 3/3/2019 3/3/2019 1.00 PROD2 TRILL DRLG P OBD, 1.8 bpm at 5,543 psi, 10,973.0 11,070.0 15:12 16:12 Diff=1,400 psi, WHP=244, BHP=4,062, IA -95, OA=121 3/3/2019 3/3/2019 1.20 PROD2 DRILL DRLG P OBD, 1.8 bpm at 5,543 psi, 11,070.0 11,126.0 16:12 17:24 Dii(=1,400 psi, WHP=244, BHP=4,062, IA -95, OA=121. New mud at bit 11,103' 3/3/2019 3/3/2019 0.40 PROD2 DRILL WPRT P BHA Wiper, PUW=39K, New mud 11,126.0 11,126.0 17:24 17:48 around obtain new baseline pressures, Have to work back to bottom 3/3/2019 3/3/2019 2.90 PROD2 DRILL DRLG P 11126', Drill, 1.84 BPM @ 5137 PSI 11,126.0 11,258.0 17:48 20:42 1 FS, BHP=4058 313/2019 3/3/2019 0.80 PROM DRILL WPRT P Wiper trip, PUW=37K, -600' 11,258.0 11,258.0 20:42 21:30 3/3/2019 3/4/2019 2.50 PROD2 DRILL DRLG P 11,258', Drill, 1.82 BPM @ 5147 PSI 11,258.0 11,319.0 21:30 00:00 FS, BHP=4103, RIW=5.4K, DHWOB=2.3K 3/412019 3/4/2019 2.90 PROD2 DRILL DRLG P 11319', Drill, 1.82 BPM @ 5147 PSI 11,319.0 11,395.0 00:00 02:54 1 FS, BHP=4105 3/4/2019 3/4/2019 3.20 PROD2 DRILL WPRT P 11395', Csll TD, Pump sweeps and 11,395.0 78.0 02:54 06:06 chase to swab, PUW=38K 3/4/2019 3/4/2019 2.00 PROD2 DRILL TRIP P Tag up, reset counters, RBIH 78.0 9,040.0 06:06 08:06 3/4/2019 3/4/2019 0.20 PR0D2 TRILL DLOG P Log formation correction of plus 5.5' 9,040.0 9,087.0 08:06 08:18 3/4/2019 3/412019 1.20 PROD2 DRILL TRIP P Continue RIH 9,087.0 11,268.0 08:18 09:30 3/412019 3/4/2019 0.40 PROD2 DRILL TRIP P Work pipe past 11,268' with multiple 11,268.0 11,395.0 09:30 09:54 pump rates, rotate TF, past through area successfully (x8), continue IH 3/4/2019 3/412019 0.40 PROD2 DRILL CIRC P Confirm TD, circulate beaded LRP 11,395.0 11,395.0 09:54 10:18 down coil, recip coil, Note: Static Pressure Survey @ 9,303' CTMD, Sesor depth 6,246.41' TVD, 12.05 EQMW, WHP=961 3/412019 3/4/2019 2.75 PROD2 DRILL TRIP P POOH laying in beaded LRP up into 11,395.0 78.0 10:18 13:03 1 the casing and tubing up to 7,190' 3/4/2019 314/2019 0.50 PROD2 DRILL PULD P Al surface, check well for flow, static 78.0 78.0 13:03 13:33 1 loss rate 0 3/412019 3/412019 0.60 PROD2 DRILL PULD P Flush/LD drilling assembly on a dead 78.0 0.0 13:33 14:09 well. 3/4/2019 3/4/2019 0.40 150MPZ2 CASING PULD P Prep RF for liner OPS, PJSM 0.0 0.0 14:09 14:33 3/4/2019 3/4/2019 3.00 COMPZ2 CASING PUTB P Pickup Ll -01 liner assembly 0.0 2,175.0 14:33 17:33 3/4/2019 3/4/2019 1.20 COMPZ2 CASING PULD P FU/MU CoilTrak tools, surface test 2,175.0 2,219.2 17:33 18:45 (good) 3/4/2019 3/4/2019 1.30 COMPZ2 CASING RUNL P RIH w/1-1-01 2-3/8" slotted/solid liner 2,219.2 9,218.2 18:45 20:03 completion, shorty deployment sleeve, and non -ported bullnose. 3/4/2019 3/4/2019 0.15 COMPZ2 CASING RUNL P Correct to the EOP flag 0.5', PUW 36 9,218.2 9,218.7 20:03 20:12 k Page 15116 Report Printed: 4/312019 a Operations Summary (with Timelog Depths) 3M-26 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (Vtl) End Depth TU(B) 3/4/2019 3/4/2019 1.20 C0MPZ2 CASING RUNL P Continue IH 9,218.7 11,395.0 20:12 21:24 3/4/2019 3/4/2019 0.20 C0MPZ2 CASING RUNL P Liner on bottom, bring pump on-line 11,395.0 9,197.0 21:24 21:36 1.5 bpm at 4,496 psi, 1.2 bpm returns, Diff=860 psi, PUW=30 k, 0 k DHWOB, Remove liner length from counters, TOL=9220' 3/4/2019 3/4/2019 0.50 C0MPZ2 CASING RUNL P *** Obtain SBHP, 9,197' CTMD, 9,197.0 9,197.0 21:36 22:06 Sensor Depth=6192.04', AP=3,952, Mud Weight=12.27 ppg '*** 3/4/2019 3/4/2019 1.40 DEMOB WHDBOP DISP P Displace well to SW 9,197.0 9,197.0 22:06 23:30 3/4/2019 3/5/2019 0.50 DEMOB WHDBOP TRIP P Trip out of well, PUW=28K 9,197.0 6,445.0 23:30 00:00 3/5/2019 3/5/2019 1.50 DEMOB WHDBOP TRIP P Continue tripping out, Pump 30 BBIs 6,445.0 54.0 00:00 01:30 diesel, Freeze protect tubing from 2500' 3/5/2019 3/5/2019 1.80 DEMOB WHDBOP PULD P At surface, Tag up and space out. 54.0 0.0 01:30 03:18 PUD BHA#16 Liner running tools 3/5/2019 3/5/2019 0.80 DEMOB WHDBOP CLEN P M/U nozzle stab on injector and flush 0.0 CW0 0318 04:06 BOPE and rig surface lines 3/5/2019 3/5/2019 1.90 DEMOB WHDBOP CTOP P Break off injector, Vac stack in prep for 0.0 0.0 04:06 0600 bore scope. Run bore scope inspection of stack. Pour methanol in tree 3/5/2019 3/5/2019 2.50 DEMOB MOVE MOB P Work rig down checklist. Blow down 0.0 0.0 06:00 0830 TT line and unhook from rig. Off load last of fluid from pits. 3/5/2019 3/5/2019 1.50 DEMOB WHDBOP MOB P Tighten tree bolts - most bolts loose 0.0 0.0 08:30 10:00 3/5/2019 3/5/2019 3.00 DEMOB WHDBOP MOB P Nipple down BOPE stack. Lift and 0.0 0.0 10:00 13:00 secure. Rig down putz. Secure injector and reel. Rig Release 13:00 Page 16116 Report Printed: 4/3/2019 Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: ,. 67 AOGCC ATTN: Natural Resources Technician II r- Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 ^wJb� Anchorage, AK 99501 1g31S3 TRANSMITTAL DATE- S TRANSMITTAL# 1R-26 3M-26 1R-018 1R-04 1F-07 1B -15A 1R-17 50.029-22193-00 50-029-22431-00 50-029-21404.02 50-029-21407-00 50.029-20830-00 50.029-22465-01 50-029-22212-00 r•r DWUJ-00000077 DWUJ-78 DWUJ-00079 DWUJ-00080 E9KH-00003 EA77-00001 EA77-00006 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL WLFINAL EMIT Caliper EMIT EMIT PPROF PPROF IPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FIELD FINAL FIELD r 2 -Feb -19 4 -Feb -19 5 -Feb -19 6•Feb-19 9•Feb-19 12 -Feb -19 13 -Feb -19 1 1 1 1 1 1 1 7 nt Nam/ "- Signature Please return via courier or sign/scan and email a Date Schlumberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The speci'ic content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. THE STATE °fALASKA GOVERNOR MIKE DUNLP.AVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-26 Permit to Drill Number: 193-193 Sundry Number: 319-039 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Www. o o g c c. a l o s ka. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner 4® DATED this ¢d of February, 2019. SCANNED FEB 0 4 2019 STATE OF ALASKA JAN � C 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGICC 20 AAC 25 280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CO261 B Whipstock ❑� . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska, Inc. P Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 193-193 3. Address: 6. API Number: , PO Box 100360, Anchorage, AK 99510 50-029-22431-0000 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/At/3�A KRU 3M-26 Will planned perforations require a spacing exception? Yes ❑ No E 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25522 ADL 2,55'A3 Ku aruk River Field / Ku aruk River Oil Pool 11,3 1.4PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Eff dive Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9625' 6534' 9522' 6453' 3650 N/A 9450' Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 121' 121' Surface 4841' 9-5/8" 4882' 3624' Production 9576' 7" 9615' 6526' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9324'- 9358' 6299'- 6325' 3-1/2" J-55 9237' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FB -1 Perm Packer 9205'/ 6209' 12. Attachments: Proposal Summary � Wellbore schematic El 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: 13 -Feb -19 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Keith Herring Authorized Title: Staff CTD Engineer Contact Email: Keith. E. Herrin COP. Corn Contact Phone: 907-263-4321 //311;0? Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 'O E/ Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: (3 0 p ttS t7L,�-C/ /4k7nVt4�jpr��«tb 25-067 p5,, y Post Initial Injection MIT Req'd? Yes ❑ No M' Spacing Exception Required? Yes ❑ No Eg/ Subsequent Form Required: g/%7 Lkf�k APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 2-140 cn VrL- �n//9 RSI RBDMSMmFEB 9 5 2019 /F \ Submit Form and Form 10-403 Revised 4/2017 Approved applica n RIG r 2 f the date of approval. ttachmenis in Duplicate v 5=i.L`_ 8. �3�/4 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 30, 2018 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 sundry application to set a whipstock and applications for permits to drill two laterals out of the KRU 3M-26 (PTD# 193-193) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in early February 2019. The objective will be to drill two laterals, KRU 3M-261_1 and 3M-261_1-01, targeting the Kuparuk A -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry application are the following documents: - 10-403 Sundry Application for KRU 3M-26 - Operations Summary in support of the 10-403 sundry application - Current Wellbore Schematic - Proposed CTD Schematic Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 3M-261_1 and 3M-261_1-01 - Detailed Summary of Operations - Directional Plans for 3M -26L1 and 3M -26L1-01 - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska KRU 3M-26 (PTD #193-193) CTD Summary for Sundry Summary of Operations: KRU well 3M-26 is a Kuparuk A -Sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the A -sands to the north and west of 3M-26. The laterals will increase A -sand resource recovery and throughput. CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 9,314' MD. The 3M -26L1 lateral will exit through the 7" at 9,314' MD and TD at 11,700' MD, targeting the A sand to the west. It will be completed with 2-3/8" slotted liner from TD up to 9,600' MD with an aluminum billet for kicking off the 3M -26L1-01 lateral. The 3M -26L1-01 lateral will drill to a TD of 12,500' MD targeting the A sand to the north. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 9,220' MD with a deployment sleeve. CTD Drill and Complete 31VI-26 Laterals: February 2019 Pre -CTD Work 1. RU Slick -line: Change out GLV's and conduct dummy whipstock drift. 2. RU Service Coil: Mill out D -nipple and conduct fill cleanout. 3. RU E -line: Obtain caliper of 7" production casing and 3-1/2" tubing. 4. Prep site for Nabors CDR3-AC. Rip Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 3M -26L1 Lateral (Al sand - West) a. Set top of high expansion wedge at 9,314' MD b. Mill 2.80" window at 9,314' MD. c. Drill 3" bi-center lateral to TD of 11,700' MD. d. Run 2%" slotted liner with an aluminum billet from TD up to 9,600' MD. 3. 3M-261_1-01 Lateral (Al sand - North) a. Kick off of the aluminum billet at 9,600' MD. b. Drill 3" bi-center lateral to TD of 12,500' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 9,220' MD. 4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Ria Work 1. Return to production Page 1 of 1 1/30/2019 KUP PROD 3M-26 Gonda Phillips AM Well Attributes Max AngleB MD TD Z hud,e ZeLel Ficltl Name WeIILo�e 6lalus ncl l'I MD(XK61 Ac191m(dKB) Alaska, Inc. 5 0 02 0 2243100 KUPARUK RIVERUNR PROO 56]5 ),33JS6 9,625.0 Comment N3.41pPml Oa1e AnnWtllon EnE Cate NB4N eq Rlg Ralmse Dela noon 6GGV: NIPPLE 41.00 1/17/1994 3M. 1I.165:46'.OSPM Last Tag VeNoelsche-1e.1- gnd..b bend lnKS, TEdl Mptl ey Lav Tag: FIRM 9,383.0 4/912018 2embaej ..._. _._.. ....__._ Last Rev Reason AnnoWron lasl Moe ay 11hredowde Rev Reason: Tag wl 25' Ralhole 4110/2018 2embae) HMGER', 36e Ceasing Strings Cssing Oasmipllon OClin) I911n) TOPIM1KBI Sn Cepth lXKB) sel Cepin lrv0l... wvl<n p... Gaae Tpp Th. CONDUCTOR i6 15.062 d3.0 121.0 121.0 62.50 H-40 WELDED Casing Dex woon 00110,1 ID 110,1 Top @N6) Se1 w,,n1KK9) 6M Depth ITVCI... WVLen11... Oraee Top— SURFACE 9516 8.921 41.1 4,882.2 16236 36.00155 BTO OSIne Description OD linl ID lint ipp IXNB) SN,,n IXNBI Sel pepth lTVOL.. WVLen B...Gnee TopTn— PRODUCTION ) 696 38 B6td] 6.525.6 2600 L-80 BTC -MOD Tubing Strings Tubing""o".. 51,in9 Ma... IC11n Tp("KOSet DepXl l0,.. set11h II ... WtNhX1l Gratln iop LennMlon TUBING 31/2 2.992 36.8 9.2372 6,233.3 9.30 J-65 EUE01eMOD Completion Details TOP IND) IDPmd Nominal Top (no.) InK9l I.nem ces Com Ohnl 36.8 38.0 0.26 1 HANGER FMC GEN NHANGER 3500 2.021.2 1,9030 3725 NIPPLE CAMCO W I IANDING NIPPLE W/ SELECTIVE PROFILE 2.812 CONDUCTOR'. 49.0121 O 9=26 6,2070 4037 LOCATOR BAKER GSK22 LOCATOR SEAL ASSEMBLY 3.000 8205.3 6,209.1 4099 PACKER BAKER FB -1 PERM PACKER 4.000 9,2086 6,2118 40.41 SBE BAKER 8040 SEAL BORE EXTENSION 4.000 8226] 6,2253 40,49 NIPPLE CAMCO D NIPPLE NO GO 2.750 NIPPLE ''20212 9.2363 62327 4052 SOS BAKER SHEAR OUT SUB 2.992 ther In Ho Ole (Wireilne retrievable plugs, valves, pumps, fish, etc.) TOp (N0) TOp Incl Top 1ttK9 IMF) 'I Des Cmm Run Oole 10 (in) 94500 63966 3640 FISH 3%6]15X]165LIPLoa(fmm AV6LIP.wasnever 4/26/1994 rountl: could be in Lend Perforations &:Slots snm cen. roIF(Tv Bm,"e) IsnolLn IF ME) 9M (lMKS) (XNB) 3nne Gale ) Type Com 83240 9.358.0 6,299.1 8,3250 A -1,3M-28 44&1996 4.OIPERF 414"BHCsg Gun. ie ode" I phasing 6VRFAGE:41.1-4.869.3— Mandrel Inserts St NTOP(NG) TopinKRl MR.) make= ODlin) S Valve D. Type Type PoRSim (in) TRO flan (pal) Run Oale Com 9,1533 6169] CAMCO MMM 11/2 GAS LIR DMV RK 0.066 9.9 bq/1994 GMUF :eIW3 Notes: General & Safety End Dala Annplalion 712&2010 NOTE: View Schemaliewl Alawbi STJlematil0 LOCPTGfl:9.A26 PACKER:9,N 3 66E:9N68 NIPPLG 9,MT SO6',82353 IPERf: 9.J3469]v6.0— FISH:9.4%0 PROOCCTION, W 8.9814.] 3M-26 Proposed CTD Schematic 62# H-4( a @ 121' 9-5/8" 36# J-55 shoe @ 4882' MD KOP @ 9314' MD via 7" wedge perfs 9358' MD 7" 26# L-80 shoe @ 9614' MD s 3-1/2" 9.3# J-55 EUE 8rd Tubing to surface 3-1/2" Camco W-1 Landing Nipple @ 2021" RKB (2.812" min ID) 3-1/2" Camco MMM gas lift mandrel @ 9153' RKB Baker GBH -22 Locator Seal Assembly @ 9202' RKB (3.0" ID) Baker FBI Perm packer @ 9205' RKB (4.0" ID) Baker SBE @ 9209' RKB (4" ID) 3-1/2" Camco D Nipple @ 9227' RKB (2.75" min ID, No -Go) Note: Will be drilled out to 2.80" ID pre -CTD Baker SOS @ 9236' RKB (2.992" ID) 3-1/2" tubing tail @ 9237' RKB 3M -26L1-01 wp03 TD @ 12,500' MD Liner top @ 9220' MD 31M-261_1 wp04 TD @ 11,700' MD Liner top @ 9600' MD Carlisle, Samantha J (DOA) From: Rixse, Melvin G (DOA) Sent: Thursday, June 14, 2018 1:41 PM To: Carlisle, Samantha J (DOA) Subject: FW: [EXTERNAL]Re: 3M-26 10-403 Question Samantha, Do you handle the 10-403 withdrawal? See below. Mel From: Plunkett, Ethan T[mailto:Ethan.T.Plunkett@conocophillips.com] Sent:Thursday,June 14, 2018 1:13 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; mel.rixse@bp.com; Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Cc: Haggerty-Sherrod, Ann (Northland Staffing Services)<Ann.Haggerty-Sherrod@contractor.conocophillips.com>;CP•3 Prod Engrs<n1223@conocophillips.com> Subject: RE: [EXTERNAL]Re: 3M-26 10-403 Question Good afternoon Victoria, Please withdraw the 10-403 Sundry approved dated 6/14/2017 submitted by Yemeli Gozon for 3M-26 to convert from prod to inj service. We would like to keep the well on production. 3M-26 API#5002922431 Permit#193193 VANEDJUN 2 1 L" i Best, Ethan Plunkett Ethan Plunkett I3NIMROQ- Petroleum Engineer I WLR BPO Coordinator I GKA Base I Professional Engineer 10: (907) 263-4280 C: (918)812-2284 From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.Rov> Sent:Thursday,June 14, 2018 11:07 AM To: Plunkett, Ethan T<Ethan.T.Plunkett@conocophillips.com>; mel.rixse@bp.com Subject: Re: [EXTERNAL]Re: 3M-26 10-403 Question Ethan, Send an email withdrawing the sundry. Thanx, Victoria 1 RBDMSs JUN 2 0 2018 Sent from my iPhone • • On Jun 14,2018,at 10:43 AM, Plunkett, Ethan T<Ethan.T.Plunkett@conocophillips.com>wrote: Hi Victoria, No 10-404 has been filed on 3M-26 after the recent 10-403 (Producer to injector). From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Sent:Thursday,June 14, 2018 10:16 AM To: Plunkett, Ethan T<Ethan.T.Plunkett@conocophillips.com> Cc: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: [EXTERNAL]Re: 3M-26 10-403 Question Did you file a 10-404 on the conversion sundry? Sent from my iPhone On Jun 14, 2018, at 10:08 AM, Plunkett, Ethan T<Ethan.T.Plunkett@conocophillips.com>wrote: Well Name: 3M-26 API # 500292243100 Permit# 193193 Good morning, Last summer, a 10-403 was filed for 3M-26 to convert from producer to injector. The well was converted but has not injected any water. I am currently looking at bringing it back to producer. Would we just cancel the 10-403 from last summer to keep it as a producer? Thanks for the help, Ethan Ethan Plunkett I3NIMROQ- Petroleum Engineer I WLR BPO Coordinator I GKA Base Professional Engineer I 0: (907) 263-4280 C: (918)812-2284 2 • %,OF T� • . ��.\��\�yyy �� THE STATE Alaska Oil and Gas ti,, of LAsKA Conservation Commission "----_=_ - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 (7- ±*S Q. Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Hilaire Yemeli-Gozon Petroleum Engineer scam juN 2 22011, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-26 Permit to Drill Number: 193-193 Sundry Number: 317-235 Dear Mr. Yemeli-Gozon: 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, 1161 Cathy Id. Foerster Chair DATED this 14 day of June, 2017. RBDMS 1. ----JUN 1 6 2017 • • RECEIVED STATE OF ALASKA JUN 0 7 207, ALASKA OIL AND GAS CONSERVATION COMMISSION 09-5 b I t, ( 7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon LJ Plug Perforations Li Fracture Stimulate LJ Repair Well LJ Operations shutdown LI Suspend 9 Perforate 9 Other Stimulate 9 Pull Tubing 9 Change Approved Program[] Plug for Redrill 9 Perforate New Pool 9 Re-enter Susp Well 0 Alter Casing 9 Other: _Prod to Inj L✓ ' 2.Operator Name: 4.Current Well Class: /I4 5.Permit to Drill Number ConocoPhillips Alaska,Inc. Exploratory 9 Development [7.1 193-193 ' 3.Address: Stratigraphic 9 Service L 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 7.If perforating: 50-029-22431-00 • 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 Q No 0 v KRU 3M-26 ' 9.Property Designation(Lease Number): ?a 10.Field/Pool(s): ADL 25522 Ar 2,518 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): 9,625' • 6,534' • 9522 • 6453' • None None Casing Length Size MD ND Burst Collapse Structural Conductor 78' 16" 121' 121' 1640 670 Surface 4,841' 10" 4,882' 3,624' 3520 2020 Intermediate Production 9,576' 7" 9,615' 6,526' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9324-9358 6299-6325 3.500" L-80 9,236' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER FB-1 PERM PACKER MD=9205 TVD=6209 12.Attachments: Proposal Summary 2 Wellbore schematic L✓J 13.Well Class after proposed work: Detailed Operations Program 9 BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development[ 1 Service 14.Estimated Date for 6/15/2017 15.Well Status after proposed work: Commencing Operations: OIL 9 WINJ 9 WDSPL 9 Suspended ❑ 16.Verbal Approval: Date: GAS 9 WAG 9. GSTOR ❑ SPLUG 0 Commission Representative. GINJ Q Op Shutdown 9 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Hilaire Yemeli-Gozon Hilaire Yemeli-Gozon Contact Name: Authorized Title: Petroleum ngineer / Contact Email: Hilaire.Yemeli-Gozon@Conocophillips.com (/�'��` • Q�/O//9�/�? Contact Phone:(907)265-1478 Authorized Signature: ( ��CC Date: V( (� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3 17- 235 ' Plug Integrity 9 BOP Test 9 Mechanical Integrity TestLocation Clearance ❑ + C.(14 t,� Other: �1,� Post Initial Injection MIT Req'd? YesNo Spacing Exception Required? Yes LI No ( Subsequent Form Required: /V — .6 4- RDDMS C-c- JUN 1 6 2017 APPROVED BY Approved by: gieCOMMISSIONER THE COMMISSION Date:6 – /c/_ )7 ' f�j�• 0%7 VIL G h3//7 Form 10-403 Revised 4/2017 0 R ® Subsin Form ane iofPA1bo n is valid for 12 months from the date of approval. Attachments in Duplicate ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 RECEIVED May 26, 2017 JUN 0 7 2017 AOGCC Commissioner AOGCC V 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 3M-26 from Oil Production to Water Alternating Gas Injection service. 3M-26 was drilled as an injector and had been injecting from July 29th, 1994 to August 2nd, 2016 when it was shut-in and flow back operations started 8/8/2016 for reservoir pressure management ahead of—Offset CTD drilling. Enclosed you will find the 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 3M-26 (PTD# 193-193) If you have any questions regarding this matter, please contact me at 907-265-1478. Sincerely, Hilaire Yemeli-Gozon Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Proposal Summary Area Map Well Schematic 1 • • 3M-26 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3M-26PTD# 193-193 ( ) from oil production service to water injection service. Area of Review KRU Well 3M-26 is waiting to be converted to dedicated water injection to provide injection into the reservoir to increase the ultimate recovery of oil. 3M-26 is anticipated to support 3M- 17 The top of the C sand was found at 9,311' MD/6,289' TVD The top of the A sand was found at 9,325' MD/6,300' TVD Area map with % mile radius around target injection zone (see attached) The map attached shows that there are no production/injection wells located within a % mile radius of the 3M-26 penetration of the Kuparuk interval Mechanical Condition of the Well to be Converted The mechanical condition of Kuparuk well 3M-26 is good and is classified as a "single casing" well. The injection tubing/casing annulus is isolated via BAKER FB-1 PERM PACKER located at 9,205' MD (6,209' TVD) A State-witnessed MIT-IA will be performed once well 3M-26 is converted to water injection, online, and stabilized CBL and interpretation of the cement quality The intermediate casing CBL indicates sufficient formation bond (7,800'-9,450' MD/6,733' — 8,072' TVD) The CBL interpretation was completed on the PTD's. • The 16" conductor was cemented with 340 ASI CMT. • The 9-5/8" surface casing was cemented with 950 SX ASIII, 530 SX G CMT. • The 7" production casing was cemented with 250 SX CLASS G. • • 1 $ 11 E T13NR9E ADL025522 ADL025512 N 2 tv7 ;_;3M ADL425521 ADLQ25523 Well Trajectory ConocoPhillips VVell Open Interval laska, Quarter Mile Open Interval Radius l 3m-26A lI CPAI Leases 0.2 0,4Injection Swap Analysis There are nc wells that intersect the Miles Qua-ter Milt Open Interval Radius. t 5/1&2017 • Al-' KUP INJ 3M-26 t< Conor PI iUips 4 * 4 Well Attributes Max Angle MD TO Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl 7) MD(ftKB) Act Btm(ftKB) xaacoraa,ps a*' 500292243100 KUPARUK RIVER UNIT INJ 56.75 7,333.56 9,625.0 "' Comment H25(pen)) Date Annotation End Date KB-Grd(ft) `Rig Release Date 3M-26,5/120162.1623 PM SSSV:NIPPLE LAST WO 41.00 1/17/1994 vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,393.0 4/30/2016 Rev Reason:TAGpproven 5/1/2016 I o til Casing Strings ._ HANGER 36.5 _ Casing Drption OD(in) ID(in) a Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H-40 WELDED 41'ii 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 41.1 4,882.2 3,623.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread PRODUCTION 7 6.276 38.7 9,614 7 6,525.6 26.00 L-80 BTC MOD Tubing Strings ,f Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 1I i ' TUBING 31/2 2.992 36.8 9,237.2 6,233.3 9.30 J-55 EUE8rdMOD ; i , Completion Details Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) .". 36.8 36.8 0.26 HANGER FMC GEN IV HANGER 3.500 2,0212 1,903.0 37.25 NIPPLE CAMCO W-1 LANDING NIPPLE W/SELECTIVE 2.812 PROFILE 9,202.6 6,207.0 40.37 LOCATOR BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 CONDUCTOR,43.0-121.0 9,205.3 6,209.1 40.39 PACKER BAKER FE-1 PERM PACKER 4.000 '.', 9,208.6 6,211.6 40.41 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 9,226.7 6,225.3 40.49 NIPPLE CAMCO D NIPPLE NO GO 2.750 9,236.3 6232.7 40.52 SOS BAKER SHEAR OUT SUB 2.992 NIPPLE;2,021.2 Other In Note(Wireline retrievable plugs,valves,pumps, fish,etcs,) Top(TVD) Top Inc( Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 9,450.0 6 396.6 38.40 FISH 3 X 6 7/8 X 7/8 SLIP Lost from Air SLIP,was never 4/26/1994 e found;could be in hole Perforations&Slots Shot Dans Tap(TVD) Btm(TVD) (shots/f Tap(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,324.0 9,358.0 6,299.1 6,325.0 A-1,3M-26 4/26/1994 4.0 IPERF 4 1/2"BH Csg Gun,180 deg.phasing SURFACE;41.1-4,882.2--• Mandrel Inserts Sl atl N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 9,153.3 6,169.3 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/3/1994 Notes:General&Safety GAS LIFT;9,153.3 a End Date Annotation 7/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;9,202.6 , i PACKER;9,205.3 a SBE;9208.6 ,. 4 NIPPLE;9,226 7 , SOS,9,236.3 (PERF;9,324 0-9,356.0--_. _. FISH;9,450.04 PRODUCTION',386-9614.7 a • • ,k( i Gh/1/? im 3 T13NR$L T13NR9E ADL025522 ADL025512 tD N E M co M 3M h•is 30\ ADL025523 3 207 , 30.13, 3M-12 Vii' 3M-06 30-19 3t- .--;- 3M-to (�..)3M 30 4".\ / 3M-05 Well Trajectory / bcs) _ _ �Q ADI 025521 Well Open Interval \1. N •`� ConocoPhillips ® Quarter Mile Open Interval Radius ,� ,"RR, 3, N 4�;y° b.. A Alaska,Inc. CPAI Leases 3M-26 Other Active Wells 4 0 0.2 0.4 Injection Swap Analysis There are no wells that intersect the / Miles Quarter Mile Open Interval Radius. 6/8/2017 • • • Bettis, Patricia K (DOA) From: Yemeli-Gozon, Yemeli <Hilaire.Yemeli-Gozon@conocophillips.com> Sent: Friday,June 9, 2017 7:10 AM To: Bettis, Patricia K(DOA) Subject: RE: [EXTERNAL]KRU 3M-26 (PTD 193-193): Sundry Application Attachments: Well_3M_26_Inj_Swap_Ana_w_AII_Other_Wells.png Patricia, Please see attached the map you requested in relation to 3M-26 Production to injection Sundy application (10-403) Paper copy is heading your way. Regards, H.Yemeli-Gozon Senior Petroleum Engineer Drill Sites 3NIMROQ &WLUG Coordinator Cell: (907)306-9453 Desk: (907) 265-1478 Office:ATO-1344 From:Yemeli-Gozon,Yemeli Sent:Thursday,June 08, 2017 2:09 PM To: 'Bettis, Patricia K(DOA)'<patricia.bettis@alaska.gov> Subject: RE: (EXTERNAL]KRU 3M-26 (PTD 193-193): Sundry Application Good afternoon Patricia, Thank you for promptly starting processing this sundry application. 3M-18 was intentionally left off because its trajectory was determined not to be in a 1/4 mile radius of 3M-26 injection interval. To provide a visual, I will resubmit a map,showing all wellbore trajectories that cross Section 24,Township 13N, Range 8E. next week. Would you still want the discussion related to 3M-18 even if it is confirmed not to be in a 1/4 mile radius on 3M-26 injection interval? Respectfully, H.Yemeli-Gozon Senior Petroleum Engineer Drill Sites 3NIMROQ &WLUG Coordinator Cell: (907) 306-9453 Desk: (907) 265-1478 Office:ATO-1344 From: Bettis, Patricia K(DOA) [mailto:patricia.bettisWalaska.gov] Sent:Thursday,June 08, 2017 11:16 AM 1 • s • To:Yemeli-Gozon,Yemeli<Hilaire.Yemeli-Gozon@conocophillips.com> Subject: [EXTERNAL]KRU 3M-26 (PTD 193-193): Sundry Application Good morning Hilaire, On the supporting map entitled 3M-26 Injection Swap Analysis which show the quarter-mile AOR, it appears that the producer KRU 3M-18 was left off. Please resubmit the map, showing all wellbore trajectories that cross Section 24, Township 13N, Range 8E. Please also provide a discussion assessing the probability that KRU 3M-18 may serve as a fluid migration conduit. The mechanical integrity of those portions in the wellbore that have some probability of experiencing injection related pressures must be demonstrated to show zonal isolation of the reservoir. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 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. 2 STATE OF ALASKA • AIL OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed. Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill rPerforate New Pool Repair Well r Re-enter Susp Well Other: PROD>30 days rci 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 193-1930 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50-029-22431-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25522 ALK 2558 KRU 3M-26 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 9625 feet Plugs(measured) None true vertical 6534 feet Junk(measured) None Effective Depth measured 9522 feet Packer(measured) 9205 true vertical 6453 feet (true vertical) 6209 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78' 16 121' 121' SURFACE 4841' 9 5/8 4882' 3624' PRODUCTION 9576' 7 9615' 652E"„,° "°`` C E V Perforation depth: Measured depth: 9324-9358 pJAN2017.3 1 AUG2016 Vertical Depth: 6299-6325 SCANNED AOGGC Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 9236 MD,6233 TVD Packers&SSSV(type,MD,and TVD) NIPPLE=CAMCO W-1 LANDING NIPPLE W/SELECTIVE PROFILE @ 2021 MD and 1903 TVD PACKER=BAKER FB-1 PERM PACKER @ 9205 MD and 6209 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbi Casing Pressure Tubing Pressure Prior to well operation 0 0 102 600 2838 Subsequent to operation 3 2 619 1050 162 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p' Exploratory r Development 17 Service r Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil F Gas r WDSPL i Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG E GINJ r SUSP r SPLUG r 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: N/A Contact Darrell Humphrey/Bob Christensen Email: n1139(C17conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature Phone:659-7535 Date 4/ Vri RBDMS 1" AUG 1 6 2016 Form 10-404 Revised 5/2015 51 Submit Original Only • • 3M-26 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/08/16 Open Well- Return to Service- Produce > 30 days for resevoir pressure management • • KUP INJ 3M-26 ConocoPhillips Well Attributes Max Angle&MD TD Alaska.Inc. • Wellbore API/DWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) =o.wcocrvatps ' 500292243100 KUPARUK RIVER UNIT INJ 56.75 7,333.56 9,625.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-26,5/1/2016 21623 PM SSSV:NIPPLE LAST WO: 41.00 1/17/1994 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,393.0 4/30/2016 Rev Reason:TAG pproven 5/1/2016 Jeli .21 Casing Strings HANGER;36.8 I.11_ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H-40 WELDED --- l' 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 41.1 4,882.2 3,623.6 36.00 3-55 ETC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread aa4mmu„m„mu.uom,n,n,,.,,.,,,,.num,o,,..i,,,nuu PRODUCTION 7 6.276 38.7 9,614.7 6,525.6 26.00 L-80 BTC-MOD Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(16111) Grade Top Connection TUBING 31/2 2.992 36.8 9,237.2 6,233.3 9.30 J-55 EUE8rdMOD a Completion Details Nominal ID $ Top(ftKB) Top(ND)(ftKB) Top Incl(°)_ Item Des Com lin) .v.nA_ t✓..,.n..r 36.8 36.8 0.26 HANGER FMC GEN IV HANGER 3.500 2,021.2 1,903.0 37.25 NIPPLE CAMCO W-1 LANDING NIPPLE W/SELECTIVE 2.812 PROFILE 9,202.6 6,207.0 40.37 LOCATOR BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 CONDUCTOR;43.0-121.o-O • 9,205.3 6,209.1 40.39 PACKER BAKER FB-1 PERM PACKER 4.000 9,208.6 6,211.6 40.41 SBE 'BAKER 80-40 SEAL BORE EXTENSION 4.000 9,226.7 6,225.3 40.49 NIPPLE CAMCO D NIPPLE NO GO 2.750 9,236.3 6,232.7 40.52'SOS BAKER SHEAR OUT SUB 2.992 NIPPLE;2.021.2 -H Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (') Des Corn Run Date ID(in) 9,450.0 6,396.6 38.40 FISH 3 X 6 7/8 X 7/8 SLIP Lost from Air SLIP,was never 4/26/1994 - found;could be in hole Perforations&Slots Shot Den Top(TVD) Btre(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,324.0 9,358.0' 6,299.1 6,325.0 A-1,3M-26 4/26/1994 4.0 IPERF 4 1/2"BH Csg Gun,180 deg.phasing Mandrel Inserts SURFACE;41.1-4.882.2-4 St ati on Top(ND) Valve Latch Port Size TRO Run N, Top(MB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 9,153.3 6,169.3 CAMCO MMM 11/2 GAS LIFT DMY RK 0.000 0.0 6/3/1994 Notes:General&Safety GAS LIFT;9,153.3 End Date Annotation 7/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;9,202.6 I PACKER;9,205.3 l,,, SBE;9,208.6 NIPPLE;9.226.7 I II SOS;9,236.3 IPERF;9,324.0-9,358.0- I FISH;9,450.0 PRODUCTION;38.85,614.7 c4 n G- _/1 � li IN �o IFI5 xro Ors cu a, v _, m L L F-QY O CT G r ._ tJ a > E ; y0 Q C O p •E O C i- 0 ro ro @ Q Q Q ..� W O t0 l0 t0 co co t0 ryD O tn 7' E "_E m Q LI r r (0 . . . . . 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Q N w m co N N V N e N 6 LU E Z a1 w t , rl c AP C.2 VI ,-1 U o C L 09/15/08 ~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth C ~~ Well Job # ~- - h~i., F d. aii Log Description N0.4871 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD iC-172A 11978478 PRODUCTION PROFILE ~- 08/19/08 1 1 iC-172A 12080429 GLS/FBHP 08/19/08 1 1 3M-26 12096533 SBHP SURVEY 08/20/08 1 1 3N-02A 11996652 SBHP SURVEY 08/20/08 1 1 3M-22 11966276 SBHP SURVEY - 08/20/08 1 1 3C-17 11996657 SCMT C.YS - /(n 9/~-/ 08/25/08 1 1 3C-15A 11996659 PERF/SBHP SURVEY ~ ~O~S-p~~ ~~C~/~- 08/27/08 1 1 2U-06 12080428 LDL _p( 08/29/08 1 1 2V-15 11996661 PRODUCTION PROFILE ~ =0 08/29/08 1 1 2T-19 11996663 PRODUCTION PROFILE 08/31/08 1 1 2D-07 11975790 INJECTION PROFILE - ~~ / Q 09/07/08 1 1 2H-09 11975788 PRODUCTION PROFILE (p 09/05/08 1 1 1C-174 12096539 INJECTION PROFILE - ~ p 09/07/08 1 1 2H-12 12096540 PRODUCTION PROFILE ` 09/09/08 1 1 30-01 11975792 LDL ~^U~} 09/09/08 1 1 3F-10 11975789 LDL ~ 09/06/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • 1VIE1~®1lTl)iJ1®/I ~ State ®f Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday, July 08, 2008 Jim Regg P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3 M-26 FROM: Bob Noble KUPARUK RIV UNIT 3M-26 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv NON-CONFIDENTIAL Comm Well Name: KUPARUK RN UNIT 3M-26 Insp Num: mitRCN080707174623 Rel Insp Num: API Well Number: 50-029-22431-00-00 Permit Number: 193-193-0 Inspector Name: Bob Noble Inspection Date: 7/6/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3M-26 Type )(n) ~ N ~ T~ ~ 6209 jA ~ 1025 ~ 2990 ~ 2960 ~ 2960 ~ i P.T. 1931930 TypeTest SPT ~ Test psi i~ 2990 OA i 160 ~ 380 380 , 380 ' I Interval 4YRTST P~F, P ~ Tubjng ! 2350 ~ 2350 i 2350 ~ 2350 ~, Notes: ~~~~~ A1~ G ~ ~ 2008 Tuesday, July 08, 2008 Page l of 1 MEM ORAND UM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'L) t'O j I P.I. Supervisor \,e.ri ~ II Ot DATE: Wednesday, August 04, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3M-26 KUPARUK RIV UNIT 3M-26 FROM: Chuck Scheve Petroleum Inspector 8rc: Inspector Reviewed By: P.I. 8uprv :"\ße- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3M-26 API Well Number: 50-029-22431-00-00 Inspector Name: Chuck Scheve Insp Num: mitCSO40803203126 Permit Number: 193-193-0 Inspection Date: 8/312004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3M-26 Type Inj. N TVD 6534 IA 1000 2250 2250 2250 P.T. 1931930 TypeTest SPT Test psi 1551.25 OA 0 0 0 0 Interval 4YRTST P/F P Tubing 1850 1850 1850 1850 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, August 04, 2004 Pagel of 1 ON OR BEFO W AOGCC individual Well Page" I __.eoiogical Materials Inventory Date' 10/13/95 ~ m ~.M_, F DATA T DATA_PLUS RUN DATE_RECVD 9~ i9'~ ~ T 4'750-9625, oH-CDK/~DN R 0~9625, GCT C M P S o5/o?/94 613/08/94 93~193 ~GBT L 7800-9421 '! 02/14/94 ~°,3-19 ~ '~S~N~LWD/DC L 4750-9620 CMPS 05/09/94 9 3 - 19 3 ~DR-LWD/DC ~'D'R-VE ~ ? W~' i R/ ~.,'.~; ~ L 4282-9625 L 4282-9625 CMPS 05/09/94 CMPS 05/09/94 93~i93 /SiT (C&C) L 7800-9450 1 Are dry ditch samples requ±red? yes ~And received? yes.~-~:o --. Was Ehe well cored? yes ~_~alysis & description recei~~es Are well tests~_:-~-~'~ired'r._~,:,. " -I/w_s~-~ Well is in comp~_zance Initial COMMENT S 2, eceived? ye~ ii0 --'- 0'2/14/94 i10 ARCO Alaska, Inc. Date: May 06, 1994 Transmittal #: 9079 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of thi~ transmittal. ,~ 3H-31 .,,LIS Tape and Listing: 04--25-94 - "' LWD CDR/CDN 1 Bit Run 3H-25 LIS Tape and Listing: ~ 04-27-94 ¢"I..WD CDR/CDN 1 Bit Run 3H-23 LIS Tape and Listing: 04-25-94 ¢' LWD CDR/CDN 1 Bit Run 3M-23 LIS Tape and Listing: 04-22-94 "/'CDR/CDN-4 Bit Run with QRO Processing 3M-26 .LIS Tape and Listing: 04-27-94 v"CDR/CDN.4 Bit Run with QRO Processing IB/2E-17 LIS Tape and Listing: 05-03-94 ¢"'2 Pass CNTG Cased Hole Edit 3M-25 ./biS Tape and Listing: ~., "Run with QRO Proc.essina Receipt Acknowledged: ~ '-(-_ot~,...O - Please acknowledge receipt 94066 94083 94075 94018 94023 94102 05-02-94 94027 oate: DISTRIBUTION: Bob Ocanas State of Alaska ARCO Alaska, Inc. Date: May 06, 1994 Transmittal #: 9078 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. Please acknowledge /3H-25 5~.~[~ ,/3H-25 - "%3H-25 /3H-31 ",3H-31 9~H-23 H-23 H-23 \ 3M-23 _ /3M-26 ¢),~ ~.1~ ~/ 3M-26 //3M-24 ~'~'''tot5 ~/'",.3M-243M-24 /3M-25 ~--'t~ (~ 3M-25 %3M-25 '/CDR '/CDN ,,"CDR Very-Enhanced I~esistivity v/CDR ¢'CDN ,/CDR Very-Enhanced Resistivity v'CDR DR Very-Enhanced Resistivity ¢CDR ,,"CDN ,,,CDR Very-Enhanced Resistivity ,,'CDR ,/'CDN '-CDR Very-Enhanced Resistivity v~"NT-G v"CDR ,/'CDN ¢CDR Very-Enhanced ResistiVity DN '/'CDR Very-Enhanced Resistivity ~$.~-t¢'~ -" 2E- 17 v CNT-G/ Acknowledged: , 02-22-25-94 02-22-25-94 02-22-25-94 02-9-12-94 02-9-12-94 02-9-12-94 02-16-18-94 02-16-18-94 02-16-18-94 12-21-28-93 12-21-28-93 12-21-28-93 01-13-16-94 01-13-16-94 01-13-16-94 04-28-94 01-20-25-94 01-2O-25-94 01-20-25-94 01-2-5-94 01-2-5-94 01-2-5-94 4-22-94 Date: DISTRIBUTION: 4650-12414 4650-12414 11800-123OO 4950-10734 4950-10734 1O100-107OO 4O8O-9358 4080-9364 8795-9296 5350-12740 5320-12740 11750-12740 4282-9625 4750-962O 4282-9625 609O-6450 52O0-1249O 5170-12480 11600-12480 5050-10890 50151-10888 1010O-1082O 87OO-1O0OO -.% STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMib~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~] GAS r~ SUSPENDED E~ ABANDONED [~ SERVICE r~water Injector 2 Name of Operator 7 Permit Number 3 Address ~:~;. 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ~-- 50-029-22431 4 Location of well at surface ~" ..._ '~ 9 Unit or Lease Name / '~, . .,.,..' :.';'..~- :.-/h-.~;.~~ .: 939'FNL, 1563'FEL, SEC25, T13N, R8E, UM ,~ , _ ~.,.,.: ~'- : KUPARUKRIVER At Top Producing Intervali~~ 10 Well Number 82'FNL, 1365'FEL, SEC13, T13N, R8E, UM i~~~!: i~" 3M-26 At Total Depth - 11 Field and Pool 275' FSL, 1323' FEL, SEC 13, T 13N, R SE, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. RKB 68', PAD 27' GL ADL 25522 ALK 2558 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 01/10/94. 01/15/94. 04/26/94(CO M P) NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional~Survey~ 20 Depth where SSSV set 21 Thickness of permafrost 9625' MD, 6534' TVD 9522' MD, 6453' TVD YES ~ NO ~ LN @ 2021' feet MD 1700' APPROX 22 Type Electric or Other Logs Run LWD LOGS, USIT, CBU, GCT 23 CASING, LINER AND CEMENTING RECORD SE'FI'lNG DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16. 62.5# H-40 SURF 121' 24" 340 ASI CMT 9.625 36# J-55 SURF 4882' 12.25" 950 SX ASIII, 530 SX G CMT 7. 26# L-80 SURF 9610' 8.5" 250 SX CLASS G 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) 3-1/2" 9.3# J-55 9237' 9198' ELM 9324'-9358' 4 SPF MD 6299'-6325' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production [Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~_. FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (corr) Press. 24-HOUR RATE ~' 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA ECEIVED -9 1994 Form 10-407 ""Jb~u~l~ ~cl u p ii cate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. . GEOLOGIC ~S 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 9311' 6289' BASE KUPARUK C 9325' 6300' TOP KUPARUK A 9325' 6300' BASE KUPARUK A 9392' 6351' 31. LIST OF A-I-rACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. 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 ARCO ALASKA INC. DAILY OPERATION, PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3M-26 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25522 ALK 2558 50-029-22431 93-193 ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 01/11/94 ( 1) PARKER 245 TD: 2135' (2135) 01/12/94 ( 2) PARKER 245 TD: 4900' (2765) 01/13/94 ( 3) PARKER 245 TD: 4900'( o) 01/14/94 ( 4) PARKER 245 TD: 7300' (2400) DRILLING 16"@ 121' MW: 9.8 VIS: 63 PREP MOD F/MOVE. KING PIN FROZEN INTO CAR BODY OF LAMPSON ON UTILITY MOD. DEFROST SAME. MOVE RIG F/3M-25 TO 3M-26. SET IN & FLANGE UP 20" DIVERTER & DIVERTER LINES. FUNCTION TEST DIVERTER SYSTEM. TEST WITNESS APPROVED BY LOU GRIMALDI W/AOGCC. MU BHA & ORIENT SAME. CLEAN OUT ICE F/50'-121'. DRILL F/121' TO 600' KOP. DIRECTIONAL DRILL F/600'-2135'. SURV W/MWD & TAKE GYRO SURV AS NEEDED. SPUDDED @ 1700 HRS 01/10/94. SHORT TRIP-RIH 16"@ 121' MW:10.0 VIS: 51 DRILL 12.25" HOLE F/2135'-3070'. CBU. SHORT TRIP TO HWDP-NO PROBLEMS. SERV RIG. RIH. NO FILL. DRILL F/3070'-4187'. REPAIR TOP DRIVE MOTOR BRAKE. DRILL F/4187'-4900'. CBU. SHORT TRIP TO HWDP. TIGHT & SWABBING F/1970'-1870' RIH. NU BOPE 9-5/8"@ 4882' MW:10.0 VIS: 0 FIN RIH. CIRC & COND MUD TO RUN CSG. POOH. LD MWD, MONEL, & MOTOR. RU TO RUN CSG. HOLD SAFETY MEETING. RUN 60 JTS 9-5/8" J-55 BTC CSG. BREAK CIRC & CBU. CONT TO RUN CSG. SET SHOE @ 4882', RAN A TOTAL OF 120 JTS. CIRC & COND F/CMT JOB. CMT W/950 SX LEAD CMT FOLLOWED BY 550 SX CLASS G TAIL. BUMPED PUG TO 2000 PSI. FLOATS HELD. LD LANDING JT. RD CSG EQUIP. ND DIVERTER, WASH OUT ANN & DIVERTER VALVES. DO TOP JOB W/DOWELL-PMP 15 BBLS CMT. INSTALL PACKOFF & SPEED HEAD W/25K FT/LBS. NU BOPE. DRILLING 8.5" HOLE 9-5/8"@ 4882' MW: 8.9 VIS: 34 NU BOPE & TEST-OK. TEST WITNESSED BY AOGCC REP JERRY HERRING. INSTALL WEAR BUSHING. PU BHA. CHANGE BEARING SECTION ON TURBINE. CONT TO PU BHA. PROGRAM & ORIENT MWD TOOLS. SERV RIG & TOP DRIVE. TIH. SLIP & CUT DRILL LINE. BREAK CIRC. TAG FC @ 4795' TEST CSG TO 2000 PSI. DRILL OUT FC, CMT, & SHOE. TAGGED SHOE @ 4882' DRILL 10' NEW FORM TO 4910' & PERFORM LOT TO 12.6 PPG EMW. DRILL 8.5" HOLE F/4910'-7300'. RECEIVED M~Y --9 1994 ,,~sKa~ u~l & Gas Cons. CommJs,. Anchorage WELL: 3M-26 API: 50-029-22431 PERMIT: 93-193 PAGE: 2 01/15/94 ( 5) PARKER 245 TD: 9180' (1880) 01/16/94 ( 6) PARKER 245 TD: 9625' ( 445) 01/17/94 ( 7) PARKER 245 TD: 9625'( o) 02/11/94 ( 8) DOWELL TD: 9625 WASH TO BTM F/LWD LOGS 9-5/8"@ 4882' MW: 9.7 VIS: 38 DRILL 8.5" HOLE F/7300'-8530' SERV RIG & TOP DRIVE. DRILL F/8530'-9180' BEGIN GRADUAL WT UP OF MUD TO 9.7 PPG @ 8800'_ CBU. POOH. REMOVE SOURCE & DOWNLOAD INFO F/ANADRILL TOOL. PU ROTARY ASSY & LWD TOOLS, LOAD SOURCE. RIH FILLING PIPE @ 3600' & 7000' WASH DN F/9080'-9180' F/LWD LOGS. RUN 7" CSG 9-5/8"@ 4882' MW:10.1 VIS: 40 DRILL 8.5" HOLE F/9180'-9380'. SERV RIG & TOP DRIVE. DRILL F/9380'-9625' MAKE SHORT TRIP TO 500' ABOVE KUPARUK SANDS. NO PROBLEMS. CIRC & COND MUD FOR CSG. DROP SURV & PMP DRY JOB. POOH. RETRIEVE SURV @ HWDP, REMOVE LWD SOURCE, & DOWNLOAD ALL LOGGING INFO. RU FLOOR TO RUN 7" CSG. HOLD PRE-JOB SAFETY MEETING. RUN 7", 26#, L-80 CSG. FINAL REPORT 7"@ 9608' MW: 0.0 VIS: 0 RUN A TOTAL OF 224 JTS 7" L-80 BTC-MOD CSG. SHOE SET @ 9610'. CMT W/53 BBLS CLASS G CMT @ 15.8 PPG. DID NOT BMP PLUG. CIP @ 1855 HRS 01/16/94. ND BOP STACK. PU SAME. SET SLIPS W/255K. MAKE ROUGH CUT ON 7" FIN ND STACK. MAKE FINAL CUT & DRESS SAME. INSTALL PACKOFF & TREE. TEST TREE TO 3000 PSI. FLUSH ANN W/WATER. FREEZE PROTECT W/70 BBLS DIESEL, FINAL PRESS 1100 PSI. LD DP F/DERRICK F/RIG MOVE. RIG RELEASED 0300 HRS 01/17/94. 7"@ 9608' PERFORM ARCTIC PACK ON 3M-26. 04/25/94 ( 9) NORDIC 1 TD: 9625 PB: 9450 RU SCHLUMBERGER 7"@ 9608' MW: 0.0 MOVED RIG FROM 3M-25A TO 3M-26. ND DRY HOLE TREE. NU BOP. TEST BLIND RAMS & BROKEN FLANGES TO 3500 PSI. TESTED 7" CSG TO 3500 PSI FOR 30 MIN. RECEIVED M~Y --9 1994 Gas Cons. Commission Anchorage WELL: 3M-26 API' 50-029-22431 PERMIT: 93-193 PAGE: 3 04/26/94 (10) NORDIC 1 TD' 9625 PB: 9450 SET STANDING VALVE IN D-NIPPLE 7"@ 9608' MW: 0.0 RU SWS. TEST LUB TO 1000 PSI. PERF A SAND W/4-1/2" OREINTED CSG GUN @ 4 SPF F/9324'-9358'. RAN GR & JB TO 9250' RIH W/COMP ASSY-3-1/2" 9.3# J-55 MOD EUE 8RD TBG. SET PKR @ 9198' W/TAILPIPE BTM @ 9230' RIH W/LOC SEAL ASSY & GLM ON TBG. LOST SLIP DIE ON AIR SLIPS & UNALBE TO LOCATE SAME. SLIP DIMENSION 3" X 6-7/8" X 1/2". FIN RIH W/COMP ASSY. TAGGED FB-1 PKR @ 9198' STUNG LOCATOR SEAL ASSY INTO PKR. PU & SPACED OUT. INSTALLED TBG HGR & LANDED SAME. PRESS UP ON TBG TO 500 PSI. RU HES SLICKLINE. RIH W/2.62" IMPRESSION BLOCK TO 9229' POOH W/SAME. HAD IMPRESSION OF BALL IN SHEAR OUT SUB. SLIP DIE NOT IN TBG~STRING. PRESS ANN & TBG TO 2400 PSI & BALL SHEARED OUT OF SHEAR OUT SUB PREMATURELY. MU STANDING VALVE & RIH. SET STANDING VALVE IN D-NIPPLE 04/27/94 (11) NORDIC 1 TD: 9625 PB- 9450 FINAL REPORT 7"@ 9608' MW: 0.0 PRESS TEST ANN & TBG TO 2500 PSI-OK. PRESS TEST TBG TO 3000 PSI-OK. RIH W/SL. PULL STANDING VALVE F/D-NIPPLE @ 9226' SET B?V. ND BOP 7-1/16" BOP STACK, NU FMC 3-1/8" 5000 PSI TREE. TEST PACK-OFF TO 5000 PSI. CHANGE WING & SWAB VALVE TO ARCO CONFIGURATION. TEST TREE TO 5000 PSI-OK. FREEZE PROTECT ANN W/12 BBLS DIESEL, BULLHEAD 4 BBL DIESEL DN TBG FOR FREEZE PROTECTION. RD & DRAIN LINES. CLEAN PITS. CLEAN UP WELL SITE, SECURE WELL. RELEASE RIG @ 1200 HRS 04/26/94. SIGNATURE: DATE: RECEIVED MAY ~-9 ]994 '~Ka u~, & Gas Oons. Oonrl~jssJoD Anchorage SUB. SURFA CE DIRECTIONAL SURVEY ~----'] UIDANCE F~ONTINUOUS ['~IOOL EIVED MAY -'9 1994 Aiaska Oil & Gas Cons. Commi8smr; Anchorage Company Well Name Field/Location ARCO ALASKA, INC. . 3N-26 (939'FNL, 1563'FEL~ SEC 25~ T13Nz R8E~ UN) KUAPRUK, NORTH SLOPE, ALASKA Job Reference No: 94043 Log~l By: FORNICA Date = 30-JAN- 1994 Computed By; SINES · SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 3M-26 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE' 30-JAN-1994 ENGINEER' FORMICA METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 2 DEG 10 MIN EAST COMPUTATION DATE' 17-FEB-94 PAGE I ARCO ALASKA, INC. 3M-26 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY' 30-JAN-1994 KELLY BUSHING ELEVATION' 68.00 FT ENGINEER' FORBICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 O0 -68 O0 0 0 N 0 0 E 0 O0 N 100 200 300 400 500 600 700 8O0 900 O0 99 O0 199 O0 299 O0 399 O0 499 O0 599 O0 699 O0 797 O0 894 94 31 93 131 92 231 9O 331 88 431 85 531 34 631 94 0 57 S 34 28 W 93 0 59 S 29 7 W 92 0 59 S 39 5 W 90 1 3 S 40 11W 88 1 3 S 38 0 W 85 3 20 N 48 19 W 34 7 55 N 36 7 W 79 729.79 12 28 N 32 52 W 65 826.65 16 I N 22 38 W 0 O0 -0 62 -2 13 -3 54 -4 94 -6 43 -6 44 0 82 14 79 36 24 0 O0 0 02 0 O0 0 O0 0 O0 0 O0 0 03 0 05 0 05 0 05 0 2 3 4 6 6 1 15 37 60 S 0 08 S 1 45 S 2 81 S 3 26 S 4 19 S 6 30 N 12 65 N 22 55 N 34 48 W 0 39 W 2 33 W 4 48 W 5 66 W 7 53 W 9 82 W 12 60 W 27 07 W 50 0 O0 E 0 O0 N 0 0 E 77 S 38 52 W 50 S 33 50 W 16 S 34 0 W 94 S 35 54 W 80 S 36 42 W O0 S 46 29 W 89 N 84 12 W 49 N 55 18 W 70 N 42 13 W 1000 O0 990 07 922.07 18 lg N 14 1 W 1100 O0 1084 1200 O0 1179 1300 O0 1272 1400 O0 1364 1500 O0 1454 1600 O0 1543 1700 O0 1631 1800 O0 1719 1900 O0 1804 64.38 81 1016 81 18 48 N 10 35 W 27 1111 84 1204 84 1296 89 1386 45 1475 74 1563 09 1651 22 1736 95.37 27 19 43 N 8 1 W 127.53 84 21 50 N 4 5 W 162.41 84 24 27 N 0 56 W 201.44 89 26 56 N 0 49 E 244.87 45 27 55 N 1 10 E 291.32 74 28 22 N 0 56 E 338.26 09 29 53 N 0 42 E 386.92 22 33 25 N 0 55 E 439.34 0 O4 0 O3 0 O2 0 02 0 O2 0 01 0 O2 0 O2 0 01 0 02 66 04 N 42 98 W 78 80 N 33 3 W 97 129 164 203 247 293 340 389 441 31N 49 69 N 55 75 N 58 86 N 6O 32 N 6O 77 N 59 71N 58 38 N 57 81N 57 78 W 109 11W 140 89 W 174 48 W 212 38 W 254 54 W 299 65 W 345 99 W 393 27 W 445 3O N 27 5 W 92 N 23 1W 96 N 19 40 W 65 N 16 32 W 59 N 13 43 W 74 N 11 27 W 72 N 9 46 W 67 N 8 28 W 50 N 7 23 W 2000 O0 1885 98 1817 98 36 42 N 1 18 E 496 87 2100 '2200 2300 2400 2500 2600 2700 2800 2900 O0 1964 O0 2039 O0 2111 O0 2180 O0 2244 O0 2303 O0 2360 O0 2416 O0 2472 53 1896 63 1971 59 2043 20 2112 55 2176 94 2235 51 2292 54 2348 29 2404 53 39 44 N 1 22 E 558 63 42 38 N 2 20 E 624 59 45 12 N 2 6 E 694 20 48 7 N 2 30 E 766 55 51 41 N 2 2 E 843 94 55 1 N 1 7 E 923 51 55 49 N 1 1 E 1006 54 56 3 N 1 15 E 1089 29 56 11 N 1 29 E 1172 73 73 15 89 40 83 27 09 10 0 O3 0 0 0 0 0 0 0 0 0 499 34 N 56.11 W 502 48 N 6 25 W 0'3 561 O3 627 03 696 03 769 03 845 03 926 03 1008 02 1091 O1 1174 19 N 54.79 W 563 16 N 52.46 W 629 53 N 49.82 W 698 20 N 46.86 W 770 65 N 43.74 W 846 06 N 41.54 W 926 50 N 40.08 W 1009 31 N 38.44 W 1091 31N 36.44 W 1174 86 N 5 35 W 35 N 4 47 W 31 N 4 5 W 63 N 3 29 W 78 N 2 58 W 99 N 2 34 W 29 N 2 17 W 99 N 2 1 W 87 N 1 47 W 3000.00 2527.98 2459 98 56 13 N 1 26 E 1255.15 3100.00 2583.58 2515 3200.00 2639.42 2571 3300 O0 2695.67 2627 3400 O0 2752 19 2684 3500 O0 2809 07 2741 3600 O0 2866 32 2798 3700 O0 2923 97 2855 3800 O0 2982 40 2914 3900 O0 3041 41 2973 58 56 8 N 1 22 E 1338.26 42 55 58 N 1 15 E 1421.21 67 55 34 N 1 24 E 1503.88 19 55 30 N 1 28 E 1586 37 07 55 11 N 1 24 E 1668 61 32 55 0 N 1 12 E 1750 59 97 54 30 N 0 55 E 1832 28 40 54 2 N 1 7 E 1913 42 41 53 34 N 0 50 E 1994 14 0 O0 1257 34 N 34.32 W 1257.81 N 1 34 W O0 1340 O0 1423 O0 1506 O0 1588 O0 1670 O0 1752 O0 1834 O0 1915 O1 1996 43 N 32.25 W 1340.82 N 1 23 W 37 N 30 37 W 1423.69 N 1 13 W 02 N 28 52 W 1506.29 N 1 5 W 49 N 26 38 W 1588.71 N 0 57 W 71N 24 31W 1670.89 N 0 50 W 69 N 22 45 W 1752.83 N 0 44 W 38 N 21 03 W 1834.50 N 0 39 W 52 N 19 56 W 1915.62 N 0 35 W 24 N 18 18 W 1996.32 N 0 31 W ARCO ALASKA, INC. 3M-26 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: iT-FEB-94 PagE 2 DATE OF SURVEY: 30-JAN-i994 KELLY BUSHINg ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3101 21 3033.21 52 59 N 0 38 E 2074 26 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3161 O0 3222 O0 3280 O0 3338 O0 3396 O0 3456 O0 3516 O0 3575 O0 3634 87 3093.87 52 25 N 0 26 E 2153 56 3154.56 53 40 N 0 54 E 2233 42 3212 42 54 52 N I 18 E 2314 22 3270 22 54 28 N 1 20 E 2396 91 3328 91 53 44 N I 16 E 2477 50 3388 50 52 57 N I 28 E 2557 74 3448 74 53 33 N 2 40 E 2637 26 3507 26 54 18 N 3 18 E 2718 11 3566 11 53 34 N 2 38 E 2799 0 O1 2076 39 N 17 19 W 2076 46 N 0 28 W 73 0 17 0 71 0 31 0 27 0 56 0 38 0 45 0 29 0 01 2155 O1 2235 O1 2316 O1 2398 01 2479 O1 2559 O1 2639 O1 2720 O1 2801 88 N 16 35 N 15 89 N 14 47 N 12 42 N 10 70 N 8 47 N 5 43 N 1 17 N 2 46 W 2155 73 W 2235 03 W 2316 14 W 2398 31W 2479 49 W 2559 85 W 2639 25 W 2720 97 E 280I 94 N 0 26 W 41 N 0 24 W 93 N 0 21 W 50 N 0 17 W 44 N 0 14 W 71 N 0 11 W 48 N 0 8 W 43 N 0 2 W 17 N 0 4 E 5000 O0 3693 45 3625.45 53 37 N 2 8 E 2879 78 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 3752 O0 3812 O0 3871 O0 3930 O0 3988 O0 4046 O0 4104 O0 4162 O0 4219 87 3684.87 53 30 N I 42 E 2960 35 3744.35 53 31 N I 31 E 3040 61 3803.61 53 49 N I 16 E 3121 35 3862.35 54 27 N 2 18 E 3202 33 3920.33 54 35 N 3 22 E 3283 45 3978.45 54 24 N 3 12 E 3364 62 4036.62 54 29 N 3 8 E 3446 49 4094.49 54 55 N 5 37 E 3527 97 4151.97 54 44 N 5 29 E 3609 21 59 14 06 51 88 21 71 37 0 O1 2881 59 N O0 2961 O0 3042 O0 3122 O0 32O3 O1 3285 O1 3366 O1 3447 01 3528 01 3610 6 27 E 2881 60 N 0 7 E 98 N 8 33 N 11 86 N 13 76 N 15 11N 19 35 N 24 57 N 28 91N 34 33 N 42 95 E 2961 18 E 3042 15 E 3122 23 E 3203 67 E 3285 29 E 3366 80 E 3447 62 E 3529 76 E 3610 99 N 0 10 E 36 N 0 13 E 89 N 0 14 E 80 N 0 16 E 17 N 0 21E 44 N 0 25 E 69 N 0 29 E 08 N 0 34 E 58 N 0 41E 6000 O0 4278 06 4210.06 54 18 N 4 44 E 3690 67 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4336 O0 4395 O0 4454 O0 4512 O0 4569 O0 4625 O0 4680 O0 4736 O0 4791 61 4268.61 54 4 N 4 14 E 3771 43 4327.43 53 55 N 3 50 E 3852 16 4386.16 54 10 N 3 39 E 3933 68 4444 68 54 23 N 3 16 E 4014 46 4501 46 56 5 N 2 29 E 4096 10 4557 10 56 9 N 2 15 E 4179 72 4612 72 '56 14 N 2 17 E 4262 14 4668 14 56 19 N 3 13 E 4346 89 4723 89 55 55 N 3 8 E 4429 66 5O 41 47 77 87 97 2O 2O 0 O1 3691 41 N 49 96 E 3691 75 N 0 47 E O1 3772 O1 3852 O0 3933 O0 4014 O1 4096 O1 4179 O1 4262 O1 4346 O1 4428 22 N 56 90 N 62 67 N 67 60 N 72 81N 76 83 N 79 88 N 82 O0 N 87 89 N 91 33 E 3772 02 E 3853 25 E 3934 21E 4015 19 E 4097 66 E 4180 70 E 4263 07 E 4346 68 E 4429 64 N 0 51 E 40 N 0 55 E 24 N 0 59 E 25 N 1 2 E 52 N 1 4 E 59 N 1 6 E 68 N 1 7 E 88 N 1 9 E 84 N 1 11E 7000.00 4847.74 4779.74 56 10 N 2 44 E 4512 15 7100.00 4903.33 4835.33 56 11 N 2 30 E 4595 26 7200.00 4958.96 4890.96 56 16 N 2 24 E 4678 36 7300.00 5014.30 4946.30 56 30 N 2 11E 4761 65 7400.00 5069 50 5001.50 55 48 N 2 9 E 4845 03 7500.00 5126 42 5058.42 55 14 N 2 21E 4927 26 7600.00 5183 16 5115.16 55 34 N 1 57 E 5009.60 7700.00 5239 49 5171.49 55 48 N 1 29 E 5092.22 7800.00 5295 81 5227.81 55 16 N 1 56 E 5174.85 7900.00 5353 86 5285.86 54 16 N 2 50 E 5256.27 0 O0 4511 74 N 95 94 E 4512 76 N 1 13 E O0 4594 O0 4677 O0 4761 O1 4844 O1 4926 O1 5008 O1 5091 O1 5173 O1 5255 77 N 99 75 E 4595 79 N 103 30 E 4678 02 N 106 63 E 4762 34 N 109 68 E 4845 49 N 113 13 E 4927 78 N 116 24 E 5010 37 N 118.71 E 5092 97 N 120.88 E 5175 85 N 1 15 E 93 N 1 16 E 21 N 1 17 E 58 N 1 18 E 79 N 1 19 E 13 N 1 20 E 75 N 1 20 E 38 N 1 20 E 30 N 124.78 E 5256.78 N 1 22 E COMPUTATION DATE: IT-FEB-94 PAGE 3 ARCO ALASKA, INC. 3M-26 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 5412 81 5344.81 53 39 N 2 0 E 5337.04 8100.00 5472 8200.00 5532 8300 O0 5593 8400 O0 5654 8500 O0 5717 8600 O0 5780 8700 O0 5844 8800 O0 5911 8900 O0 5980 17 5404.17 53 32 N 1 44 E 5417 51 02 5464,02 52 23 N 2 30 E 5497 62 31 5525.31 52 11 N 2 45 E 5576 63 72 5586.72 51 49 N 3 22 E 5655 55 37 5649.37 50 55 N 4 9 E 5733 92 5712.92 50 18 N 3 27 E 5810 97 5776.97 50 2 N 2 45 E 5887 57 5843.57 46 39 N 3 16 E 5961 86 5912.86 44 50 N 3 45 E 6034 45 63 4O 96 O5 0 O1 5336 O0 N 128 23 E 5337.54 N I 23 E O1 5416 O1 5496 O1 5575 O1 5654 O1 5731 O1 5809 O1 5885 O1 5960 02 6032 43 N 130 49 N 133 42 N 137 24 N 141 99 N 146 03 N 151 70 N 156 17 N 159 15 N 164 88 E 5418 01 N 1 23 E 55 E 5498 32 E 5577 21E 5656 73 E 5733 93 E 5811 05 E 5887 89 E 5962 05 E 6034 12 N I 24 E 11 N 1 25 E O1 N I 26 E 87 N 1 28 E O1 N 1 30 E 77 N 1 31E 32 N I 32 E 38 N I 33 E 9000.00 6053 28 5985.28 42 21 N 5 53 E 6102.91 9100.00 6128 49 6060.49 40 15 N 6.47 E 6168.62 9200.00 6204 97 6136.97 40 21 N 7 51 E 6232.82 9300.00 6280 89 6212.89 40 50 N 11 32 E 6297.31 9400.00 6357 42 6289.42 38 51 N 12 23 E 6360.74 9500.00 6435 77 6367.77 38 24 N 12 51E 6421.86 9600.00 6514 14 6446.14 38 24 N 12 51 E 6482.90 9625.00 6533 73 6465.73 38 24 N 12 51 E 6498.16 0 03 6100 85 N 169,74 E 6103 21 N 1 36 E 0 02 6166 33 N 177.14 E 6168 87 N 1 39 E 0 02 6230 27 N 185.06 E 6233 02 N 1 42 E 0 02 6294 39 N 196.08 E 6297 45 N 1 47 E 0 02 6357 37 N 209.38 E 6360 81 N 1 53 E 0 O0 6418 O1 N 223.16 E 6421 89 N 1 59 E 0 O0 6478 57 N 236.98 E 6482 90 N 2 6 E 0 O0 6493 71N 240.43 E 6498 16 N 2 7 E COMPUTATION DATE: 17-FEB-94 PAGE 4 ARCO ALASKA, INC. 3M-26 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN IO00 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/1OO FEET FEET FEET DEG MIN 000 O OO 1000 2000 3000 4000 5000 6000 7000 8000 9000 O0 990.07 922.07 18 19 N 14 I W 64 O0 1885.98 1817.98 36 42 N 1 18 E 496 O0 2527.98 2459.98 56 13 N i 26 E 1255 O0 3101.21 3033.21 52 59 N 0 38 E 2074 O0 3693.45 3625.45 53 37 N 2 8 E 2879 O0 4278.06 4210.06 54 18 N 4 44 E 3690 O0 4847.74 4779.74 56 10 N 2 44 E 4512 O0 5412.81 5344.81 53 39 N 2 0 E 5337 O0 6053.28 5985.28 42 21 N 5 53 E 6102 0.00 -68.00 0 0 N 0 0 E 0 O0 38 87 15 26 78 67 15 04 91 04 66.04 N 42 03 499.34 N 56 O0 1257.34 N 34 01 2076.39 N 17 01 2881.59 N 6 01 3691.41 N 49 O0 4511.74 N 95 O1 5336.00 N 128 03 6100.85 N 169 98 W 78 11W 502 32 W 1257 19 W 2076 27 E 2881 96 E 3691 94 E 4512 23 E 5337 74 E 6103 0.00 N 0 O0 E 0 O0 N 0 0 E 8O N 33 3 W 48 N 6 25 W 81 N 1 34 W 46 N 0 28 W 60 N 0 7 E 75 N 0 47 E 76 N I 13 E 54 N 1 23 E 21 N I 36 E 9625.00 6533.73 6465.73 38 24 N 12 51 E 6498.16 0.00 6493.71 N 240.43 E 6498.16 N 2 7 E ARCO ALASKA, INC. 3M-26 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE' 17-FEB-94 PAGE 5 DATE OF SURVEY' 30-JAN-1994 KELLY BUSHING ELEVATION' 68.00 ET INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH I'RUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG BIN DEG MIN 0 0 N 0 0 E 0 48 S 38 3 W I 0 S 30 14 W 0 57 S 35 56 W I 3 S 40 58 W I 4 S 39 21W I 13 N 75 19 W 6 31 N 38 15 W O0 11 5 N 34 4 W O0 15 13 N 25 18 W ENGINEER' FORMICA 0 O0 68 05 168 07 268 08 368 09 468 11 568 13 668 41 769 57 872 32 0 O0 68 O0 168 O0 268 O0 368 O0 468 O0 568 O0 668 O0 768 O0 868 O0 -68 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 70O 80O N 15 6 W N 11 4 W N 8 23 W N 4 20 W N 0 50 W N 0 55 E N 1 7 E N 047 E N 0 46 E N I 17 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 976 77 1082 1188 1294 1403 1514 1627 1741 1856 1977 900.00 18 0 O0 1000.00 18 47 O0 1100.00 19 32 O0 1200.00 21 42 O0 1300.00 24 34 O0 1400.00 27 14 O0 1500.00 27 51 O0 1600.00 29 1 O0 1700.00 31 57 O0 1800.00 36 5 968 O0 24 1068 03 1168 79 1268 46 1368 72 1468 78 1568 35 1668 96 1768 66 1868 2104 52 1968 O0 1900 O0 39 53 O0 43 45 O0 47 28 O0 53 19 O0 55 53 O0 56 9 O0 56 12 O0 55 45 O0 55 24 O0 55 0 0. O0 -0.20 -1.64 -3.11 -4.49 -5.95 -7.09 L2.29 9.75 29.53 2238 2381 2538 2713 2892 3072 3250 3427 3602 91 2068 78 2168 52 2268 33 2368 30 2468 02 2568 92 2668 86 2768 93 2868 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 3775 44 2968.00 2900 O0 54 8 57 46 89 79 123 55 160 49 202 86 251 56 304 31 358 12 416 09 483 62 N 1 26 E 561 63 N 2 11E 651 37 N 2 30 E 753 36 N 1 41E 873 96 N 1 2 E 1017 29 N 1 29 E 1165 71 N 1 26 E 1315 02 N 1 16 E 1463 35 N 1 28 E 1609 31 N 1 11E 1752.99 N 1 7 E 1893.53 N 0 43 e 2029 97 3944 4110 4278 4450 4619 4787 4957 5125 5293 63 3068.00 3000 03 3158 O0 3100 40 3268 O0 3200 98 3368 O0 3300 08 3468 O0 3400 56 3568 O0 3500 10 3668 O0 3600 45 3768 O0 3700 90 3868 N 0 25 E 2161 N 1 17 E 2297 N 1 18 E 2437 N 1 33 E 2572 N 3 23 E 2708 N 2 18 E 2845 N 1 38 E 2980 N 1 17 E 3116 O0 53 18 O0 52 19 O0 54 55 O0 54 1 O0 52 48 O0 54 20 O0 53 37 O0 53 30 O0 3800.00 53 48 67 04 68 78 34 24 66 21 0 O0 0 O3 0 O0 0 O0 0 O0 0 O0 0 O1 0 05 0 05 0 05 0 O0 N 0 19 S 1 60 S 3 04 S 4 37 S 5 79 S 6 89 S 1 90 S 10 48 N 30 72 N 0 O0 E 0 18 W 1 12 W 2 O1 W 3 10 W 4 29 W 5 53 W 10 41 W 19 17 W 31 05 W 0 O0 N 0 0 E 0 1 3 5 7 8 10 21 43 27 S 43 35 W 95 S 35 3 W 64 S 33 27 W 36 S 35 22 W 20 S 36 32 W 83 S 38 44 W 58 S 79 39 W 85 N 61 2O W 68 N 45 18 W 0 04 0 03 0 O2 0 O2 0 O2 0 O1 0 O2 0 O1 0 O1 0 03 59.05 n 91.69 N 125.69 N 162.82 N 205.29 N 254.02 N 306.76 N 360.57 N 418.56 N 486.10 N 41 16 W 48 71W 103 54 55 W 137 58 75 W 173 60 51W 214 60 28 W 261 59 28 W 312 58 36 W 365 57 61W 422 56.41W 489 71 98 N 34 52 W 83 N 27 59 W 02 N 23 28 W 10 N 19 51W 02 N 16 25 W 07 N 13 21W 43 N 10 56 W 27 N 9 12 W 51 n 7 50 W 36 N 6 37 W 0 03 0 O3 0 03 0 O3 0 O2 0 O1 0 O0 0 O1 0 O0 0 O0 564 09 N 653 77 N 755 69 N 876 20 N 1019 52 N 1167 92 N 1317 19 N 1465 50 N 1611 43 N 1755 09 N 54.72 W 566 74 N 5 32 W 51.41W 655 47.44 W 757 42 75 W 877 39 88 W 1020 36 61W 1168 32 82 W 1317 29 44 W 1465 25 79 W 1611 22 41W 1755 79 N 4 30 W 17 N 3 36 W 24 N 2 48 W 30 N 2 14 W 49 N 1 48 W 60 N 1 26 W 79 N 1 9 W 63 N 0 55 W 23 N 0 44 W 0 O0 0 O1 0 O1 0 O1 0 O1 00l 0 O1 0 O1 0 O0 0 O0 1895 63 N 2032 09 N 2163 82 N 2299 22 N 2439 84 N 2574 92 N 2710 34 N 2847 07 N 2982 42 N 3117 94 N 19 95 W 1895 73 N 0 36 W 17 16 14 11 8 1 4 9 13 70 W 2032 41W 2163 43 W 2299 21W 2439 10 W 2574 84 W 2710 94 E 2847 55 E 2982 04 E 3117 16 N 0 30 W 88 N 0 26 W 27 N 0 22 W 86 N 0 16 W 93 N 0 11W 34 N 0 2 W 08 N 0 6 E 44 N 0 11 E 96 N 0 14 E COMPUTATION DATE: 17-FEB-94 PAGE 6 ARCO ALASKA, INC. 3M-26 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 5464 91 3968 O0 3900 O0 54 36 N 3 22 E 3254 92 5637 5809 5982 6153 6323 6497 6677 6857 7036 03 4068 60 4168 75 4268 43 4368 64 4468 38 4568 12 4668 27 4768 43 4868 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 54 26 N 3 10 E 3394 O0 54 58 N 5 47 E 3535 O0 54 21 N 4 50 E 3676 O0 53 58 N 4 I E 3814 O0 54 10 N 3 37 E 3952 O0 56 5 N 2 29 E 4094 O0 56 13 N 1 58 E 4243 O0 56 5 N 3 11 E 4393 O0 56 15 N 2 40 E 4542 0 01 3256.56 N 17 99 E 3256 61 N 0 19 E 98 0 55 0 67 0 87 0 57 0 60 0 95 0 78 0 42 0 01 3396.42 N 25 01 3536.73 N 35 O1 3677 44 N 48 O1 3815 34 N 59 O0 3952 79 N 68 01 4094 64 N 76 O1 4243 88 N 81 O1 4393 52 N 89 O0 4541 98 N 97 96 E 3396 38 E 3536 79 E 3677 44 E 3815 47 E 3953 09 E 4095 99 E 4244 73 E 4394 36 E 4543 52 N 0 26 E 90 N 0 34 E 77 N 0 46 E 81 N 0 54 E 39 N I 0 E 35 N I 4 E 67 N 1 6 E 44 N I 10 E O2 N 1 14 E 7216 31 4968 O0 4900.00 66 20 N 2 22 E 4691 93 7397 7573 7750 7924 8092 8258 8421 8579 8735 30 5068 21 5168 79 5268 16 5368 98 5468 72 5568 40 5668 76 5768 43 5868 O0 5000.00 55 51 N 2 8 E 4842 O0 5100.00 55 30 N 2 5 E 4987 O0 5200.00 55 51 N 1 22 E 5134 O0 5300.00 54 3 N 2 43 E 5275 O0 5400.00 53 31 N I 44 E 5411 O0 5500.00 52 11 N 2 47 E 5544 O0 5600.00 51 29 N 3 59 E 5672 O0 5700.00 50 22 N 3 38 E 5795 O0 5800.00 48 53 N 2 47 E 5914 80 52 25 85 87 02 32 05 33 0 O0 4691 35 N 103 86 E 4692 50 N 1 16 E O0 4842 O1 4986 O0 5133 O1 5274 O1 5410 O1 5542 O1 5670 O1 5793 01 5912 11N 109 71N 115 39 N 119 86 N 125 78 N 130 84 N 135 99 N 142 48 N 150 60 N 157 60 E 4843 46 E 4988 74 E 5134 73 E 5276 71E 5412 75 E,5544 28 E 5672 96 E 5795 35 E 5914 35 N 1 18 E 04 N 1 20 E 78 n 1 2O E 36 N 1 22 E 36 N 1 23 E 51 N 1 24 E 77 N 1 26 E 44 N 1 30 E 69 N 1 31E 8881 76 5968.00 5900 O0 45 30 N 3 25 E 6021 12 9019 86 6068.00 6000 O0 41 45 N 6 19 E 6116 22 9151 62 6168.00 6100 O0 40 0 N 6 52 E 6201 73 9282 97 6268.00 6200 O0 40 47 N 11 6 E 6286 32 9413 56 6368.00 6300 O0 38 34 N 12 43 E 6369 09 9541 13 6468.00 6400 O0 38 24 N 12 51 E 6446 96 9625 O0 6533.73 6465 73 38 24 N 12 51 E 6498 16 0.02 6019 25 N 163 23 E 6021 46 N 1 33 E 0.03 6114 12 N 171 14 E 6116 51 N 1 36 E 0.02 6199 31 N 181 10 E 6201 96 N 1 40 E 0.02 6283 48 N 193 89 E 6286 47 N 1 46 E 0.02 6365 65 N 211 22 E 6369 15 N 1 54 E 0.00 6442 92 N 228 84 E 6446 98 N 2 2 E 0.00 6493 71 N 240 43 E 6498 16 N 2 7 E COMPUTATION DATE: 17-FEB-94 PAGE 7 ArCO ALASKA, INC. 3M-26 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK A GCT LAST READING PBTD 7" CASING TD DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 939' FNL & 1563' FEL, SEC25 T13N RSE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4882 O0 9311 O0 9325 O0 9325 O0 9392 O0 9425 O0 9522 O0 9610 O0 9625 O0 3623 42 6289 22 6299 83 6299 83 6351 20 6376 95 6453 01 6521 98 6533 73 3555 42 6221 22 6231 83 6231 83 6283 2O 6308 95 6385 O1 6453 98 6465 73 2786 70 N 6301 44 N 6310 38 N 6310 38 N 6352 46 N 6372 59 N 6431 33 N 6484 63 N 6493 71N 2 30 E 197 52 E 199 39 E 199 39 E 208 31E 212 80 E 226 20 E 238 36 E 240 43 E COMPUTATION DATE: 17-FEB-94 PAGE 8 ARCO ALASKA, INC. 3M-26 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK a BASE KUPARUK a TD DATE OF SURVEY: 30-JAN-1994 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: FORMICA ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION = 939' FNL A 1563' FEL, SEC25 T13N R8E MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 9311.00 6289.22 6221.22 6301.44 N 197.52 E 9325.00 6299.83 6231.83 6310.38 N 199.39 E 9325.00 6299.83 6231.83 6310.38 N 199.39 E 9392.00 6351.20 6283.20 6352.46 N 208.31 E 9625.00 6533.73 6465.73 6493.71 N 240.43 E FINAL WELL LOCATION AT ID: TRUE SUB-SEA MEASURED VERTICAL VERTICAL' DEPTH DEPTH DEPTH 9625.00 6533.73 6465.73 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 6498.16 N 2 7 E COMPANY ARCO ALASKA, INC. FIELD 3M-26 WELL KUPARUK RIVER COUNTRY USA RUN DATE LOGGED 30-JAN- 1994 REFERENCE 94043 All interpretations are opinions based on inferences from elecl]'ical or other measurements and we cannot and dn guarantee the accuracy or correctness of any interpretations, and we shall not except in the case of gross or negligence on our part, be liable or responsible for any loss, costs, dame~es or expenses incurred or sustained by anyone res~lti.ng from any interpretation made by a,r~ of our officers, age. n~ or employees. Thee ,se i ,nt~;rpretation9 Rte aJso subject to our General Terms aha L, ondil~ons as set out in our currern price ~:~cneau~e. 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' :: :::: :::: :::: ..:: .::: :::: :.:. :::: ::.: .:. .: ..~.,~.~i..i..~.--i ...... i...i..,i-.i ...... i...i.-.~..-; .... i.-.i.--~...i ..... ~.-i..-i--.i .... i.--~...i-.; ...... i-,i-i..J .... ~.~.;..; I :.: .... :: :::: :::: :::: :::: :.:: :.:: ..:: ,.:::.. :.::.:...::.:..: ..... ::..:...:,.:.:..:...:.;...:...;.:...:.:.:..:. :.:...:: ..::. :::: ..: .... : :... ::.. . .......................................... :-i-i!i 'ii"!i---ii"i-'i ..... i---ii---! i'i-'i'-i ..... i--ii--i---i"!--!-i-'i--i-li .... !-i-'i-i ':: -';' ::! .... :~ ' : , ':': :'::::::: :::: :::::::: :::: :::' :::: ::': '::' :!'i':;'!:!"i'i"~:":":":'!":!''(!'"!'i .... i''i"!:'':i::' i"i:: ':i:"i':'::': '!':: .......:' '':' ' I ~i~'~ 'i-i'i"!l'i"i'?! .... !"i'i -i'?'i"i ..... ?..!..!-:.-.i?.i..i..!-.i~..i. !.i..i.:..~:.~ ..: ....... : > 1 ,:-!i :':!-'!i-'i-':"!i ..... :':':'-!-'~h60"!'"!"i"i ';'i:'!-'!i-'i'!i :::':.. :ii!-'~: : ,_ ...... !_. 12O00 20 P~ECTI~h',~ ON VERTICAL PLANE 182.0 - 2,0 ~<3ALED IN VERTICAL DEI=q'HS HORIZ SCALE = 1 2000 IN/FT ARCO Alaska, Inc. Date: March 04, 1994 Transmittal #: 9020 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. return one signed copy of this .transmittal. Please acknowledge receipt and ~¥-~-~ 3M-23 ~'_~-~'~ 3M-26 c~-cu 3M-25A q~5~c1% 3M-24 Receipt Acknowledged: Directional SurveyS"' ~-~c 01-30-94 Directional Survey c~- ~t~a-s 01-30-94 Directional Survey o- ~ t-z. 01-29-94 Directional Survey D ~-iz.q~, 01-30-94 /~~~_~ ~_~_~ Date: DISTRIBUTION: D&M State of Alaska (2 copies) 94045 94043 94042 94044 ARCO Alaska, inc. Date: January 11, 1994 Transmittal #: 9000 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 c"'i'tl .-- OU Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. 3M-25A 3M-26 3M-23 3M-24 3M-26 3M-25A 3M-23 3M-24 '"'Ultrasonic Imager-USIT Cement & Corrosion '/'Ultrasonic imager-USIT Cement & Corrosion ~/Ultrasonic Imager-USIT Cement & Corrosion ,,-'Ultrasonic imager-USIT Cement & Corrosion ,/Cement Bond Log (CBT),," ,,'Cement Bond Log (CBT) · /Cement Bond Log (CBT) ,,'"Cement Bond Log (CBT) 01-29-94 ~,[ 01-29-94 P-,', 01-29-94 01-29-94 ~ Please acknowledge. Receipt Acknowledge: 7~50 Drilling State of Alaska(+sepia) 6900-8785 ~ 7300-12606 5" 10600-12356 12-20-93 ~,~ 7800-9421 5" 12-20-93 ¢,t 6900-8756 _5 12-20-93 P,~ 7300-12577 ~" 12-20-93 ~ 10600-12327 NSK Date: MEMORANDb.. TO: THRU: Blair Wondzell, -~'--~ P. I. Supervisor State (,. Alaska Alaska Oil and Gas Conservation Commission DATE: January 15, 1994 FILE NO: acxkambd.doc FROM: Jerry Herring,-~}~ SUBJECT: Petroleum Inspector B.O.P.E. Test- Parker 245 ARCO, KRU, 3M-26 Kuparuk River Field PTD # 93-193 Thursday, January 13, 1994: I traveled to AAI's Kurparuk 3M pad to witnessed a B.O.P.E. test on Parker 245. The 9-5/8" casing was installed to 4882 feet. The B.O.P.E. Test Report is attached. The test went very smoothly with no failures. The equipment and crew performed well. Summary: The B.O.P.E. test on Parker 245 started at 8:00 AM and lasted for 2-1/2 hours. No failures were encountered. Attachment: acxkambd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: x Workover: Drlg Contractor: PN:{KER Operator: ARCO ALASKA, INC. Well Name: 3M-26 Casing Size: 9-5/8" Set@ Test: Initial X Weekly DATE: 1/1 3/94 Rig No. 245 PTD # 93-193 Rig Ph.# 659-7670 Rep.: JC PYRON Rig Rep.: JC CRISP 4882' Location: Sec. 25 T. 13N R 8E Merd. U Other MISC. INSPECTDNS: FLOOR SAFETY VALVES: Quan. Location Gen.: X Well Sign X Upper Kelly/IBOP 1 Housekeeping: X (Gen) Dri. Rig X Lower Kelly/IBOP 1 Reserve Pit NA Ball Type 1 Inside BOP 1 BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 300/3000 P 1 300/3000 P 1 300/3000 P 1 300/3000 P 1 300/3000 P 1 300/3000 P 2 300/3000 P NA MUD SYSTEM: Visual Alarm Trip Tank X NA Pit Level Indicators X X Flow Indicator X X Gas Detectors X X Test Pressure P/F 300/3000 P 300/3000 300/3000 300/3000 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 1 6 300/3000 P 38 300/3000 P 2 FUNCTION P 1 FUNCTION P ACCUMULATOR SYSTEM: System Pressure 3,000 P Pressure After Closure 1,800 P 200 psi Attained After Closure minutes 25 sec. System Pressure Attained 2 minutes 20 sec. Blind Switch Covers: Master: X Remote: X Nitgn. Btl's: 2300,2300,24'00 2300,2290,2350 Psig. Number of Failures 0 Test Time 2.0 -"~Hours Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 H2S AND COMBUSTIBLE DETECTORS TESTED 12/17/93. FIRE ALARMS WERE TESTED 12/29/93. Distribution: orig-Well File c - Oper./Rig c- Database c- Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: JERRY HERRING FI-O21L (Rev. 2/93) PARKER 245 TEST ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 10, 1994 Phyllis Billingsley ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Ms Billingsley: The Commission is compiling statewide drilling statistics for 1993. Attached is a list of outstanding Permits to Drill issued to your engineering group (permits for which no form 10-407 has been received by this office). Please review this list to determine if any of the wells were drilled in 1993. If so, please note the well name, total measured depth, and class (development, service or exploratory). If any wells were ddlling as of 12/31/93, estimate the depth at 12:00 midnight. We would appreciate your reply by the end of January if possible. Thank you for your cooperation with this project. If i may be of any assistance, please call me at 279-1433. Yours very truly, Robed P Crandall Sr Petr Geologist encl jo/A:RPC:~rlstats .1/04/94 OPERATOR ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA ARCO ALASKA INC ARCO ALASK3% INS ARCO ALASKA INC ARCO ALASKA INS ARCO ALASKA INS ARCO ALASKA INS ARCO ALASKA INC ARCO ALASKA INC ARCO ALASKA ARCO ALASKA ARCO ALASKA INC ARCO ALASKA ARCO ALASKa% ARCO ALASKA ALASKA WELLS BY ARCO PER~4IT 93-0166-0 93-0152-0 93-0151-0 93-01~3-0 93~0144-0 93-0188-0 93-0179-0 93-0169-0 93-0104-0 93-0189-0 93-0174-0 93-0175-0 93-0187-0 93-0195-0 93-0196-0 93-0193-0 92-0040-0 WELL NAME KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIY UNIT KUPARUK RIV I/NIT KUPARUK RIV ~-NIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UNIT KUPARUK RIV UI~IT 2A-18 2A-19 2A-20 2A-22 2A-24 2E-04 2~-05 2E-06 2E-07 2~-08 2E-17 2E-18 3M-23 3M-24 3M-25 3M-26 3R-16 PAGE MEMORANDb,,'I State (,. Alaska Alaska Oil and Gas Conservation Commission TO: David Johnsto~.~, Chairma~ DATE: 1-10-1994 THRU: Blair Wondzell, FiLE NO: P. I. Supervisor EC9JAJBD.DOC FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector Diverter inspection and function test Parker rig #245 Arco well fl 3M-26 Kuparuk River Field PTD # 93-t4¢ ~/°l.] Monday, January 10, 1994: I traveled to Arco's 3-M pad in the Kuparuk River field to witness the function test and inspect the diverter system on Parker rig # 245 drilling well # 3M-26. The diverter system was well laid out and functioned properly, closure time was 24 seconds. Down wind diversion is accomplished thru a alternate leg. The recharge time of two minutes and forty seconds was average for this size assembly and accumulator set. Summary: I witnessed the function test of the diverter system on Parker rig # 245 drilling Arco's well # 3M-26 in the Kuparuk river field. Attachment: EC9JAJBD.XLS STATE OF ALASKA ~--- ALASKA (.,,,_ AND GAS CONSERVATION COM~..,SION Diverter Systems Inspection Report Operation: Development Drlg Contractor: PARKER DRLG. Rig No. 245 PTD # Operator: ARCO Oper. Rep.: Well Name: 3M-26 Rig Rep.: Location: Sec. 25 T. 13N R. 8E Merdian Umiat Date: 1/10/94 X Exploratory: 93 - 144 Rig Ph. # 659 - 7670 Donnie Lutrick JOHN CRISP MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: OK Systems Pressure: 3000 psig Housekeeping: OK (Gen.) Drlg. Rig: OK Pressure After Closure: 1625 psig Reserve Pit: N / A Flare Pit: N lA 200 psi Attained After Closure: min. 32 sec. Systems Pressure Attained: 2 min. 40 sec. DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: 7 @ 2300 Diverter Size: 20 in. psig Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES MUD SYSTEM INSPECTION: Light Alarm Vent Line(s) Size: 10 in. Trip Tank: YES YES Vent Line(s) Length: 100' / 200' ft. Mud Pits: YES YES Line(s) Bifurcated: NO Flow Monitor: YES YES Line(s) Down Wind: YES Line(s) Anchored: YES GAS DETECTORS: Light Alarm Turns Targeted / Long Radius: TARGETED Methane YES YES Hydrogen Sulfide: YES YES __ -- "~ 200' ~ -,~ ~ ~ 100' ~ ~on Gompliance Items 0 8opair Items Withi 0 ~ay (s) ~n~ contact the Inspoctor ~ ~5¢-3~07 Bomarks: Distribution orig. - Well File c- Oper/Rep c- Database c -F~_rl~l~ ~'i~.e7/9 3 c- Inspector AOGCC REP.: ECXJAJBD.XLS OPERATOR REP.: Louis R Grimaldi Donnie Lutrick u/..:-i_! Lt ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 7, 1994 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3M-26 ARCO Alaska, Inc. Permit No. 93-193 Sur Loc 939'FNL, 1563'FEL, Sec. 25, T13N, RSE, UM Btmhole Loc 276'FSL, 1344'FEL, Sec. 13, T13N, R8E, UM Dear McBride: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated December 22, 1993 are in effect for this revision. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA AI_~SKA OIL AND GAS CONSERVATION COMMISsiON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill E~] lb Type of Well Exploratory E] Stratigraphic [] Development Oil X Test Re-Entry r'-] Deepen I"-I service r-] Development Gas r-I Single Zone X Multiple Zone [] 2_ Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 68', Pad 27' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25522, ALK 2558 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 939' FNL, 1563' FEL, SEC. 25, T13N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 103' FSL, 1354' FEL, Sec. 13, T13N, R8E, UM 3M-26 #U-630610 At total depth 9. Approximate spud date Amount 276' FSL, 1344' FEL, Sec. 13, T13N, R8E, UM 1/9/94 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3 M- 1 4 9649' MD 1344' @ TD feet 12.0' @ 400' MD feet 2560 6516' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 600 feet Maximum hole angle 54.5° Maximum surface 2142 psig At total depth (TVD) 3272 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantit), of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 36.0# J-55 BTC 4823' 41' 41' 4864' 3618' 620 Sx Arcticset III & HF-ERW 510 Sx Class G 8.5" 7" 26.0# L-80 BTCMOF 9608' 41' 41' 9649' 6516' 140SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vedical depth Structural i~r~flam~it~irate ~_~ ~ C ."~ I V ~L ~) Production Liner Perforation depth: measured true vertical * ~,-¢~,~* 0il & 6~$ 00tlS, OoBli~issiop, 20. Attachments Filing fee X Property plat [] BOP Sketch X AI]]6'~t§~Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that th,~ foregoing is true and correct to the best of my knowledge Signed,~¢~~ ~~/ j~¢' ~'//¢t Title Area Drilling Engineer Date b//e ~ Commission Use Only I /~-~ '-~C~¢ -~-'~"~ See cover letter fOrrequirements Permit Num r APl number Approval date '_i ' ~; -'/' P..~ 50- .-:_~¢.~ ~ ~ ~ ~ ~;~¢.i~-:~,/' "other Conditions of approval Samples required Fl Yes [~ No Mud Icg required II I Yes [~ No Hydrogen sulfide [] Yes [] No Directional survey required [] Yes ~ No measures Required working pressure for BOPE ~ 2M J~ 3M BI 5M ~ 10M ~ 15M Other: ORIGINAL SIGNED BY by order of Approved by RUSSELL A RCltlR!/~qq Commissioner the commission Date /'¢"' Form 10-401 Rev. 7-24-89 Submil in triplicate KRU 3M-26 Permit to Drill As a result of the dry hole drilled at Kuparuk on 1/5/94 (Well 3M-25), the original location for KRU 3M-26 will not be drilled due to the proximity of the well to the dry hole. The permit number for the original location of 3M-26 is 93- 193 (approved 12/22/93). The attached permit to drill is for the revised location of 3M-26. Side track operations for KRU Well 3M-25 are currently in progress. KRU Well 3M-26 will be drilled after Well 3M-25 is drilled to TD and 7" casing is run and cemented. The estimated timing for spudding 3M-26 is Sunday, 1/9/94. Approval of this Permit to Drill is requested before this time so as not to incur significant stand by rig charges. If you have any questions or comments regarding the attached permit to drill or the overall development program for Kuparuk Drill Site 3M, please contact Wayne McBride at 263-4962 or the Drilling Engineer working on the project (Steve Bradley) at 263-4243. Thank you for your expedient response to this request. RECEIVED ,.IAN -"-( ,.,.,,.:.:;t.;a Oil & Gas Cons. Commission Anchorage · , · · · · · · . 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3M-26 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4864')according to directional plan. Run and cement 9-5/8" casing. No cement bond logs to be run in 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (9649') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED ,iAi;! "'7 · , I ,J ,J '!' ;...,..-: :;i..:~ 0ii & 6~s Cor~s. Corr~mission Anchorage DRILLING FLUID PROGRAM Well 3M-26 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud ko 9-5/8" surface casing 9.0-10.5 15-25 15-35 5O-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.1 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2142 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3M-26 is 3M-14. As designed, the minimum distance between the two wells would be 12,0' @ 400' MD, Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ALASKA, Ina. Created by ' jones For: S BRADLEY iDate plotted ' 6-Jan-94 iPIot Reference is 26(F) Version #4. Coordinates ore in feet reference slot #26. ;True Vertical Depths ore reference wellhead. Baker Hughes INTEQ 350 _] 04 ~o! RKB ELEVATION: KOP TVD=600 TMD=600 DEP=O 3.00 Structure : Pad 3M Field : Kuparuk River Unit Well : 26(F) Location : North Slope, Alaska ..... East --> 700 3500 350 700 I I I I I I I I I 700 1050 1750 2800 S1504 13(1')'8~°4 ~ 4200_ 5950 66501 N 2.16 DEG E 6327' (TO TARGET) **,PLANE OF PROPOSAL**, 8.61 BEGIN TURN TO TARGETTVD=866 TMD=867 DEP=11 I'ID LOCATION: I 276' FSL, 1344' FEL SEC. 13, T13N. RSE JTARGET LOCATION: 103' FSL. 1354' FEL SEC. 15. T13N. RSE C TARGET TVD=6310 TMD=g3Bo DEP=6327 NORTH 6322 EAST 239 13.16 1~.55 3 DEG / I00' DOGLEG 24.21 50.01 B/ PERMAFROST TVD=1623 TMD=1667 DEP=241 ,,, \ 35.8s %, 41.75 '~%, 47.67 ~ 53.60 EOC TVD=2265 TMD=2533 DEP=812 ,x~NU SNDS TVD=2343 TMD=2668 DEP=922 T/ W SAK SND5 TVD=3018 TMD=3831 DEP=1868 B/ w SAK SNDS TVD=3418 TMD=4520 DEP=2429 KI10 '['¢D=3668 TMD=4950 DEP=2780 /8 CSG PT TVD=3618 TMD=4864 DEP=2710 MAXIMUM ANGLE "-. 54.5 DEG '""-'- '-... TVD=5368 TMD=7878 DEP=5163 K-5 SURFACE LOCATION: 959' FNL. 1593' SEC. 25. T13N, RSE BEGIN ANGLE DROP TVD=5819 TMD=8655 DEP=5795 ~--.~ 54.00 TARGET ANGLE 5O00 '% 46.00 40 DEG TARGET - T/ ZONE C (EOD) TVD=6310 .Tl~lD=9380 42.00 T/ ZONE A 1VD=63~8 TMD=9390 DEP=6333' B/ KUP SNDS 1VD=6363 TMD=9449 DEP=6371 TD / 7" CSG PT TVD=8516 TMD=9649 DEP=6500 i i i i i ! i i i i i i i i i I i i i i i i i i i i i i i i i i i I i i i i i i 350 0 350 700 1050 1400 1750 21 ~ 245-5 2800 3150 35(Y5 3850 4200 4550 4~00 5250 5600 5950 6300 6650 Scale 1· 175.00 Vertical Section on 2.16 azimuth with reference 0.00 N, 0.00 E from slot #26 1050 7000 665O . .6300 - _5950 420O ~850 _ _.0O - _3150 - - _2450 1400 _1050 7OO o ~j Casing Design / Cement Calculations 7-Jan-94 Well Number: o Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 3M-26 4,864 ft 3,618 ft 9,649 ft 6,516 ft 3,831 ft 9,380 ft 6,310 ft 3200 psi ** See Page 4 For Casing Choices 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5'0.052)-0.11}*TVDshoe Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =1 3,618 ft 2,142 psiJ 3,200.0 ppg 6,310 ft 100 psi 10.1 PPgl Surface lead: Top West Sak, TMD = 3,831 ft Design lead bottom 500 ft above the Top of West Sak = 3,331 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,043 cf Excess factor = 15% Cement volume-required = 1,200 cf Yield for Permafrost Cmt = 1.94 Cement volume required =[ 620 sxJ Surface tail: TMD shoe = 4,864 ft (surface TD - 500' above West Sak) * (Annulus area) = 480 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 515 cf Excess factor = 15% Cement volume required = 592 cf Yield for Class G cmt = 1.15 Cement volume required =l 510 sx Casing Design / Cement Calculations 7-Jan-94 Production tail: TMD = 9,649 fi Top of Target, TMD = 9,380 fi Want TOC 500' above top of target = 8,880 fi Annulus area (9" Hole) = 0.1745 (TD-TOC)*Annulus area = 134 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 151 cf Excess factor = 15% Cement volume required = 174 cf Yield for Class G cmt = 1.23 Cement volume required =1 140 sx TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy - Weight of displaced mud Length Casing Wt (lb/fi) Dead Wt in Air Buoyancy = Tension (Pipe Body) Design Factor 564000 lb 4,864 fi 36.OO lb/fi 1751 O4.0 lb 26057.1 lb 149046.9 lb Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 639000 lb 4,864 fi 36.00 Ib/ft 175104.0 lb 26057.1 lb 149046.9 lb Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air- Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 604000 lb 9,649 fi 26.00 lb/fi 250874.0 lb 38053.8 lb 212820.2 lb Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = · 667000 lb 9,649 ft 26.00 Ib/ft 250874.0 lb 38053.8 lb 212820.2 lb 3.11 Casing Design/Cement Calculations BURST - Minimum Desicjn Factor = 1.1 Surface Casing: Burst = Maximum surface pressure' Casing Rated For: Max Shut-in Pres = Design Factor =1 Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 7-Jan-94 3520 psi 2141.9 psi 1.61 7240 psi 6908 psi 3016 psi 3892 psi 1.9] 2020 psi 0.523 Ib/ft 956 psi 2.11 5410 psi 0.523 Ib/ft 3408 psi 1 Casing Design / Cement Calculations 7-Jan-94 Surface Casing Choices OD ID I b/ft Grade I 9.625 8.681 47 L-80 2 9.625 8.835 40 L-80 3 9.625 8.921 36 J-55 4 10.750 9.950 45.5 J-55 Metal X-Section Jt Strength Body Strength Collapse Burst 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade I 7.000 6.276 26 L-80 2 7.000 6.276 26 J-55 Metal X-Section Jt Strength 7.5491 sq. in. 667000 lb 7.5491 sq. in. 490000 lb Body Strength 604000 lb 415000 lb Collapse 5410 psi 4320 psi Burst 7240 psi 4980 psi ~'{UPARUK RIVER UNf~;~::: ............ :'"' .... 20" DIVERTER SCHEMATIC J 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLL~ED~T-Q'AGY~-IIEVE EI~,NWIND DIVERSION i~ ~ [~ !~ ~ ~! 6. 20" - 2000 PSI ANNULAR PREVENTER I/~:~i ...'i/ '-;'.,t :,;..~., , !'~ ~. EDF3/10/92 1 7 6 I 3 13 518" 5000 i SI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAJNING PRESSURE. BOP STACK TE~T 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL Ah~ CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BO'FrOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULLOUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-.5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5¢8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE~ (1) Fee ,.,,~' ( 2 ) Loc [10 S 13] "~'14 thru 22 [23 thru 2 (5) BOPE (6) Other ,.X.__ [29 thru 31] (7) Contact /¥ ~ .... ,,.'...~,, E32] (8) Addl . 5. 6. 7. 8. . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. Company YES Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... .~C_ Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ngrnber appropriate .......................................... Does well have a unique name & ntrnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor $ surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wel lbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to :~ ps ig ..... Does choke manifold comply w/API RP-53 (May 84) ...... ] ............... Is presence of H2S gas probable ...................................... FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. 0 .--I "rz ~-~0 rev 6/93 jo/6.011 INITIAL GEOL I UNIT ON/OFF POOL CLASS STATUS AREAI ~ SHORE Additional remarks' .×' Exp~_~ Red rtl 1 Inj Rev MERIDIAN' SM WELL TYPE' ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 January 4, 1994 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3M-26 ARCO Alaska, Inc. Permit No. 93-193 Sur Loc: 938.5'FNL, 1593'FEL, Sec. 25, T13N, RSE, UM Btmhole Loc 2403'FNL, 257'FWL, Sec. 24, T13N, R8E, UM Dear Mr. McBride: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated December 22, 1993 are in effect for this revision. · David W. ' BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA AL,-,6~ OIL AND GAS CONSERVATION COMM~oiON PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic [] Development Oil X Teal Re-Entry [~ Deepen r~ Service [~] Development Gas [~] Single Zone X Multiple Zone ~-1 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 68', Pad 27' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25522, ALK 2558 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 938.5' FNL, 1593' FEL, SEC. 25, T13N, ReE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2534' FNL, 375' FWL, Sec. 24, T13N, ReE, UM 3M-26 #U-630610 At total depth 9. Approximate spud date Amount 2403' FNL, 257' FWL, Sec. 24, T13N, ReE, UM 1/5/94 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3M-14 8651' MD 2746' @ TD feet 12.0' @ 360' MD feet 2560 6458' TV• feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1 000 feet Maximum hole angle 48,8o Maximum surface 2053 psig At total depth (TVD) 3275 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade CouplingI Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 36.0# J-55 BTC 4151' 41' 41' 4192' 3468' 480 Sx Arcticset III & HF-ERW 440 Sx Class (3 8.5" 7" 26.0# L-80 BTCMOE 8610' 41' 41' 8651' 6458' 1403xClassG HF-ERW Top 500' above 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 R Ee~u~d~ ~IE D True Vertical depth Structural Conductor Surface Intermediate J/~N -'3 1994 Production Liner,/~i'~'''I';': ~,.~:,,, 0il & Gas C0~s. Commission Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee X Property plat ~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot ~ Refraction analysis ~ Seabed report r'~ 20 AAC 25.050 requirements X 21. I hereby certify that tl'~e foregoing is true and correct to the best of my knowledge Title Area Drillin~ Encjineer Date SIgne ~'0~- /~4.]/4~ Commission Use Only Permit Number IAPI number '~" IApproval datei 7 ._.~; ISee cover letter for c~,~--/"~r~' 50-~?~-_?--~' .~_ ~ ~ /" ..~.-( -(,,~Tr,~ ;~ other requirements Conditions of' approval Samples required ~ Yes ~ No Mud Icg required Yes J~ No Hydrogen sulfide ~ Yes J~ No Directional survey required ~ Yes ~--1 No measures Required working pressure for DOPE ~ 2M ~ 3M [-1 5M [] 10M ~ 15M Qther: Original Signea By Approved by David W. Johnston Commissioner the commission Date /~, ',' /w' ~ . . Form 10-401 Rev. 7-24-8g triplicate o , , 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3M-26 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4192')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (8651') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED JAN .-.,--5 1994 Ai~.ska 0il & 6as Cons. 60mmissi0r~ Anchorage DRILLING FLUID PROGRAM Well 3M-26 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.5 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.3 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and 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 and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2047 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3M-26 is 3M-14. As designed, the minimum distance between the two wells would be 12.0' @ 360' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED JAN .-'$ 1994 0il & Gas Cons. Commission Anchorage ARCO ALASKA, Inc. iCreoted by : jones For: S BRADLEY iOote plotted : 27-Dec-93 Plot Reference is 26 Version #3. iCoordinotes ore in feet reference slot #26. !True Vertical Depths ore reference wellhead. Baker Hughes INTEQ --- Structure : Pod 5M Field : Kuparuk River Unit ! i V 5600 3300 3000 2700 I i I I t I I Well: 26 Location : North Slope, Alaska <-- West 2400 2100 1800 1500 1200 900 600 I II IZ II I[ II I[ 6OO 900 i 1200_ 1500_ o 1800_ _ 2100_ 2400 3300_ _ 31500_ _ 3900_ _ 4200_ 4500t 48ooq 5100t 5400t 5700...{ _ 6000_ _ 6300 _ _ TD LOCATION: [ ~ 2405' FNL, 257' FV/L SEC. 24, 'fl`3N. RSE TARGET LOCATION: RKB ELEVATION: 68' 25`34' FNL, ,375' F'WL SEC. 24, TI`3N, RSE TARGET TVD=6248 TMD=8`376 DEP=4955 NORTH 3685 WEST 3312. KOP Tv'D=IO00 TMD=IO00 DEP=O 6.00 BUILD 3 DE(; / 100' 512.00 18.00 B/ PERMAFROST TVD=1645 TMD=1656 DEP=112 24.00 0 ~060. 00 N~N.,.42.00 T/ UGNU SNDS TVD=2228 TMD=2534 DEP=447 ~ 48.00 EOC TVD=2437 TMD=2627 DEP=652 T/ W SAK SNDS TVD=2938 TMD=5587 DEP=1224 B/ W SAK SNDS 1'VD=`3268 TMD=3888 DEP=1601 %'~ 9 5/8" CSG PT l"v'D=5468 TMD=4192 DEP=1830 '~..~-10 TVD=3568 TMD=4344 DEP=1944 MAXIMUM ANGLE 48.8 DEG · }<-5 l'VD=5068 TMD=6621 DEP=5658~ TARGET ANGLE 40 DEG BEGIH ANGLE DROP 1VD=5954 TMD=7956 DEP=4647 DROP 2 DEG / 100' TARGET - T/ ZONE C (EOD) TVD=G248 TMD=8376 DEP=4955 T/ ZONE A TVD=6265 TIdD=8596 DEP=4967 B/ KUP SNDS 1%'D=6305 TMD=8451 DEP=5002 TD / 7" CSG PT TVD=6458 TMD=8651 DEP=5131 Scale 1 : 150.00 I i I I I I I i t I I I I I I I t i I I i00[ I I I I I 59100 I I I i I 300 0300 600 900 1200 1500 180-32100 2400 2700 ~ 3~00 3600 4200 4500 4800 5100 Scale 1 : 1,50.00 Vertical Section on 318.05 azimuth with reference 0.00 H, 0.00 E from slot #26 500 0 N 41.95 DEG W 4955' (TO TARGET) ISURFACE LOCATION: 939' FNL, 1593' FEL SEC. 25, T13N, RSE RECEIVED JAN --5 1994 Alaska Oil & Gas Cons. C0~nmission Anchorage 300 4200 - 3600 _3300 - _3000 2700 24.00 - _2100 - _1800 Z O 1soo '~i 1200 9OO 60O 300 -- -- 0 O 3OO O ii 5400 48.00 44.00 ARCO ALASKA, IllO. Structure : Pad 3M Well : 26 West 400 350 300 Field : Kuparuk River Unit Location : North Slope, Alaska 250 200 150 100 50 0 Scale 50 1 · 50.00 10o 1600 1600 200 1400 1400 2000 1 ooo 1800 1200 3000 1600 2800 2400 I 1400 200 I I . ioo 4OO _ 350 _ 300 _ 25O _ 200 / -- I _ 150 _ _ 100-- 5O 1200 1000 1000 2400 200 2600 00 RECEIVED 50' ( 100' JAN ---3 ]994 Aiaska 0il & Gas Cons. Commission Anchorage Casing Design/Cement Calculations 28-Dec-93 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TM D: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 3M-26 4,192 ft 3,468 ft 8,651 ft 6,458 ft 3,387 ft 8,376 ft 6,248 ft 3200 psi ==========?=?=?=?====?=?=?======?=?====?=?==========?=?=?=?===?=?========?=?==?=============?=============?= ** See Page 4 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 3,468 ft {(13.5*0.052)-0.11 }*TVDshoe =1 2,053 psiI Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =[ 3,200.0 ppg 6,248 ft 150 psi 10.3 ppgJ Surface lead: Top West Sak, TMD = 3,387 ft Design lead bottom 500 ft above the Top of West Sak = 2,887 ft Annular area = 0.3132 cf/If Lead length * Annulus area - 904 cf Excess factor = 15% Cement volume required = 1,040 cf Yield for Permafrost Cmt = 2.17 Cement volume required =[ 480 sxJ Surface tail: TMD shoe = 4,192 ft (surface TD - 500' above West Sak) * (Annulus area) - 409 cf Length of cmt inside csg = 80 ft Internal csg volume - 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 443 cf Excess factor = 15% Cement volume required - 510 cf Yield for Class G cmt - 1.15 Cement volume required =1 440 sxJ RECEIVED ,JAN -,3 1994 Oil & Gas Cons. Corr~mission Anchorage Casing Design / Cement Calculations 28-Dec-93 Production tail: TMD = 8,651 ft Top of Target, TMD -- 8,376 ft Want TOC 500' above top of target -- 7,876 ft Annulus area (9" Hole) -- 0.1745 (TD-TOC)*Annulus area -- 135 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing - 17 cf Total cmt - 152 cf Excess factor = 15% Cement volume required = 175 cf Yield for Class G cmt - 1.23 Cement volume required =L 140 sxJ TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) - Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy - Weight of displaced mud Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy -- Tension (Pipe Body) = Design Factor =1 Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =b Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length - Casing Wt (Ib/ft) = Dead Wt in Air - Buoyancy = Tension (Pipe Body) = Design Factor =1 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/R) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =l RECEIVED ,JAN .-.,3 1994 Oil & Gas Cons. Commission Anchorage 5640OO lb 4,192 ft 36.00 Ib/ft 150912.0 lb 23O23.6 lb 127888.4 lb 4.4] 639000 lb 4,192 ft 36.00 Ib/ft 150912.0 lb 23023.6 lb 127888.4 lb 604000 lb 8,651 ft 26.00 Ib/ft 224926.0 lb 34978.5 lb 189947.5 lb 3.21 667000 lb 8,651 ft 26.00 Ib/ft 224926.0 lb 34978.5 lb 189947.5 lb Casing Design / Cement Calculations ..BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressur(¢ Casing Rated For: Max Shut-in Pres = Design Factor =[ Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 28-Dec-93 3520 psi 2053.1 psi 1.7J 7240 psi 6963 psi 2989 psi 3974 psi 1.81 2020 psi 0.536 Ib/ft 923 psi 2.21 5410 psi 0.536 Ib/ft 3463 psi 1.6J RECEIVED JAN .... 5 1994 Oil & 6as Cons. Commission Anc/~orage Casing Design / Cement Calculations 28-Dec-93 Surface Casing Choices oi3 ID I b/ft Grade Metal X-Section Jt Strength Body Strength Collapse I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb Collapse Burst 5410 psi 7240 psi 4320 psi 4980 psi RECEIVED JAN .... $ 199zi f' ~'-~'" Oil & Gas Cons. Commissior-,, -'.. Anchorage ~UPARUK RIVER UNI', 20" DIVERTER SCHEMATIC I HCR 3 I DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20"-2000 PSI DRILLING SPOOLWITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION o,,. ooo RECEIVED 0il & Gas Cons. Commission Anchorage EDF 3/1 O/92 7 6 5 4 13 5/8" 5000 [-';51 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BO'FI-OM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16"- 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED JAF i994 & 6as Cons. Commission Anchorage ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE ~. ~.. ': ~, ,, .~, ~:~,.. [ 2 thru (3) Admi n ..~i> ~L (4) Casg (5) BOPE .,;:,:,..-:.,/?,-?, 9. [9 thru 13] 10. h ¢ . [10 g 13] / r / 12. [14 thru 22 15. [23 thru Company YES 1. Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. ~ 3. Is well located proper disgance from property line ................... /~ 4.. Is well located proper distance from other wells ..................... ~. 5. Is sufficient undndicated acreage available in this pool ............. ,~ 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. ~'~ 8. Can permit be approved before 15-day wait ............................ ~'. NO REMARKS ~' t ~ "' ' ~ f~' '- 7.,,-~. ,-~. ~,~. ~ ~ :5, -~.~ ,.~,., ..,,__ 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique n~ne & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is 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 drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... ? Does BOPE have sufficient pressure rating -- test to ~~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... ~-~7-~ Is presence of H2S gas probable ...................................... (6) Other [29 thru 31] (7) Con~act (8) Add] [32] 29. 30. 31. 32. 33. FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements ............................................. ,/ ~eo 1 ogy: DW. TAB rev 6~93 jo/6.011 en9ineer inq' INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ...> ,~ . ~ > ~ ,' ,,,. ~. ,~ ~ ×~ "~ -- ,'"" ~ 0 ~,. ~ b~ ,.,' -' ~ .. / ,:., ~_ . .~ . i , Additional MERIDIAN' remarks' UM SM WELL TYPE' Exp/Dev, Redrill Inj Rev C~ O ALASKA OIL AND GAS CONSERVATION COMMISSION December 22, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3M-26 ARCO Alaska, Inc. Permit No: 93-193 Sur. Loc. 938.5'FNL, 1593'FEL, Sec. 25, T13N, R8E, UM Btmhole Loc. 1454'FNL, 519'FEL, Sec. 23, T13N, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. S' Chairman~ BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ~ A~-,SKA OIL AND GAS ~SERVATION ~Ml.'_olON PERMIT TO DRILL 20 AA(;; 25.005 la. Type of Work Drill X Redrill E] lb Type of Well Exploratory E] Stratigraphic D Development Oil X Test Re-Entry D Deepen D Service D Development Gas D Single Zone X Multiple Zone D 2_ Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 68', Pad 27' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 ADL 25522, ALK 2558 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 938.5' FNL, 1593' FEL, SEC. 25, T13N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1589' FNL, 399' FEL, Sec. 23, T13N, RSE, UM 3M-26 #U-630610 At total depth 9. Approximate spud date Amount 1454' FNL, 519' FEL, Sec. 23, T13N, R8E, UM 12/22/93 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3 M- 1 5 9417' MD 3691' @ TD feet 12.4' @ 575' MD feet 2560 6460' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500 feet Maximum hole angle 52.65° Maximum surface 2047 pslg At total depth (TVD) 3325 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity' of cement Hole Casing Weight Grade Coupling Length Mi) TVD Mi) TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 36.0# J-55 BTC 4587' 41' 41' 4628' 3458' 540 Sx Arcticset III & HF, ERVV 460 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 9376' 41' 41' 9417' 6460' 140SxClassG HF-ERW Top 500' above 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 d~r~h~, True Vertical depth Structural~,[~CEIVED Conductor Surface Intermediate Production DEC 1 4 1995 Liner Perforation depth: measured Alaska Oil & ~ Corts. C(Iml/llss~0rl true vertical 20. Attachments Filing fee X Property plat D BoP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [~] Refraction analysis ~] Seabed report ["] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /,,/~,~~~~_,~ Title Area Drillinc, I Engineer Date / - Commission Use Only Permit. Number IAPInumber IApprova' date4,.~ Isee cover letter l°r ~.~ -/".~...,~ 50- ~-~.~ ~ -' ~ ~ ~'?',.~ / , ~4:~ -~ 5 other requirements Conditions of approval Samples required [-1 Yes ~ No Mud Icg required [] Yes J~ No Hydrogen sulfide D Yes ~[] No Directional survey required [] Yes D No measures Required working pressure for DOPE r'l 2M ~ 3M r'l 5M r'l 1OM D 15M Other: ,: i~:i"i~.! ..-.~,.gn~,(l By i;)avid W, Johnston by order of Approved by Commissioner the commission Date o..-_:~' Form 10-401 Rev. 7-24-89 ;[ o , . 10 11 12 13 14 15 16 17 18 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3M-26 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4628')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (9417') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED DEC 1 4 19~F5 u~ & Gas Cons. Commission Anchorage DRILLING FLUID PROGRAM Well 3M-26 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.5 15-25 15-35 5O-8O* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.5 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2047 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3M-26 is 3M-15. As designed, the minimum distance between the two wells would be 12.4' @ 575' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. R£CEIV O At~s~ Oil & Gas C[ms. Anchorage ARCO ALASKA, Inc. Structure : Pod 3M Well : 26 iCreated by : jones For: S :Date plotted : 7-Dec-93 Plot Reference is 26 Version #2. iCoordinotes are in feet reference slot #26. iTrue Vertical Depths are reference wellhead. Baker Hughes INTEQ .... TD LOCATION: J 1454' FNL, 519' FEL SEC. 25, T13N, RSE 350 700 t 1C)50~ 1400 ! 1750 2450_~ 2s°°4 - 3500_ 5850_ 4550_ Field : Kuparuk River Unit Location : North Slope, Alaska RKB ELEVATION: 68' ,3.00 KOP TVD=500 TMD=500 DEP=O 27.00 TARGET LOCATION: 1587 FNL, 399' FEL SEC.23,T15N,R8E TARGET TVD=6245 TMD=9156 DEP=6175 NORTH 4650 WEST 4086 4550 4200 3850 3500 3150 [ I I I [ I i I I , \Nk 33.00 ",% 39.00 B/ PERMAFROST TVD=1648 TMD=1732 DEP=384 x..... 45.00 '~...51.00 EOC TVD=2018 TMD=2255 DEP=751 ~ T/ UGNU SNDS TVD=2228 TMD=2601 OEP=lO26 MAXIMUM ANGLE 52.65 DEG <-- West 2~00 2450 2100 1750 1400 1050 700 I I I I [ I I I I I I I I N 41.43 DEG W 6175' (TO TARGET) T/ W SAK SNDS TVD=2938 TMD=3771 DEP=1956 B/' W SAt': SNDS T'VD=,3258 TMD=4298 DEP=2576 Scale 1 : 175.00 350 0 350 4900 455O . .420~ _ _ . _3150 . .2800 _ _2450 _ _210~ _ _ ! 750 1400 1050 700 35O 0 350 TARGET ANGLE ~ t 40 DEG 6650/-~ I I I I '' ' ' ' ' ' ' ' ' ' ' g' ' ' ' ' ' ' g' ' ' ' ' ' ' ' ' '5' ' '5' ' 350 0 350 700 1050 1400 1750 21 2450 2800 3150 35 3850 4200 45,.'.'.'.'.'.'.'.'.~0 4900 52 0 56,0059 0 6300 6650 I I g 0 ~ 9 5/8" CSG PT TVD=3458 TMD=4628 DEP=2638 10:- TVD=3548 1'MD=4776 DEP=2756 [ ESTIMATED SURFACE LOCATION: I 958.5' FNL, 1593' FEL ~'-~..... SEC. 25, T15N, R8E -._ ~ ,', ~,;lta u~ & Gas Cons. Commission BEGIN ANGLE DROP TVD=5809 TMD=8505 DEP=5718 o~o, ~ / ,®. "'%s°'4~'°°°° Anchorage TARGET - T/ ZONE C (BOP) TVD=0245 TMD=9136 D~P=0]Ta N 42.00 Ti/ ZONE A TVD=6262 TMD=9158 DEP=6189 B/ KUP SNDS TVD=6507 TMD=9217 DEP=6227 TI) / ?" CSG PT '~/I)=6460 ?MD=941? DRP=6855 Scale 1 : 175.00 Vertical Section on 318.57 ozimuth with reference 0.00 N, 0,00 E from slot #26 West 2100 2050 2000 1950 I I I I I I I 1700 ARCO AI,ASKA, Inc. Structure · Pad 3M Field · Kuparuk River Unit Well: 25-24-25-26 Location · North Slope, Alaska 19OO I I 1850 1800 1750 I I I I I 1500 15O0 1500 1300 1300 1700 1650 1600 I I I I I I 2900 1300 1100 1 lO0 900 1100 700 1550 650 _ ~" _ 700 " o _ 75O (./) 800 0 I 850 ~ I 900 I V 950 ,i PROPOSED 500 000 Casing Design / Cement Calculations 10-Dec-93 Well Number: 3M-26 Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 4,628 ft 3,458 ft 9,417 ft 6,460 ft 3,771 ft 9,136 ft 6,245 ft 3250 psi 3,500 psi Maximum anticipated surface pressure 1-VD surface shoe = 3,458 ft {(13.5'0.052)-0.11}*TVDshoe =[ 2,047 psiJ Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD: Overbalance, psi= Anticipated Mud Weight =J 3,250.0 ppg 6,245 ft 150 psi 10.5 ppgJ Surface lead: Surface tail: Top West Sak, TMD = 3,771 ft Design lead bottom 500 ft above the Top of West Sak = 3,271 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,024 cf Excess factor = 15% Cement volume required = 1,178 cf Yield for Permafrost Cmt = 2.17 Cement volume required =[ 540 sxI TM D shoe: 4,628 ft (sudace TD - 500' above West Sak) * (Annulus area) = 425 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4340 cf/If Cmt required in casing = 35 cf Total cmt = 460 cf Excess factor = 15% Cement volume required = 529 cf Yield for Class G cmt = 1.1 5 Cement volume required =1 460 sxI RECEIVED DEC 1 4 1993 0il & 6aS Cons. Commission Anchorage Casing Design ! Cement Calculations 10-Dec-93 Production tail: TMD = 9,417 ft Top of Target, TM D = 9,136 ft Want TOC 500' above top of target = 8,636 ft Annulus area (9" Hole)= 0.1745 (TD-TOC)*Annulus area = 136 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 153 cf Excess factor = 15% Cement volume required = 176 cf Yield for Class G cmt = 1.23 Cement volume required =[ 140 sxJ TENSION - Minimum Design Factors are: T(pb)=l.5 and TOs)=1.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Length Casing Wt (Ib/ft) Dead Wt in Air Buoyancy = Tension (Pipe Body) Design Factor Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud RECEIVED Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Gas Cor~s. Commiss~0n Anchorage 564000 lb 4,628 ft 36.00 Ib/ft 166608.0 lb 25810.0 lb 140798.0 lb 4.01 639000 lb 4,628 ft 36.00 Ib/ft 166608.0 lb 25810.0 lb 140798.0 lb 4.5J 604000 lb 9,417 ft 26.00 Ib/ft 244842.0 lb 38662.6 lb 206179.4 lb 2.91 667OOO lb 9,417 ft 26.O0 Ib/ft 244842.0 lb 38662.6 lb 206179.4 lb 3.2] Casing Design / Cement Calculations BURST - Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =[ Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE - Minimum Design Factor = 1.0 -- Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*-FVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 10-Dec-93 3520 psi 2047.1 psi 1.7J 7240 psi 7017 psi 2990 psi 4027 psi 1.81 2020 psi 0.544 Ib/ft 947 psi 2.1J 5410 psi O.544 Ib/ft 3517 psi 1.51 RECEIVED DEC 1 4 i99b .~!aska Ull & Gas Cons. Commission Anchorage Casing Design/Cement Calculations 10-Dec-93 Surface Casing Choices OD ID I b/ft Grade I 9.625 8.681 47 L-80 2 9.625 8.835 40 L-80 3 9.625 8.921 36 J-55 4 10.750 9.950 45.5 J-55 Metal X-Section Jt Strength Body Strength Collapse 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 13.0062 sq. in. 931000 lb 715000 lb 2090 psi Burst 6870 psi 5750 psi 3520 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade I 7.000 6.276 26 L-80 2 7.000 6.276 26 J-55 Metal X-Section Jt Strength Body Strength Collapse Burst 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 7240 psi 7.5491 sq. in. 490000 lb 415000 lb 4320 psi 4980 psi RECEIVED DEC 1 4 199~ Aiaska (Jil & Gas Cons. Commission Anchorage ~UPARUK RIVER UNI'~~ 20" DIVERTER SCHEMATIC I DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION 3 , UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION ~. ~o,,.~ooo~s, ANNUL~ ~V~ R E C E IV E E) DEC 1 4 '199~ Aiaska UiI & Gas Cons. Commissio~ Anchorage EDF 3/10/92 13 5/8" 5000 1-,51 BOP STACK 7 I I I ' 4 I ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSi WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-FOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED DEC A~.~ska {jit & Gas Cons. OommissJor, Anchorage CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE ( 1 ) Fee ,,~,"' (2) Loc [2 thru 8] (4) Casg (5) BOPE ) [9~Bru 13](¢ [10 & 13] [14 thru 22] [23 thru 2 Company //~','~r',,J,q2 , , , YES 1. Is permit fee attached ............................................... 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 und~.dicated acreage available in this pool ............. 6. Is well to be deviated $ is wellbore plat included ................... .~ 7. Is operator the only affected party .................................. ~ .... 8. Can permit be approved before 15-day wait ............................ .. i 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24 25 26 27 28. Lease & Well NO Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is 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 drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter $ BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~Z~ ps ig ..... Does choke .manifold comply w/API RP-53 (May 84) ...... ~ ......... Is presence of H2S gas probable ...................................... REMARKS ([6) Other /~(i~.~. ,./~p/"/?:...,,;,:~. [29 thru 31] (7) Contact / f::l ~ .iI~ ~ [32] (:8) Addl 29. 30. 31. 32. 33. geology' engineer ing: rev 6~93 jo/6.011 FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~nber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ' 'i/ ~ ~ ,~ 17/~ ~ ~3 Additional remarks' UM Y MERIDIAN' SM WELL TYPE' Exp/(]~i .,¥ Inj Red r i 11 Rev 0 ~0 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. * ALASKA COMPUTING * ****************************** *------- SCHLU~BERGE~ ****************************** COMPANY NAif: : ARCO ALASKA, !NC, W£bL N~MF : 3M-26 FIELD NAME : KUPAROK RIVER RtJROUG~ : NORT}~ SLOPE STATE : ALASFA API NU~BE~ : 50-029-22431-00 REFERENCE NO : 94023 RECEIVED MAY 0 9 1994 A/ae/m Oil & Sas Cons. Commission Anchorage ..IS TaDe Verificatt. on Listlnq ;cblumberqer AlasKa Co~[;t!ti.r. lq Center PAGE..'. **~* REEL HEADF~R **** SERVICE NR~IE : EDIT DaTE : 94/04/28 ORICI~ : ~L!C REEL ~A~E : °4023 CONTI~]U~TIU~ ~ : P~EVIOUS R~jEb : COM~T ~ ~:RCO AI,ASKA, INC,,KUPARUK RIVER UN/T, 3M-26,50-029-22431-00 **** TAPE HEADF:R S~RVICE NAME : EDIT DATE : 94/04/28 ORIGIN : FL!C TAPE ~AME : 94023 CONTINUATIOM # PREVIOUS TAPE CO~E~T : ARCO ALASKA, INC,,KUPARUK RIVER UNIT, 3N-26,50-0~9-224~1-00 TAP~ HEADER KIJP5RUK RIVER MWD/MAD LOGS Ami {~UMBER: O~E~ATOR: bOGGING COMPA~4'¥: T~PF CREATION DATE: nP~RATnR WIT~tE$S: 8I{R~ACE LOC~T!ON SECTION: TOwnShiP: FNL! FSL: FEb: FWb: DERRICK CASING RECORD BIT RII~i !, ST. AMOUR 1ST STPI~G 2t'~D ST~IWG 3S-26 500292243100 ARCO ~bASKA, iNC. 8C~LIIhBERGER i.. SERVICES 27-APR-94 BiT RUN 2 ~4023 ~T. AMOUR ~IT RUN 3 25 1 939 15~3 68,on 68,00 2'7,00 OPEN tiOI.E CASING DRILbER$ BIT STZg (IN) STZg (1N) DgPT!.{ (FI) 8,500 9,625 48~2.0 ~I$ Tape Verificat~o~ Listing 28-APR-~994 14:51 .chlumberoer AlasKa Computing Center 3RD STRi~G ~a~s: ************** ~t,}~+~ 1 *****~********* RES TO BlT{ 65,93 ~'T GP TO ~!T~ 76 26 FT {)EN TO ~iT: i~9'34 FT D~70T T0 SIT: 136,32 FT DRII~L~][) INTERVAL: 4882-9180 ~T *****'*~******* RON ~ RGS RP TO BIT: 29,87 FT {',~P8 RP TO BIT: 52,38 FT RKS TO BlT: 26 70 f~T GR TO [~IT: 37 ~2 FT DEN TO BIT: 5~,69 f~T NEUT T0 }:{IT: 60,67 DPi[~L:ED IMT~RVAL: 9J~80 - 9~25 FT V~ASHDObN INTERV~,L: 9104 - 9180 FT HObM ANGLE AT TD = 36,00 [)E;G.g 9625 b.iAXI~iU~ HOLE ~h~GbE = 56,37 DEG,8 7230,40 FT TD WELL ~ 19154 JAN 15,1994 L~S f'OR~iAT DATA PAGE: **** FILE ~4E~DER **** F!L~ MAUE : EOIT ,001 SERVICE : FbIC ¥FRSION : O0~CO! D~TF : 94/04/~8 MAX REC SIZ~ : ~024 FTL~ TYPE L~5'? FI!,E FTLF HEAI)FR FIL~ MU~BER: 1 EDI~ED ~ERGED ~t~ DePth shiite~ and clt~Ded curves: all bit runs merqed. DEPTH IMCRE~E~T$ 0.5000 # FTLF SU~M~RY LDWG TOOL COD~ CDR C D $ START DEPTH 4R06.0 ~RCH SlOP DEPTh 9625 9625.0 iS Ta~e Verification Listtna chlumberger A,.1. asKa Comp,J. tln~ Center 2~-APR-1994 14:51 ----- ..... EQUIVALENT UNSHIFTED DEPTH---------- F~ASELiNE D~PT!4 8888~.0 98~84.5 9~78'0 9274.5 9237,0 9233,. 9~00,0 9!96.0 105 918~.0 ~0~9' 9054,0 ~ .. ,0 90 40.0 9039,5 902!,5 902t,5 8977,0 8977,0 960,5 8960.5 .917,0 8q15,5 890n,0 8~9~.5 8791,0 8791,0 8728,5 8728,5 8529,5 8529,0 8445,0 8444,5 8350 0 8348.5 7055.0 7955.0 100.0 !00.0 LDWG TOO[, CODE ~IT RUN ~D. UERGE TOP ..... ...... .... .... ....... ........ C[)~ 1 48060. CO~ 2 g180,O CD~ ~ 4806.0 CDN ~ 9180.0 ME~GE ~ASE 180.0 9625.0 9180.0 9625.0 THE DFPTH ADJUST~iEr:~TS SHGWN ABOVE REF[,ECT THE MWD GR TO THE CBT/GR D~.TED 29-Jh~-~994. ALL OTHER CURVES WERE C~RRIFD WITH THE GR SHIFT. ~-~IS FILE ALSO CONTAIN5 TME VFRY ~iNHANC?D ORr} PPOCESSED RESISTIVITY DATA WITH 2' AVEPAGE. THE GPCW.CET lS ALSO INCLUDED IN THIS FILE. $ LIS FORMAT DATA PAGE: IS Tape Verification Listing chlumherger AlasK'a Co,purl, ri0 Center 28-'~PR-! 994 !4:51 PAGE; ** SET TYPE - 64EB ** TYPE R~PP C{3D~ VALItE I 6~ 0 2 66 0 3 73 68 4 66 5 66 6 73 7 65 8 68 0,5 9 I~ 66 15 1~ 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - C~A ,.M ~ER.V O E A ID ORD~ # h '5[;['' ...... 7;'''~''';'''''302 0 0 R~O~ ~WD G/C3 630260 0 DmHO ~WD G/C3 630260 0 PEF ~O BNtE 630260 0 C~LN ~W9 IM 630260 NPH! u~D P[]-$ 630260 R~ ~WP 0~4 ~ 630260 RP Mt,~O OH~~ 630260 DFE ~wD og~ ~ ~30260 V~P ~w9 O H ~:~ ~'~ ~30260 V~A ~[) OHMu 630260 ROP ~ f'PHP 630260 G~ }~D GAPI 630260 NCNT ~W~ CD6 ~30260 FCNT ~WD C~$ 630260 F~T ~D HR 638260 GPC~ CET G~PI 630260 ** ~.PI APl API FILE NU ,B E EPR PROCESS OG TYPE CLASS ~OO NUmB SA~P ELEM CODE fHEX) '''''''''''''''''''''''''''''''''''''''O 00 0 1 1 1 4 .... 68''''';';''''''''0 0000000 0 000 00 0 1 1 ! 4 68 0000000000 0 000 O0 0 1 I 1 4 68 0000000000 0 OOO O0 0 1 1 I 4 68 0000000000 O0 OOO O0 0 I ! I 4 68 0000000000 O0 000 O0 0 1 1. 1 4 68 0000000000 00 OUO O0 0 I 1. 1 4 68 0000000000 O0 000 O0 0 I 1 1 4 68 0000000000 0O 000 O0 O 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 I 1 1 4 68 0000000000 00 non O0 0 ! ! 1 4 68 0000000000 O0 000 O0 0 l 1 I 4 68 0000000000 OO 000 O0 0 1 ! 1 4 68 0000000000 On 000 O0 0 i I I 4 68 0000000000 O0 000 On 0 1 1 I 4 68 0000000000 O0 000 O0 0 I 1 1 4 68 O000000000 mmmmmmmmmmmm# mmmm#mmmmm#mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm#m#mmmmmmmmmmmm DEPT. gOD0.500 RhOB.~wo -999.250 DR;40.MWD -999.250 PEF.~D Cab~.~,~O -999.250 HPHI.i,iWD -o99.250 PA.MWD -999.250 RP*MwD DEP.M~D -9q9.250 'VPP.M!ql.) 1OO0.OO0 V~A.MWD 1000.000 ROP.~D G~.~wn -9o9.250 NCNT.MWD -999.250 FC~!T.~WD -999.250 FET.U~D ~999250 999:250 27.279 -999,250 IS ~aoe verification tistln~ chlumberger AlasKa Computing Cent:er G~C~{.CET -9C~9,250 DEPT, ~000,000 RHO~.~WO CaL~,MWD 8.690 ~PHI'~WD DE~,~WD 3.654 VRP,~WD G~.~WO §1.269 NC~T,MWD GRCW,CET 50,735 DEPT, ~7000.000 R HOi!~. ~iWD CaLN.MWD 8.500 gPgI. ~tW[) DE~. ~D 3.136 VRP, ~i ~L G~ ~WD i12.425 NCNT, NWD GPCH:CET -999,250 DEPT, 6000,000 RHOB,~WD C~[,M,MWD 8.600 NPHI,MWD DEP.~WD 3,61.3 VPP,MWD G~.M~D 10~.421 NCNT.MWD GPCH,C~T -999.250 DEPT, 5000,000" . R. HOB.MWD C~LW. ~W.~ 8.51.2 NPHi.blWD DER. ~WD 2.453 VPP. ~ ~D G~.MWD 89.241 NCNT./~!WD GPCM, CET -9~9.25() DEPT. 4745.O00 CaLN.~.WO -999,290 NPHI.MWD r)EP,MwO - ,.9~9,250 VPP. (;P, ~WD '999. 250 NCNT GPCM.CET -999.250 ** EMD OF DA~A ** **** FILE TR~ILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01COI DITF : 94/04/28 MaX REC SIZE : 1024 FIb~ TYPE : LO L~$T FILE : 2!~-/~PR-! 994 14:51 2,466 DRHO.M'WD 33.900 RA.MWD 3.000 VRA.'MWD 292,000 FCNT.MWO 3.159 6,665 ~3.32¢ .... ~A,MWD 3; 700 -999,250 V~A,MWD -999,250 ~96..480 FCNT.MWD 6.805 2 37o 36:300 RA.MWO -999.250 VRA,MWD 279,624 FCNT.NWD o 022 3iO32 -999 250 6.065 0.01~ 3.756 -999,~50 6.260 178 DRHO.MWD -0 001 37~00 RA,MWD 1;98! -099.~50 VRA.MWD -999 250 ~70.500 FCNT.MWD 5~773 -999,250 DRHO,MWD -a99.250 RA,MWD -999 250 VRA,MWD -09o.:25o FC~T.~WO -999 250 -0991250 -999 ~50 ~ 146 PEF,M~D .RP,MWD ROP.MWD FET,~MD PEF RP:M~D ROP.~D FET,MWD PEF M~{D ROP,MWD FET.~WD P~F,MWD RP.MWD ROP,~WD FET,~WD PEF.M~D RP,MWD ROP.~W'O FET,~WD PEF RPiMWD ROP~wD FET,~WD PAGE: 974 954 29:5 956 035 630 · I 87 3, '193 3.200 397.. 499 0.247 3. ,~53 3. 47 230,779 0,307 3 5O 381,637 0,169 -999.250 -999250 '999i250 -999 250 ,IS Tame Yerificatton Listing ~chlumberger Alaska Computing Center **** FILE BEADFR **** FILE ~A~E : FDI~I' .002 SERVICE : FbIC VERSION : OO~.COI DATE : 94/04/28 M,SX H~C SIZE : 1024 F!LF TYPE : LO L~ST FILE { 2B-A~R-~.994 14:5i FILE TUBBER 2 Curves a~d lDO qeader data ~or each bit run In sepsrate D~PTH i~CREMENT: 0.5000 LDWG TOO[~ CODE START DEPTH .... ...... . ...... ........ CmN 4745.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURWACE $OFT~AkE VERSION: DATA TYPE (MFMQRY or REAI,-TI~E): TD DRILLER TOP LOG FOTTOM LmG INTF~VAL (MT), nit POTATiNG TOLE INCLI~ATION (DEG) MININ!~M ANGI, E: M~X!M~IM ANGL~: TOO[, ST~IMG (TOP VENDO~ TOnb COOE TOO[, TYPE CDR RESISTIVIT~ STOP DEPTH 9~80,0 N~UTRON/PDROSITY BORE~!OI,E AMD C~$1i',~G DATA OPE~ HOI, E f{!T ~IZE (IN): DRILL, EPS CASING DEPTH (FT): ~ORE~O[.,E CONDITIONS MUD TYPE: MUD DRNSIT~ 16-jAN-94 FAST 2,4 ~EMORY 9625.0 4750 0 9625~o 56.4 NUMBER ;7.,';;;s ..... NDS049 RNGSOO9 8,500 4~82.0 files. IS Tare Verification I,isting chlumberger AlasKa Computfnc! Center 28-APR-1994 14:51 ~UD VISCOSITY FLUID LOSS RES!STIVITY (ON~) AT TE~PERATURE (DEGF): MUD ~T ~EASURED TEMPERATURE ~UD AT ~A× CIRCULATING TEMPERATURE ~UD FILTRATE AT (MT): ~UD CAKE AT (MT): MATRIX: ~AT~IX DENSITY: TOOL STAb!DOFF (IN): !50,0 3,470 3,090 SANDSTONE 2.65 1,000 RIIN I DRILLED INTF, RVAI, 44~2 - 9180 PT R!!~',~ 2 i;?RILL~]D iNTERVAL 91~0 - 9625 FT WAS!..IDO~N INTERVAL 9104 - 9180 FT HOb~ A~GLE AT TD : 36.0 LEG ~qaXI~qI~ }.!OI~E .ANGL~ = 56,37 DEG ~T 7230,40 FT TD W~]T.,5 AT 19:54 JAN 15, ~.994 LIS FORMAT DATA 80,0 80.0 PAGE: DATA FOR~!AT SPECTF!CAT!UN PECORD ** 2 66 0 3 71{ 64 4 66 1 5 66 6 7~ 7 65 8 68 0.5 9 65 FT 1~ 6~ 13 66 0 14 65 PT 15 6b 6~ 1~ 6~ 1 0 66 I IS Tape verification Listino chlumberger AlasKa Computing C e B t e r 28-APR-] 994 14:5i PAGE: RHO~ D~H! L~! D~HO LW1 PEF LWl DCAL ATR LW 1 PSR D~R H~F~ TABU L~I SET TYPE - C~AN [iRD~R # LOG TYPE CLASS MOD ..;..... . ....... ;..-;-.., ...... 63 26(i) O0 0 0 0 0 G/C3 630260 00 000 00 0 PU 630260 0o 00o 00' 0 G/C3 630260 O0 000 O0 0 BNtE 630260 O0 000 O0 0 IN 630260 00 00(7) 00 0 PU 630260 O0 000 O0 0 OHM~ 630260 O0 000 O0 0 OH~4~ 630260 oo 000 O0 0 O~M~ 630260 O0 000 O0 0 F/HR 630260 O0 00~ O0 0 2 GAPI 630260 00 000 O0 0 2 CPS 630260 O0 000 O0 0 2 CPS 630260 O0 000 O0 0 2 H~ 630260 O0 000 O0 0 2 HP 630260 O0 000 O0 0 2 BE NU~4B NUMB R PROCESS NUMB SAMP EbEM CODE (HEX) ;''''''! ..... 1'''''''''''''''''''''''''''''4 6800 . O0 2 t I 4 68 0000000000 2 1 1 4 68 0000000000 2 1 1 4 68 0000000000 2 I 1 4 68 0000000000 2 1 ! 4 68 0000000000 2 1 i 4 68 0000000000 2 i i 4 68 0000000000 2 I i 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 i I 4 68 O00000OO00 i I 4 68 0000000000 i 1 4 68 0000000000 I ! 4 68 0000000000 1. I 4 6a 0000000000 DEPW. 9179.000 RHOB.bWi -999.250 PE~.!,Wl -999.25() DCAb.hWi -999.250 P$~.L~I -999.250 [)ER.LWI -q99.250 HFNI.LW~ -909.250 HEWA.I.,%!I -990.250 DFPT. qO00.O00 aHOB.LW1 2.466 PEF I.~ 3 974 gab LWl 0 252 PS~L~/. 2.954. DER.bWl 2.939 H~N~.LW1 292.000 HEVA.U~;I 6.605 D~PT EO00.O00 PHOB bWl 2,46~ · Ev,'I,;~I 3'087 DC~blI,~l 0.175 DSP. I.w I 3. t)? 8 t)F~. bw I 3.60g HFN~.L~I 296.250 }~EFA. h~,~ 1 7,038 DFPT. 7000.CO0 RHOB,bWl 2.370 PEF.Lwl 3.103 OCab.hw1 0.000 PS~.LW! 3.200 DFR.Lwl 3.136 [i~a.[,~! 279.62t HE;FA.LWl 6.065 DVPT 6000.un0 ~itOf3.b~l 2.359 PEV~!,~;~! 3.053 DCaB,L~I 0.100 ~5~.L;~l 3.547 DER.bWI 3,613 }iENa.L~I 2~2,'150 HEFA.LWl 6.200 np 4t.bwl -9.99.2so DRanO.nWl TNP~.LWI -999.25o ATR.bWl ROPE,LWI 269 841 GR bWl TAB.nWl -999 25o T BO:t, Wl DPFII.LWl 11.200 DRHO.LWl TNPH,LWI 33 900 ATR LWl ROPE.BWl 193i295 GR:LW! TAO.BWl 0 956 TABD.LW1 DPHI.bWl 1! 000 DRHO.LWl TNPH.hWI 31!700 ATR'LWl ~OPE.LWl 353 847 GR.L~I TAB.LW1 0.187 TABD.I,~i DPDI.LWl 17.000 DRHO.LW! TNPH.bW1 36.300 ATR.LWl ~OP~;,bW1 397.499 G~.L~I IAB.bwl 0.247 TABD.LW! oPNl.bWl 17.600 DR~{O b~l TNPH.hWI 35.200 ATR:LWl RDPE.LWI 230.77g GR,I,,Wl T~B.bw1 0.307 TABD.L~! .-999.250 ~ 999.250 999. 250 -999.250 0,014 259 1.653 ~, 56 89.494 0.545 0,022 3,032 112,425 0.394 0.018 3.756 108.421 0.583 :IS WaDe verification Listinq cblum~erDer AlasKa Computino Center DEPT 5000.000 PiiOB.bWl PEP tL, W~ 3.209 DCAb,LWl PSP I'.~W! 3. i50 DER.LNI HFN~ I,,~I 270,500 HEF'~. LW 1 2a-~PR-lg94 14:51 2.178 0 012 2 453 5 7'13 DPM!.LW1 TNPH'bWI ROPE,bW1 T~B.hN1 DEPT 4745,000 ~i'iOH bWl -999 250 DJ>HI t:,~R. LW 1 '999,250 LC!L, L.~ i -990 250 TNPit, LW1 ,LW1 -999 250 DER,b~I -999' ... . , .. ,250 [iMN~,L~! -999.250 HEFA,bW1 4,I46 TAB,bWi END OP DATA ** -999.250 DRHO.bW~ -999,250 ATR.bWl -999.~50 GR.LWl -999,250 TABO,LW! PAGE: -0.001 1,981 89,24! 0,442 -999.250 -999.250 -999 ' 250 -999,250 **** FILE TRAIL~ .... **** F!L~ ~A~ : EDIT ,002 SERVICE : FblC VERSION : O0tCO1 DATE MAX REC SIZ~ : !024 FTb~ TYPE : LAST FILE **** FIL~ HEADER **** FILE NA~E t EDTT ,003 SERVICE : FblC VFRSION : 001C0! DATE : 94104/~8 MAX REC SIZE : 1024 F!L~ TYPE : LAST F!L~; FILE HEADER FIbF NUMBER 3 Curves and log header ~ata ~or each bit run in semarate BIT R!iN ~,[.I~BEP: 2 DPPTH I~CPE~E~T: 0.5000 FILE SLJ~i~hRY !.,DWG ~OOL COPE CD N LOG HEADER DATA DAmE bOGGED; SOFTWARE: St~RWACE 5()~'q'~AR~ VEP$IU~; START DEPTH 9180.0 STOP DEPTH 9625. 9625.0 16-dAN-94 PAST 2.4 files. ,IS Tape verification Listinq ichlumberger AlasKa ComputinQ Center 2B-APR-1994 14:51 PAGE~ 10 DOWMHOLE SOFTWARE VERSIO?~ DATA TYP~ (MK;qORY or REAL-Ti~'!E): TD D~ILLER (FT): TOP [,OG INTERVAL (FT): BOTTOI~ LOG INTERVAL ~IT POTATING SPEED HOLE I~CblNATION (DEG) ~4 Y N I Mi. JM ANGLE~: M~XIM!~M ANGLE: ST'~ING (TOP TO BOTTOM) TOOL COD~ TOOL BOREHOLE AND CASING DATA OPEN HOLE B!T SIZE (IN): DRILLERS C.a6INC, DEPTH ~5~ORY 9625.0 4750.0 9625.0 56.4 TO06 NUMBER RGS055 NDS049 RNGSO09 BOREHOLE CONDITIONS MUD TYPF: MUD DENSITY MUD VISCOSITY (S): MUD PN: MAXIM{!M RECORDED TEMPERATURE (DEGF): RRSYSTIVIT¥ (OH~) AT TRNPERATORE (DEGF); ~UD ~T HEASUP'~.ED TE~P~R~'TURE C~T3; ~UO.AT MAX CIRCULATING T~MPERATORE MOD FILTRATE AT uUD CAKE AT NEUTRON TOOL., M~TPIX: ~ATRIX DENSITY: HOLE COPRECTID~ {IN): TOOL STANOOFW (IN): FWD FREQI!E~3CY (HZ): 8,500 4882.0 ~0,10 ~50.0 3.470 SANDSTONE P.65 1.000 RUN 1 Deli, LED INTERVAl, 4482 - 9~80 FT RUN 2 DRILLED INTERVAL 9180 - 9625 MT ~$HDOW~] INTErVaL 9104 - 9180 P'T hOLE ~NGLF AT TD : ]6.0 D~G ~AX!M[~ HOLE ~NGi.,E : 56.37 PEG AT 7230.40 TD WELL AT ~9:5~ JA~ ~5, ~.994 $ L~S FORMAT DATA 80.0 80.0 IS Tame Verification List,.no chlumberger AlasKa Com'putinq Center 28-APR-]9~4 1,4:51 PAGE: 1.1 DATA FORMAT SPECIFICATION R~CORD ** ** SET TYPE - 64EB ** TYPE REP~ CODE VA. bUE I 66 0 2 66 0 3 73 64 4 66 5 66 6 73 7 65 9 65 II 66 1.6 !~ 68 1~ 66 0 i4 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ..... ........... '"""'"'"'" ;" NAME V UN SE VICE APl APl A~I APT FILE NU .B MB SIZE REPR PROCESS ID ORDER # LO.G TYPE CLASS MOD NUmB SAPP E]LEM CODE (HEX) ......... ............... . .......... ......-............................................. D~PT FT 630260 00 006 00 0 3 I 1 4 68 0000000000 RHO~ [,W~ G/C3 630260 O0 000 O0 0 3 1 1 4 68 0000000000 DPHT [.,W~ PU 630260 00 000 O0 0 3 1 1 4 68 0000000000 D~HO LW2 G/C3 630260 O0 000 O0 0 3 1 I 4 68 0000000000 PEF LW? BN/E 630260 00 000 O0 0 3 1 1 4 68 0000000000 DCAL LW2 IN 630260 O0 000 O0 0 3 1 1 4 68 0000000000 TNP~ LW2 PU 630260 O0 000 00 0 3 I 1 4 68 0000000000 ATR t.,~ OHM~ 630260 00 000 00 0 3 I 1 4 68 0000000000 PSR T.,~? OMM~ 630260 O0 000 00 0 3 1 i 4 68 0000000000 D~R [~ OMM~ 630260 OO 000 O0 0 3 I 1 4 68 0000000000 ROP~ I.:~ F/HR 630260 00 000 O0 O 3 1 1 4 68 0000000000 GP l..w? GAP! 630260 00 000 00 0 3 I 1 4 68 0000000000 HENA T,W~ CPS 630260 O0 000 O0 0 3 1 1 4 68 0000000000 H~F~ L~ CPS 630260 O0 OOU O0 0 3 1 1 4 68 0000000000 TaB Lw7 H~ 630260 O0 000 O0 0 3 i 1 4 68 0000000000 T~BD I,,~ ~-:tP 630260 O0 000 O0 0 3 1 I 4 68 0000000000 mmmmmm~mmmmm*m~mmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmm#mmmmmmmmmmmmmmmm ,iS Tape Ver~.~].cat~on Listinq ~chlumberger AlasKa Computlnq Center 90~8.500 RHO~:~. LW2 -999.250 DCAL.LW2 -999. 250 DER' bw2 -999.250 HEVA.LW2 END OF DATA 28-APR-1994 14:51 -999. ~50 DPHI. LW2 -999.250 Th~P}t.. bW2 -999,250 R[IPE.bW2 -999.250 TAB,LW2 '999.250 DPHI,i, W2 -999.250 TNPH.LW2 -999.250 ROPE'LW2 5,780 TAB.LW2 '999.250 DRHO.LW2 - Al. LW2 999.~50 ~'~. 27,745 GR,LW2 -999.250 TABD.LW~ PAGE: ~999.250 999.250 '999..250 '999.250 -999 250 DR}iO.L~2 -999.250 ' ' R L~2 -999,250 "999.~50 A~ , -999,250 GR.LW~ 999'250 -999.250 TABD,LW2 :999,250 12 **** F!L~ TRAILER FlbE NA~5 : EDIT .003 SERVICE ~ FLIC VERSIO~ : DAT~ : 94/04/28 MAX REC S!Z~ : 1024 FIL~ TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NANE : EDIT DATE : ~4t04/~8 ORIGIN : FLIC TAPE NA~E : 94023 CONTINUATION # : ~ PREVIOUS TAPE : CO~ENT ~ ARCO ALASKA, INC.,KUPAROK RIVER UNIT, 3M-26,50-029-22431-00 **** REEF., T~{A!LER **** 8FRV1CE NAME : EDIT DATE : ~4t04/25 O~iCI~ ! FLIC CONTiNUATTUN ~ : PREVIOUS REEL ~ Co~ENT : A~CO ALASKA, INC.,KUPARUK RlVER UNIT, 3M-26,50-029-22431-00