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Home My WebLink About178-031MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, January 27, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 04-13 PRUDHOE BAY UNIT 04-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/27/2025 04-13 50-029-20305-00-00 178-031-0 W SPT 8355 1780310 2089 1808 1808 1810 1805 161 157 135 122 4YRTST F Josh Hunt 11/19/2024 Second MIT-IA. Lost 350 psi in 15 min but went ahead and finished the test. The well will be shut in after the flowline and well are freeze protected tomorrow. Test showed roughly a 1.5 bbl loss. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 04-13 Inspection Date: Tubing OA Packer Depth 2259 2621 2271 1971IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250127114254 BBL Pumped:BBL Returned:3 Monday, January 27, 2025 Page 1 of 1 9 9 9 9 9 9 999 99 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.27 14:57:06 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, January 27, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 04-13 PRUDHOE BAY UNIT 04-13 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/27/2025 04-13 50-029-20305-00-00 178-031-0 W SPT 8355 1780310 2089 1822 1807 1808 214 178 161 4YRTST F Josh Hunt 11/19/2024 First MIT-IA. Initially lost 348 psi in the first 15 min. They wanted to bump it up and start the timer again at that point (see second test report mitJDH250127114254). 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 04-13 Inspection Date: Tubing OA Packer Depth 549 2607 2259IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH241119155558 BBL Pumped:4.5 BBL Returned: Monday, January 27, 2025 Page 1 of 1 9 9 9 9 9 9 99 99 9 9 9 9 9 First MIT-IA lost 348 psi in the first 15 min James B. Regg Digitally signed by James B. Regg Date: 2025.01.27 14:54:46 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 04-13 (PTD #1780310) failed AOGCC MIT-IA Date:Monday, December 2, 2024 10:20:00 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, November 26, 2024 6:10 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector 04-13 (PTD #1780310) failed AOGCC MIT-IA Mr. Wallace, On 11/24/24 Fullbore performed an offline MIT-IA that failed with a LLR ~0.12 bpm @ 2650 psi. A PPPOT-T and PPPOT-IC passed, indicating the leak is downhole. The well is now classified as NOT OPERABLE until the well barriers are restored. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, November 20, 2024 3:58 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector 04-13 (PTD #1780310) failed AOGCC MIT-IA Mr. Wallace, Injector 04-13 (PTD #1780310) failed its 4-year AOGCC MIT-IA on 11/19/24. The well has been shut- in and freeze protected. It will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostic work. Plan Forward: 1. Fullbore: Offline MIT-IA/Establish LLR 2. Eline: LDL 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG Injector 04-13 (PTD #1780310) failed AOGCC MIT-IA Date:Wednesday, November 20, 2024 8:07:44 AM Attachments:04-13.pdf TIOChart.jpg With corrected TIO chart. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, November 20, 2024 3:58 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector 04-13 (PTD #1780310) failed AOGCC MIT-IA Mr. Wallace, Injector 04-13 (PTD #1780310) failed its 4-year AOGCC MIT-IA on 11/19/24. The well has been shut- in and freeze protected. It will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostic work. Plan Forward: 1. Fullbore: Offline MIT-IA/Establish LLR 2. Eline: LDL 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. TREE = FMC WE-LHEAD= FMC ACTUATOR= AXE -SON KB. E LEV = 64.0 BF. E-EV = 36.6 KOP= 3450' Max Angle = 48' C 7400' Datum MO= 10573' Datum TVD= 8800'SS 13-3/8" CSG, 72#, N-80, D = 12.347" 2692' Minimum ID = 2.80" @ 10459' 3-1/2" D"IS LYNCH LNR SHOE 5-12' TBG, 17#, L-80, .0232 bpf, D = 4.653' 10053' PERFORATIONSUNMRY REF LOG: BHCS ON 04/12/78 ANGLEAT TOP PE2F: 45" @ 10225' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEEPAGE 2 FOR PERF BREAKDOWN PBTD 10782' 9-5/8" CSG, 47#, Ia80, ID=8.681" 10826' 04-13 READINGS SSV 125ppm SAFETY NOTES: WELL WHEN ON MI. WELL REQUIRES A SSSV WHEN ON Ml. 9-518" CSG P6iF'D FROM 2350' - 2352' DURING RIND TO CMT OA. IA & OA HAD BEEN COMM(NCATING. OA CMT'D FROM 2352' TO SURFACE SURFACE., O 2207' 5-12" CAMCO BAL-O SSSV 4.562" 2370' 9-518" FOG 9731' I—j5-12" HESX NP, D=4.562" 9733' —i9-59" X 5-12" BKR S-3 PKR D = 4.750- 9� 5-12" HES XN rP, ID= 4.455" 9930- —ITOP OF BOT PBR ASSE 4BLY 9950' 9-5/8" X 5-12" BOT 3-H 10024' 5-12" BKR GS DEPLOYMENT SUB, D = 3.00" 10040' 5-12" CAMCO DB NO-GO MP, D = 4.313" 10064'—j5-1/2"B0TSOS,D=4.653" 10459' -13-12" DAVIS LYNCH SHOE, D = 2.80" 10460' ELMD TT LOGGED 11/09/95 CAUTION MSC FISH N HOLE BKR R(R ELEM3JT LOST ON 07/10/90 & EP RUBBER ON 09111/01. EXACT DEPTH (1PKNDWPL 1074W j—]SWSBOWSTRNGCENTR UZER DATE REV BY COMMENTS DATE REV BY COMMENTS 04/19/78 ORIGINAL COMPLETION 09/12116 KP/JMD TREE C/O (09/09/16) 06/1185 RW0 09/12/16 JMG/JMD PULLED DSSSV (09/09/16) 01/1895 CTD -RUN / CMT 3-12" LNR 0921116 JMD UPDATED PERF SUMMARY 09101101 RWO 1126M8 LG/JMD CORRECTION TO TBG ID 06/05/08 JWTLH PKR DEPTH CORRECTION 02/09/11 MB/JMD ADDED SSSV SAFETY NOTE PRUDHOE BAY UNIT WELL: 04-13 PERMIT No: 1780310 API No: 50-029-20305-00 SEC 26, TI I N, R15E 33' FSL & 441' FWL Hilcorp North Slope, LLC TREE= FMC WELLHEAD = FMC ACTUATOR= AXE -SON KB. E LEV = 64.0' BF. E LEV = 366 KOP= 3459 Max Angle = 48" CQ2 7409 Datum MD= 10573' Datum TVD= 8800'SS PERFORATION St1MMARY REF LOG: BFI S ON 04/12/78 ANGLE AT TOP PE RF: 45" @ 10225' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" .25 10225 - 10245 S 12/30/94 3-3/8" .60 10252 - 10262 S 12/30/94 3-3(8" .60 10277 - 10287 S 12/30/94 3-3/8" .20 10296 - 10316 S 12/30/94 3-3/8" .20 10325 - 10345 S 12/30/94 3-3/8" .25 10360 - 10375 S 12/30/94 3-318" .50 10390 - 10440 S 12/30/94 2-1/7 6 10464 - 10478 O 11/10/01 2-11T 6 10464 - 10486 O 11/10/01 3-W8" .25 10512 - 10522 S 12/30/94 3-3/8" .25 10570 - 10610 S 12/30/94 3-WB" .25 10630 - 10666 S 12/30/94 3-3(8" 6 10678 - 10685 S 12/30/94 3-3(8" 6 10694 - 10703 S 12/30/94 3-318" 6 10714 - 10724 S 12/30/94 04-13 DATE REV BY COMMENTS DATE REV BY COMMENTS 04/19/78 ORIGINAL COMPLETION 09/12/16 KP/JMD TREE C/O (09/09/16) 06111165 RWD 09/12/16 JMG/JMD PULLED DSSSV (09109/16) 0111B95 CTD -RUN / CMT 3-12" LNR 0921/16 JMD UPDATED PERF SUMMARY 09101101 RWD 1126118 LG/JMD CORRECTION TO TBG ID 06/05/08 JM/TLH PKR DEPTH CORRECTION 02/09/11 MB/JMD ADDED SSSV SAFETY NOTE PRUDHOE BAY UNIT WELL: 04-13 PERMIT No: 1780310 API No: 50-029-20305-00 Hilcorp North Slope, LLC Wei I-04-13 300 280 260 240 220 200 180 m 160 v 140 m a 120 m 100 80 fi0 40 20 0&&20124 02i27..24 09+0124 091024 09.1117.24 09.2424 1001124 10+0&24 101524 107224 1&29.+24 11AW4 1T112,24 1V19,24 TIO Plot f Tubing — On ■ Bleed * Operable + Not Oper ♦ Under Eval — Man. IA —A Man.OA Man. OOA Man. OOOA n Man. WHT MEMORANDUM TO:gg Jim Re P.I. Supervisor I 71rt Z I �+7t% FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, November 12, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 04-13 PRUDHOE BAY UNIT 04-13 Src: Inspector Reviewed By: P. I. Supry/,'-- Comm Well Name PRUDHOE BAY UNIT 04-13 API Well Number 50-029-20305-00-00 Inspector Name: Guy Cook Permit Number: 178-031-0 Inspection Date: 11/8/2020 . Insp Num: mitGDC201108063257 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 04-13 Type Inj W "TVD 8355 Tubing 1115 1116 1111 1112 - PTD 1780310 Type Test SPT Test psi 2089 IA 650 2325 2300 - 2294 BBL Pumped: 3 - BBL Returned: 3 OA o 0 0 0 Interval) 4YRTST p/F P Notes: Testing completed by a Little Red Services pump truck and calibrated gauges. wr�C�./��JJJ.I�-✓�. Swce- Thursday, November 12, 2020 Page 1 of I Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Tuesday, November 3, 2020 7:23 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Bo York; Aras Worthington; Oliver Sternicki Subject: OPERABLE: Injector 04-13 (PTD #1780310) ready for Injection, needs AOGCC MIT -IA Mr. Wallace, Injector 04-13 (PTD #1780310) was shut in and missed its required 4 -year AOGCC MIT -IA in May 2020. The well is now operationally ready for injection and will be classified back to OPERABLE. Once on stable injection, an AOGCC witnessed MIT -IA will be performed. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/Compliance andrew.ogg@hilcorp.com P:(907)659-5102 M:(307)399-3816 From. K, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com> Sent: Sun May 10, 202012:44 PM To: 'Begg, Jame (DOA) Qim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpeciali @bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Alk, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@ com>; Alk, OPS FS2 Field PTL <AKOPSFS2FieldPTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS2OSM1@bp.com>; RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPB tWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; ' hards, Meredyth <Meredyth.Richards@bp.com>; Rupert, C. Ryan <Rya n. Rupert @ B P. co m> Cc: 'chris.wal lace @a laska.gov' <chris.waIlace @a a.gov>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO SUPT Integrity <AKDCWeIIlntegrityCoordinator@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com KIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp. >; Dempsey, David G <David.Dempseyl@bp.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Smith, Travis T (CONO PHILLIPS) <travis.smithl@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthin n@bp.com> Subject: NOT OPERABLE: Injector 04-13 (PTD #1780310) Missing AOGCC MIT- All, IT-AII, Injector 04-13 (PTD # 1780310) is due for a regulatory compliance MIT -IA in May 2020. The we ' shut in with no near term plans to put on injection. It will now be classified as NOT OPERABLE and will require an AOGC IT -IA when injection resumes. Please respond with any questions. Ryan Holt Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, May 10, 2020 12:44 PM To: Regg, James B (CED); AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; G GPB FS2 Drillsites; Richards, Meredyth; Rupert, C. Ryan Cc: Wallace, Chris D (CED); AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Janowski, Carrie; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Worthington, Aras J Subject: NOT OPERABLE: Injector 04-13 (PTD #1780310) Missing AOGCC MIT -IA All, Injector 04-13 (PTD # 1780310) is due for a regulatory compliance MIT -IA in May 2020. The well is shut in with no near term plans to put on injection. It will now be classified as NOT OPERABLE and will require an AOGCC MIT -IA when injection resumes. Please respond with any questions. Ryan Holt Well Integrity BP Global Wells Organization - Alaska Office: 907-659-5102 BAJCER 4#• PRINT DISTRIBUTION LIST UGHES FINAL a GE company FINAL COMPANY BP Exploration Alaska Inc. WELL NAME 04-13 FIELD Prudhoe Bay Unit COUNTY PRUDHOE BAY BHI DISTRICT Alaska AUTHORIZED BY Paul Canizares EMAIL Paul. Canizares(cDbhge.com 176031 30 19 0 Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, 1_132-1 900 E. Benson Blvd. Anchorage, Alaska 99508 or AKGDMINTERNAL@bp.com to acknowledge receipt of this data. LOG TYPE RPM:PNC3D LOG DATE November 22, 2019 TODAYS DATE January 3, 2019 Revision STATUS Final Replacement: No Details: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION 4 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aides Attn: Benda Glassmaker & Peggy O'Neil 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 3-344 700 G Street Anchorage, AK 99501 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Lisa Boggs 3201 C Street, Suite 505 Anchorage, AK 99503 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *** Attn: Garret Brown 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 * Stamp "confidential" on all nmterial deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR24 900 E. Benson Blvd Anchorage, Alaska 99508 Attn: Gerardo Cedillo TOTALS FOR THIS PAGE: Rev. Requested by: --- FIELD / FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, I SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS #UFHKIN161 # OF COPIES # OF COPIES J#OFCOPIES 1 1 0 1 4 `� 0 0 M • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,May 31,2016 Jim Regg yy P.I.Supervisor l et L (l to SUBJECT: Mechanical Integrity Tests (RCI " BP EXPLORATION(ALASKA)INC. 04-13 FROM: Bob Noble PRUDHOE BAY UNIT 04-13 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-13 API Well Number 50-029-20305-00-00 Inspector Name: Bob Noble Permit Number: 178-031-0 Inspection Date: 5/26/2016 Insp Num: mitRCN160526164808 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 04-13 'Type Inj G 'TVD 8355 Tubing) 2220 2224 ' 2224 - ' 2227 PTD 1 1780310 Type Test SPT Test psi 2089 • IA 440 2797 - 2756 2738 Interval 4YRTST P/F P / OA 610 781 870 907 Notes: s NtiEa 0 Tuesday,May 31,2016 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon L Repair Well L Plug Perforations L Perforate L Other ' Brightwater Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well[] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Developmert❑ Exploratory ❑ Stratigraphic❑ Service ❑� 178-031-0 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-20305-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028325 PBU 04-13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: R E C E I V E Total Depth measured 10845 feet Plugs measured None feet true vertical 8992.82 feet Junk measured See Attachment feet 0 C T 2 7 2014 Effective Depth measured 10782 feet Packer measured See Attachment feet true vertical 8947.51 feet true vertical See Attachment feet AO�.�I�V Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 83 20" 94# H-40 29-112 35-110 1530 520 Surface 2664 13-3/8" 72# L-80 28-2692 8352.11 - 8352.94 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 435 3-1/2" 9.3# L-80 10024 - 10459 8063.48 - 8508.86 10160 10530 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10464'-10685' SCANNED NOV 0 4 2014 Treatment descriptions including volumes used and final pressure: 6200GALS EC9360A SURFACTANT, 30000GALS EC9398A POLYMER 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 5650 26814 0 0 1514 Subsequent to operation: 401 24765 1727 0 232 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service ❑✓ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil L Gas L WDSP GSTOR ❑ WINJ ❑✓ WAG ❑ GINJ ❑ SUSP ❑ SPLUC[:] 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 Nita Summerhays Email Nita. Summerhays(a)bp.com Printed Name Nita Summerhays Title Petrotechnical Data Engineer Sign Phone 564-4035 Date 10/27/2014 �0/3o�lf- Form 10-404 Revised 10/2012 RRC MS OCT 2 8 2 Submit Original Only Daily Report of Well Operations ADL0028325 Prightwater I rea men aging equipment and rigging up. 9/29/2014 ***WSR continued to 9-30-14*** continued from 9-29-14777 rig a er treatment Standing by for chemical 9/30/2014 ***WSR continued to 10-1-14*** continued from 9-30-14— rig a er I reatment (RESERVOIR SWEEP MOD) Pumping brightwater chemicals down TBG while well was on water injection -18000BWPD Pumped 890 gallons of EC9360A Surfactant Pumped 4098 gallons of EC9398A Polymer 10/1/2014 ***WSR continued to 10-2-14*** continued from 10-1-14— rig a er I reatment (RESERVOIR SWEEP MOD7 Pumping Brightwater chemicals down TBG while well is on water injection 18000 BWPD Pumped 3288 gallons EC9360A Surfactant Total of 4450 gallons since the start of this project Pumped 16392 gallons EC9398A Polymer Total of 21856 gallons since the start of this project 10/2/2014 ***WSR continued to 10-3-14*** continued from 10-2-13 rig a er Treatment Pumped Brightwater chemicals down TBG while well is on water injection @ -V18000 BWPD. ***Establishing true pump rates with proving pots*** Pumped 1750 gals of EC9360A surfactant, total of 6200 gals for job. Pumped 8144 gals of EC9398A polymer, total of 30,000 gals for job. Final WH Ps 1100/180/180 SV = C. WV, SSV, MV = O. IA & OA = OTG 10/3/2014 FLUIDS PUMPED GALS 6200 EC9360A SURFACTANT 30000 EC9398A POLYMER 36200 TOTAL AB ABANUUNEU MIR Perforation Attachment APF ADD PERF MIS MECHANICAL ISOLATED BPP ADL0028325 MLK MECHANICAL LEAK BPS SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 04-13 7/25/2008 BPP 10225 10245 8553.57 8567.69 04-13 7/25/2008 BPP 10252 10262 8572.63 8579.68 04-13 7/25/2008 BPP 10277 10287 8590.26 8597.3 04-13 7/25/2008 BPP 10296 10316 8603.64 8617.72 04-13 7/25/2008 BPP 10325 10345 8624.05 8638.11 04-13 7/25/2008 BPP 10360 10375 8648.65 8659.17 04-13 7/25/2008 BPP 10390 10440 8669.7 8704.7 04-13 7/25/2008 BPP 10464 10474 8721.44 8728.41 04-13 7/25/2008 BPP 10474 10478 8728.41 8731.19 04-13 7/25/2008 BPP 10478 10486 8731.19 8736.76 04-13 7/25/2008 BPP 10512 10522 8754.84 8761.82 04-13 7/25/2008 BPP 10570 10610 8795.58 8824.03 04-13 7/25/2008 BPP 10630 10666 8838.32 8864.1 04-13 7/25/2008 BPP 10678 10685 8872.71 8877.74 04-13 7/25/2008 BPP 10694 10703 8884.21 8890.68 04-13 7/25/2008 BPP 10714 10724 8898.59 8905.78 AB ABANUUNEU MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing / Tubing Attachment ADL0028325 Casing Length Size MD TVD Burst Collapse CONDUCTOR Length 20" 94# H-40 29 - 112 35 - 110 1530 520 LINER 3-1/2" 9.3# L-80 10024 - 10459 8063.48 - 8508.86 10160 10530 PRODUCTION 9-5/8" 47# R -S-95 27 - 2344 8365.35 - 9114.64 8150 5080 PRODUCTION 9-5/8" 47# N-80 2344 - 7806 2087.91 - 2088.91 6870 4760 PRODUCTION 9-5/8" 47# R -S-95 7806 - 10079 8199.15 - 8199.99 8150 5080 PRODUCTION 9-5/8" 47# N-80 10079 - 10120 8236.98 - 8237.82 6870 4760 PRODUCTION 9-5/8" 47# R -S-95 10120 - 10825 8323.89 - 8324.72 8150 5080 SURFACE 13-3/8" 72# L-80 28 - 2692 8352.11 - 8352.94 4930 2670 TUBING 5-1/2" 17# L-80 26 - 9926 8370.3 - 8371.13 7740 6280 TUBING 5-1/2" 17# L-80 9930 - 10054 33 - 8485.37 7740 6280 Packers and SSV's Attachment ADL0028325 SW Name Type MD TVD Depscription 04-13 PACKER 9739 8135.25 5-1/2" BAKER S-3 PACKER 04-13 PACKER 9950 8291.39 5-1/2" BOT 3-H PACKER TRFF = r -Q WELLHEAD = GRAY ACTUATOR = AXELSON KB R EV = 64.9 BF ELEV = 36.5' KOP = 3450 Max Angle = 48' @ 7409!, Datum MD = 10573'1 Datum TV D = 8800' SS'' 13-3/8" CSG, 72#, N-80, ID = 12 347' H 2692' Minimum ID = 2.80" @ 10459' 3-1/2" DAVIS LYNCH LNR SHOE TOP OF LOCATOR SEAL ASSY ID = 2 875" 1-I 9922' TOP OF 3.1/2" LNR 9.3#, ID = 2 992' H 10027' 5-1/2" TBG. 17#, L-80, .0232 bpf, ID = 4 892" 1—{ 10053' PERFORATION SUMMARY REF LOG BRCS ON 04/12!78 ANGLE AT TOP PERF 45'@10225' Note. Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE RWO CMT'D FROM 2352' TO SURFACE SEE PAGE 2 O2207—�5-1/2 CTD- RUN I CMT 3-112" LNR 02/09/11 CAIVICO BAL-O SSSVN, ID = 4.562" FOR PERF RWO 01/10/12 TMIN/JMD ADDED H2S SAFETY NOTE 10/05/01 2370' 9-5/8" FOC BREAKDOWN 11/11/01 I PBTD 9-5/9' CSG, 47#, N-80. ID = 8.681" 10782' 10826' 04-13 SAFETY NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON MI. DATE 9-5/8" CSG PERF'D FROM 2350' - 2352' DURING RWO TO 04/1988 CMT OA. IA & OA HAD BEEN COMMUNICATING. OA 06/11/02 CJS/TLH PERF CORRECTIONS 06111/85 RWO CMT'D FROM 2352' TO SURFACE _ JWTLH PKR DEPTH CORRECTION O2207—�5-1/2 CTD- RUN I CMT 3-112" LNR 02/09/11 CAIVICO BAL-O SSSVN, ID = 4.562" 09/01/01 RWO 01/10/12 TMIN/JMD ADDED H2S SAFETY NOTE 10/05/01 2370' 9-5/8" FOC 11/11/01 JLG/KAK I PEWS 2496' 9-5/8" FOC 9731' —15 -tit" HES X NIP, ID = 4.562" 9733' 9-5/8" X 5-1/2" BKR S-3 PKR, ID = 4 750" 9778' 57/2' HES XN NIP, ID = 4.455" 9930' —i TOP OF BOT PBR ASSEMBLY 9950' 9-5/8" X 5-1/2" BOT 3-H PKR, ID = 4 750" 10024' -- 5-1/2" BKR GS DEPLOYMENT SUB, ID = 3 00" 10040' 5-1/2" CAMCO DB NO-GO NIP, ID = 4 313" 10054' j- j 5-1 /2" BOT SOS, ID = 4 892" 10457' —13-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992' 10459' 3-1 /2" DAVIS LYNCH SHOE, ID= 280" 10460' ELMD TT LOGGED 1 i /09/95 CAUTION MSC FISH IN HOLE BKR PKR / ELEMENT LOST ON 07/10/90 & IBP RUBBER ON09/11/01 EXACT DEPTH UNKNOWN 10743' SWS BOWSTRING CENTRALIZER (10/01/90) DATE REV BY COMMENTS DATE REV BY COMMENTS 04/1988 ORIGINAL COMPLETION 06/11/02 CJS/TLH PERF CORRECTIONS 06111/85 RWO 06/05/08 _ JWTLH PKR DEPTH CORRECTION 01118195 CTD- RUN I CMT 3-112" LNR 02/09/11 MB/JMD ADDED SSSV SAFETY NOTE 09/01/01 RWO 01/10/12 TMIN/JMD ADDED H2S SAFETY NOTE 10/05/01 1 CWKAK CORRECTIONS 11/11/01 JLG/KAK I PEWS PRUDHOE BAY UNIT WELL. 0413 PERMIT No '1780310 AR No 50-029-20305-00 SEC 26, T11 N, R15E 33' FSL & 441' FWL BP Exploration (Alaska) TREEt GRAY 04-13 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV - 64 0 BF. ELEV = 36 5' KOP = 3450' Max Angle = 48° @ 7400' Datum MD = 10573' Datum TVD = 8800 SS PERFORATION SUMMARY REF LOG. BHCS ON 04/12/78 ANGLE AT TOP PERF 45'@10226 Note. Refer to Produchon DS for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 3-31W 25 10225 - 10245 S 12/30/94 3-3/8" 60 10252- 10262 S 12/30/94 3-3/8" 60 10277 - 10287 S 12730/94 3-3/8" 20 10296 - 10316 S 12130/94 3-3/8" 20 10325 - 10345 S 12!30/94 3-3/8" 25 10360 - 10375 S 12/30/94 3-3/8" 50 10390 - 10440 S 12/30/94 2-12" 6 10464 - 10478 0 11/10/01 2-1/7' 6 10464 - 10486 0 0923/01 3-3/8" 25 10512 - 10522 0 09/02/95 3-3/8" 25 10570 - 10610 0 09/02/95 3-3/8" 25 10630 - 10666 0 09/02/95 3-3/8" 6 10678 - 10685 O 09/02/95 3-3/8" 6 10694 - 10703 C 12/22!94 3-3/8" 6 10714 - 10724 C 12/22/94 PERFS DATE REV BY COMMENTS DATE REV BY COMMENTS 04/19178 ORIGINAL COMPLETION 06/11/02 CJS/TLH PFRF CORRECTIONS 06/11185 RWO 06/05/08 JIWTLH PKR DEPTH CORRECTION 01/18/95 CTD- RUN/ CMT 3-112" LNR 02/09/11 MB/JMD ADDED SSSV SAFETY NOTE 09/01101 RWO 01/10/12 TMN/JMD ADDED H2S SAFETY NOTE 10/05/01 1 CWKAK CORRECTIONS 11 11/11/01 1 JLG/KAK I PERFS i PRUDHOE BAY UNIT WELL 04-13 PERMIT No `1780310 API No 50-029-2030500 SEC 26, T11 N, R15E 33' FSL 8 441' FWL BP Exploration (Alaska) 193L-k, 04- r3 Pit (- 031c, Rig, James B (DOA) From: AK, OPS FF Well Ops Comp Rep [AKOPSFFWeIIOpsCompRep @bp.com] Sent: Tuesday, June 04, 2013 12:01 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay (� /4 (13 Subject: FW: PBU/East Area/FS2/04 defeated pilots Mr. Regg, Here is the info you requested on the DS-4 water injectors that were temporarily SI yesterday for pigging operations. Well PTD 04-06 1760830 04-08 1760100 04-10 1760420 (04-13 1780310 -/) 04-15 1780370 04-20 1831190 SGAN�ED 04-25 1860490 04-27 1852950 04-45 1940340 I apologize for the time delay since the initial email was sent. I will have this data available for future notification emails since I now know it is required. Thank you, Lee Hulme From: AK, OPS FS2 DS Ops Lead Sent: Tuesday, June 04, 2013 8:35 AM To: AK, OPS FF Well Ops Comp Rep Cc: AK, OPS FS2 Facility OTL; AK, OPS FS2 OSM Subject: RE: PBU/East Area/FS2/04 defeated pilots Lee, All of the PWI wells are gagged during pigging operations in order to prevent inadvertent blocked flow and a stuck pig.— This is how we always pig and how we will always pig every week in the future. It is a manned operation. The wells gagged yesterday were DS4-6,8,10,13,15,20,25,27,19,45. Ron White Ak, Ops FS2 DS Lead 907-659-5493 Alt: James Barndt From: AK, OPS FF Well Ops Comp Rep Sent: Tuesday, June 04, 2013 7:43 AM To: AK, OPS FS2 DS Ops Lead Cc: Regg, James B (DOA); Redmond, Randy; AK, OPS FF Well Ops Comp Rep 1 Subject: FW: PBU/East Area/FS2/04 defeated pilots Importance: High Ron, Please supply me with a list of the water injectors on DS-04 that were defeated during the pigging operations yesterday so I can look up the PTD numbers and pass on to Mr. Regg. Thanks, Lee From: Regg, James B (DOA) [mailto:jim.recgg @alaska.gov] Sent: Monday, June 03, 2013 9:08 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU/East Area/FS2/04 defeated pilots Our approvsl only covers injectors. And yes, I want a record of the injectors involved. Particularly since it is DS 4. Sent from Samsung Mobile Original message From: "AK, OPS FF Well Ops Comp Rep" <AKOPSFFWellOpsCompRep @bp.com> Date: 06/03/2013 6:32 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg @alaska.gov> Subject: RE: PBU/East Area/FS2/04 defeated pilots Mr. Regg, I just called the FS2 Field Lead Tech and he told me the pigging operation is completed and the temporary defeat for PWI wells has been lifted. It will take some research to determine which wells were involved since the DSD log blanketed the whole pad. I can get this data tomorrow if you still want it. Please advise. Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony—7187 (Alternate: Ryan J Hayes) From: Regg, James B (DOA) [mailto:jim.reqg©alaska.gov] Sent: Monday, June 03, 2013 5:01 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU/East Area/FS2/04 defeated pilots Please identify wells and PTD for each. Jim Regg AOGCC 2 333 W.7th Ave,Suite 100 Anchcyrage,AK 99501 907-793-1236 From: AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWellOpsCompRep @bp.com] Sent: Monday, June 03, 2013 4:25 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Redmond, Randy; AK, D&C Well Integrity Coordinator; Bill, Michael L(ASRC); Starck, Jennifer L; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, RES GPB East Wells Opt Engr Subject: PBU/East Area/FS2/04 defeated pilots Dear Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that wells on DS-04 are now operating with its SVS defeated as of 6/3/13 for pigging operations. Per the wavier, BPXA has tagged and logged the defeated components, and will notify AOGCC once the SVS is returned to service. Please contact me with any questions. Thank you, Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony-7187 (Alternate: Ryan J Hayes) 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE: Wednesday, August 08, 2012 P.I. Supervisor RCll �� SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04-13 FROM: Jeff Jones PRUDHOE BAY UNIT 04-13 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprvl� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-13 API Well Number 50-029-20305-00-00 Inspector Name: Jeff Jones Permit Number: 178-031-0 Inspection Date: 7/10/2012 lnsp Num: miUJ120730182013 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min — ell 04-13 ,]Type Inj W' TVD 8355 IA sos 2410 - 2354 2331 - TD 1780310 Type Test i SPT Test psi 2088 OA 458 390 430 571 Interval 4YRTST P/F P Tubing 757 750 745 765 - Notes: OA cemented to surface. 1 well inspected, no exceptions noted ✓ SCANNED K i 10 2014 Wednesday, August 08, 2012 Page I of I Brooks, Phoebe L (DOA) PTI) 179)0310 From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, July 31, 2012 4:10 PM To: Brooks, Phoebe L (DOA) Subject: RE: Missing MITs Attachments: 04 -09 (PTD #1760300) wellbore schematic.pdf; 04 -13 (PTD #1780310) wellbore schematic.pdf Phoebe, Both of the wells have a stacked packer in them, with your depth being related to the lower one, and the upper packer being related to the depth on the form. If I need to change to reflect the lower packer, please let me know, otherwise the depth on the form is currently the highest packer in the well. •• • , Please let me know how I can be of further assistance. Jerry Murphy BPXA Well Integrity Coordinator SCANNED MAY 0 7 2013 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks @alaska.gov] Sent: Tuesday, July 31, 2012 3:49 PM To: AK, D &C Well Integrity Coordinator Subject: RE: Missing MITs Jerry /Mehreen, Will you please send me the schematics for wells 04 -09 and 04 -13? The Packer TVD that we have in our database differs from what is on your report (for 04 -09 we have a MD of 10711' with a TVD of 8064' and for 04 -13 we have a MD of 9950' with a TVD of 8355'). Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907 - 793 -1242 Fax: 907-276-7542 From: Wallace, Chris D (DOA) Sent: Tuesday, July 31, 2012 7:25 AM To: Brooks, Phoebe L (DOA) Subject: FW: Missing MITs Phoebe, Can you please look for these records and see if we have these MIT's and try to establish the timeline of information flows into AOGCC. Thanks, Thanks and Regards, Chris Wallace 1 TREE= GRAY SAFETY NOTES: H2S READINGS AVERAGE 125 ppm VELLHEAD = GRAY WH ON MI. WEZ.L REQUIRES A SSSV WHEN ON MI. ACTUATOR = AXELSON 04-1 3 EN 9-5/8" CSG PERF'D FROM 2350' -2352' DURING RWO TO KB. ELEV = 6 ci CMT OA. IA & OA HAD BEEN COMMUNICATING. OA BF. ELEV = 36 5 7 4 MI 4 CMT'D FROM 2352' TO SURFACE KOP = 3450' .. 2207' 4 MIMI $ Max Angle = 48° st■ 7400' F4 " ,,,,, H5-1/2" CANICO BAL-0 SSSVN,IY5 Datum MD = 10573 it 0 70 Datum = 8800' SS 2370' 9-518" FOC MGM 9-5/8" FOC 13-3/8" CSG, 72#, N-80, ID = 12.347" H 2692' I — ■ Minimum ID = 2.80" @ 10459' 3-112" DAVIS LYNCH LNR SHOE 9731 —15-1/2" HES X NIP, ID = 4.567' I .3....■ lc. 9733' 1— 9-5/8" X 5-1/2" BKR S-3 PKR, ID = 4.750" 1 II 9778' —15-1/7 HES XN NIP, ID = 4 455" TOP OF LOCATOR SEAL ASSY , ID = 2.875" 9922' I 9930' HTOP OF BOT FBR ASSEMBLY 1 1 lii •-c. ,,,,,, 9950 —19-5/8" X 5-1/2" BOT 3-H PKR, ID = 4,750 1 I. 10024' H5-1/2" BKR GS DEPLOYMENT SUB, ID = 3,00° 1 TOP OF 3- 1 a. LNR 9.3#, ID= 2.992' H 10027' 1 m — 10040' H5-1/2" CAMCO DB NO-GO NIP, ID = 4.313" 1 1 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" H 10053' 10054' H5-1/2" BOT SOS, ID = 4.892" . 1 1° Ir 1* 11 41 •W '• • • 141 1.11 114 PERFORATION SUMMARY '41. 100 1**1 144 '01* 110 REF LOG: BI ON 04/12/78 1 1101 1.4 /0 0** ANGLE AT TOP FERF: 45° @ 10225' 'm ## • 4 11 • Note: Refer to Production DO for historical pert data 4* • 10457' H3-1/2" LNR, 9.3#, L-80, 0087 bpf, ID = 2.997' 1 SIZE SPF ' INTERVAL 1 Opn/Sqz DATE 'it.tt VA! SEE PAGE 2 10459' 1 DAVS LYNCH SHOE, ID = 2.80" FOR PERF I 1 10460' HELMD TT LOGGED 11/09/95 1 BREAKDOWN . , , „ , .. CAUTION: MSC FISH IN HOLE BKR PKR ELEMENT LOST ON 07/10/90 & IBP RUBBER I ON 09/11/01. EXACT DEPTH UNKNOWN. ill ' ■1 L10743' i_ SVVS BOWSTRING CENTRA LEER (10/01/90) 1 ' 1PBTD 1 '10782' 7............. • ■111.4/111/11 6,1,0,•,1,1,.,0,0 CSG, 47#, N-80,10= 8.681" — 10826' '"-------- i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/19/78 ORIGINAL COMPLETION 06/11/02 CJS/TLH PERF CORRECTIONS WELL: 04-13 06/11/85 RWO 06105/03 JM'TLH PKR DEPTH CORRECTION PERMIT No: '1780310 01/18195 CT D - RUN I CMT 3-1/2" LNR 02109/11 N13/JMD ACOF_D SSSV SAFETY NOTE AR No: 50-029-20305-0O 09101101 RWO 01/10112 TWN/JMD ADOED H2S SAFETY NOTE SEC 26, T11N, R15E 33' FSL & 441' FWL 10/05/01 CHIKAK CORRECTIONS 11/11/01 JLG/KAK PERFS :.• Exploration (Alaska) TREE = GRAY 04-1 3 WELLHEAD = GRAY KB.ELEV= 640' ACTUATOR = AXELSON P ; F S KOP = 3450' 4 11 _____ _____ •• Max Angle = 48° @ 7400' .• Datum MO= 10573' Datun1 TVD = way ss PERFORATION SUMMARY IMO REF LOG: BHCS ON 04/12/78 ANGLE AT TOP PERF 45° @ 10225' Note: Refer to Production DB for historical pert data SIZE SFF INTERVAL Opn/Sqz DATE 3-3/8" r 25 10225 - 10245 S 12/30/94 I 3-3/8"' 60 10252 - 10262 S 12/30/94 1133 3-3/8" ' 6 0 10277 - 10287 S 12/30/94 3-3/8" ' 20 10296 - 10316 S 12/30/94 3-318" 20 10325 - 10345 S 12/30/94 3-3/8" ' 2 5 10360 - 10375 S 12/30/94 I 3-3/8" ' 50 10390 - 10440 S 12/30/94 2-1/2" 6 10464 - 10478 0 11/10/01 2-1/2" 6 10464 - 10486 0 09/23/01 3-3/8" r .25 10512 - 10522 0 09/02/95 3-3/8" " 2 5 10570- 10610 0 09/02/95 3-3/8" ' 25 10630 - 10666 0 09/02/95 3-3/8" 6 10678 - 10685 0 09/02/95 4 4 4 4 # 4 94' 3-3/8" 6 10694 - 10703 C 12/22/94 . 4••. 3-3/8" 6 10714 - 10724 C 12/22/94 441 1 1 4 4 4 14 44 4 Mt 1 14 4 4, I 4 1••• P at I I I 4111114 V O Ovff• Ov ••• #* • • ** * ##•••••••• 14.4.4.44.....114.4. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04119178 ORIGINAL COMPLETION 06/11/02 C.JS/TLH PERF CORRECTIONS WELL 04-13 06111185 RWO 06/05/08 JM/TLH PKR DEPTH CORRECTION , FERMIT No: '1780310 01118/95 CT D - RUN / CMT 3-1/2" LNR 02/09/11 MB/JMD ADDED SSSV SAF EN NOTE API No: 50-029-20305-00 09/01101 RWO 01/10/12 TMN/JMD ADDED H2S SAFETY NOTE SEC 26, T11N, RISE 33' FSL & 441' FVVL 10/05/01 Cli/KAK CORRECTIONS 11/11/01 JLG/KAK PERFS , BP Exploration (Alaska) 1VIElVi®12A1l1DUl0~I TOE Jim Regg P.I. Supervisor ~ r~ ~r, ~Y FROM: Chuck Scheve Petroleum Inspector State ®f Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 23, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04-13 PRUDHOE BAY UNIT 04-13 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name• PRUDHOE BAY UNIT 04-13 Insp Num: mitCS080722 1 940 1 1 Rel Insp Num: API Well Number' S0-029-20305-00-00 Permit Number: t78-o31-o Inspector Name' Chuck Scheve Inspection Date: 7i22i2oo8 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04-13 Type Inj. ~ N TVD 8195 - IA 20 ~ 4000 ~ 3900 3880 P.T. 1780310 TypeTest SPT Test psi 2048.75 OA 20 30 30 30 Interval 4YRTST P~, P '~ Tubing 140 ~ 280 280 260 ~ Notes: ~~~~~ A~lu ~~ =~ 200$ Wednesday, July 23, 2008 Page I of l RE: 03-10 (PTD #1790210), 04-08 (PTD #17.0), R-25A (PTD ... . Subject: RE: 03-10 (PTD #1790210),04-08 (PTD #1760100), R-25A (PTD #1972300), 04-13 (PTD #1780310), Pl-25 (PTD #2060530), S-101 (PTD #2001150), NK-13 (PTD #1961340) MIT Forms From: "Hughes, Andrea" <hugha4@BP.com> \o\t\0& Date: Sun, 01 Oct 200616:26:12 -0800 ~ut1 \~<f>' D3 (J"ù ....\~ otx Jim, We are not surprised by the OA response noted during the MITIA on 08/10103. The OA fluid level was found at surface. The TIO plot immediately after the test indicated potentiallAxOA communication, so the OAP was bled to 10 psi on 9/25/04. Since the bleed took such a short time, it appears that fluid was bled off. This would explain why the OA showed little pressure response from that point on. 9/25/2004 T/I/O=1280/3801200. Temp=Hot. Bleed OAP & Monitor. (Eval if IAxOA comm exists.). OA FL @ Surface. Bled OAP from 200 psi to 10 psi in 15 min. Final WHP's= 1280/380/10. v/ 9/27/2004 T/IIO=1280/380110. Temp=Hot. MonitorWHPs (post OAP bleed) (day 2). No change in OAP. The only work on the well between the test and now was a Schmoo treatment 8/14/06 and the OA bleed ../ seen above. I have included a TlO plot from the test date forward and a 1-year injection plot covering a WAG cycle. Please let me know if I have not provided enough information. Thank you, Andrea Hughes (Filling in for Anna Dube) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 .. "r 1 ,,>"~ :SC~~~;·h~.¡t;1!; r;~. F)r,nc: tj,¡) ""u......J ..:"Y From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Friday, September 29,20063:13 PM To: Hughes, Andrea Cc: Winton GAubert; bob_fleckenstein@admin.state.ak.us; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: Re: 03-10 (PTD #1790210),04-08 (PTD #1760100), R-25A (PTD #1972300), 04-13 (PTD #1780310), Pl-25 (PTD #2060530), S-101 (PTD #2001150), NK-13 (PTD #1961340) MIT Forms ~: PBU 04-13 (PTD 1780310)) You priovided an MIT done on 8/1012003 for PBU 04-13. There was a significant pressure increase in the OA (from 200 psi initial to 1000 psi) during the 30 minute test that gives the appearance of an lof4 10/2/2006 9:23 AM - - ,- - ~ - < ~ ~ . H __.. \' . ~ . ~'~ .?, } Winton, Jim and Bob, Please see the attached MIT forms for the following wells: ,/ PBU 03-10: CMIT-IAxOA for Waiver compliance'! ?Æ.C' / n , PBU 04-08: MITIA to evaluate the well for an IAxOA AA and waiver .../,--PBU R-25A: MITrA Pre-dewatering ! ! Z¿::2~';: ;- /PBU 04-13: MITIA Pre MI swap ';'1 z¿~;;.~ :::5, /PBU P1-25: MITIA Pre MI swap cd '5/~l c;!< " /"'"::;.:> /'PBU S-101: MITIA Pre MI swap 1\ \'23 i 2,"(;3 J' 5.;';" ,,/PBU NK-13: MITIA for UIC Compliance, Chuck Scheve witnessed ~"" / /ifhe MIT form for PBU X-36 (PTD #1961670) was emailed by Anna Dube on 9/10/06. If you need an additional copy or did not receive the email, I will gladly send it again. Thank you for your patience. «MIT PBU 8-101 11-23-03.xls» «MIT GPMA P1-25 09-06-06.xls» «MIT PBU 04-13 08-10-03.xls» «MIT PBU 04-08 08-04-05.xls» «MIT PBU R-25A 06-12-05.xls» «MIT PBU 03-10 09-30-05.xls» «MIT PBU NK-13 09-19-06.xls» ".. -" Andrea Hughes (Filling in for Joe Anders) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~CANNED SEP 2 92DD5 Hi Jim, Thank you for the note. To update you on MITs that are past due: 1) PBU 04-13; due 1/8/2006 Completed 8/10/03 2) PBU S-101; due 2/25/2006 Completed 11/23/03 3 ) PBU NK-13; due 5/4/2006 Completed 9/Ð/06 ;,./4) PBU X-36; due 5/20/2006 Completed 9/5/06 - Sent in earlier e-mail 5) PBU R-25A; due 7/24/2006 Completed 6/12/05 We agree to schedule MITs on the following wells once on injection: 10f4 9/25/2006 9: 15 AM ·~\'._ "/~_'_I''''V~\..~".,~v.n~~''\..~ '/... 1) MPU H-06¡ due 2/28/2006 (S1 Slnce 7/2002) returned to injection 2) PBU WG1-01¡ due 4/22/2006 (S1 since 12/12/2005) Sidetrack later this year 3) MPU F-41¡ due 5/14/2006 (S1 since 5/2005) returned to injection ~ 4) PBU S-31A¡ due 6/1/2006 (S1 since 12/2004) Schedule post Rig Workover ~ 5) PBU P1-01¡ due 6/4/2006 (S1 since 6/2006 for workover) A patch to restore integrity is planned. Scheduel when returned to injection . Schedule when Schedule post Rig Schedule when J 6) PBU Pl-25¡ due 7/2/2006 (S1 since 6/2006) 7) PBU GC-02C¡ due 7/22/2006 (SI since 4/2006) returned to injection, estimated some time in '07. Completed 9/6/06 Schedule when Others /1) PBU 03-10; MIT 9/30/2005 (CMIT 1AxOA) 2) PBU 04-08¡ MITs (IA and OA) doneper monthlyinjector rpt¡ date unknown- this well is currently SI with an AA and Waiver being drafted. I apologize for this office dropping the ball on these wells. Thank you for your patience in this matter, Ron Wilson WI Tech 659-5524 ------------------------------ We have recently completed a mid year review of MIT data from our inspection database to see how many injection wells may be in question regarding MIT timing. Results of our review relating to BP-operated fields are as follows: MITs are past due for the following wells (injecting as of 7/31/2006) 1) PBU 04-13¡ due 1/8/2006 2) PBU S-101¡ due 2/25/2006 3) PBU NK-13¡ due 5/4/2006 4) PBU X-36¡ due 5/20/2006 5) PBU R-25A¡ due 7/24/2006 The following shut in wells are past their due date for MIT 1) MPU H-06¡ due 2/28/2006 (SI since 7/2002) 2) PBU WGI-01¡ due 4/22/2006 (S1 since 12/12/2005) 3) MPU F-41¡ due 5/14/2006 (S1 since 5/2005) 4) PBU S-31A; due 6/1/2006 (S1 since 12/2004) 5) PBU P1-01¡ due 6/4/2006 (SI since 6/2006 for workover) 6) PBU Pl-25; due 7/2/2006 (SI since 6/2006) 7) PBU GC-02C¡ due 7/22/2006 (S1 since 4/2006) A MIT for each well injecting on the list should be conducted as soon as practical¡ please notify the Commission for an opportunity to witness. Regarding SI injectors, the Commission suggests deferring testing (at least 20f4 9/25/20069: 15 AM v_ 'V" .~ "., /v~,vh V' vV \. .~". ,vv.." ~~n ,. ,'--' "'/... . the Commission's witnessed test) until injection is recommenced and well conditions have stabilized. There's also two wells with MITs that have apparently been done (not witnessed) that we would like to have for our database: 1) PBU 03-10¡ MIT 9/30/2005 (CMIT IAxOA) 2) PBU 04-08; MITs (IA and OA) done per monthly injector rpt; date unknown As with all operating companies, the Commission is willing to work with you to take advantage of operating efficiencies in scheduling MITs (perform multiple MITs per pad¡ perform tests during the more temperate months¡ etc.). Feel free to call if you have any questions, and thank you in advance for your prompt attention to those MITs that are past due. Jim Regg AOGCC Content-Description: MIT PBU S-101 11-23-03.xls MIT PBU S-10111-23-03.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT GPMA Pl-25 09-06-06.xls MIT GPMA Pl-25 09-06-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 04-13 08-10-03.xls MIT PBU 04-13 08-10-03.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 04-08 08-04-05.xls MIT PBU 04-08 08-04-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU R-25A 06-12-05.xls MIT PBU R-25A 06-12-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 30f4 9/25/20069:15 AM V-I 1 V \.l 11..-.' "/V~'VhV"'-VU\' lL/n-';VV.l'---"-'JIo.\l ,Un-!/... . Content-Description: MIT PBU 03-10 09-30-05.xls MIT PBU 03-10 09-30-0S.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU NK-13 09-19-06.xls MIT PBU NK-13 09-19-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 4 of 4 9/25/2006 9: 15 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION /Î C1 \7c,\00 Mechanical Integrity Test ~~ ¿:i l " Email to:WintonAubert@admin.state.ak.us;BobFleckenstein@admin.state.ak.uS;Jim_Regg@admin.state.ak.us;T1m_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay I PBU I OS 04 08/10/03 Jeff Rea Packer Depth Pretest Initial 15 Min. 30 Min. Well 104-13 Type Inj. , W TVD r 8,210' Tubing 1,800 1,800 1,800 1,800 IntervaÔ -tJ ) PTD.11780310 I Typetest I P Test psi! 2052.5 Casing 100 4,000 3,900 3,870 P/FT7 P Notes: MIT-IA pre-MI swap. OA 400 200 750 1000 I ~ Well' , Type Inj. , I TVD I Tubing Interval I p.T.D.1 I Type test I Test psil Casing P/FI Notes: OA Well' I Type Inj.1 TVD I Tubing Intervall P.T.D.I I Type test I Test psil Casing P/FI Notes: OA Weill , Type Inj.' I TVD , Tubing Interval I P.T.D. I Type testl I Test psil Casing P/FT Notes: OA Well' I Type Inj. I I TVD I Tubing IntervaIT P.T.D.I I Type test I I Test psi I Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = other (describe in notes) TYPE TEST Codes M = Annulus Monitoring P = standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differenhal Temperature Test MIT Report Form BFL 9/1/05 MIT PBU 04-13 08-10-03.xls .'-- i. J bt:) .c.; luJ ,...xL "- "' -'(. \ ~ \:?a,)~J ~V\O lÅ- . ttJ' r~SS~ \:;uv / . . ~ ··~f \NLlCt.J1 ~ V »- ~O f'r- " cç,uhV' Co l\.r\ (Ali \ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate _X ADPERFSIREPERFIACIDISBG Pul~ tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_ RKB 64 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 5247' FNL, 4839' FEL, Sec. 26, T11 N, R15E, UM (asp's 713270, 5951918) 04-13 At top of productive interval 9. Permit number / approval number 1406' FNL, 3740' FEL, Sec. 34, T11 N, R15E, UM (asp's 709134, 5950361) 178-031 At effective depth 10. APl number 1404' FNL, 3791' FEL, Sec. 34, T11N, R15E, UM (asp's 709082, 5950363) 50-029-20305 At total depth 11. Field / Pool 1390' FNL, 4006' FEL, Sec. 34, T11 N, R15E, UM (asp's 708867, 595O371) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10845 feet Plugs (measured) Tagged PBTD @ 10537 (06/08/2002) true vertical 8893 feet Effective depth: measured 10537 feet Junk (measured) IBP Rubber on Bottom (09/11/2001) true vertical 8773 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 111' 20" 320 sx Acrticset II 147' 147' Surface 2656' 13-3/8" 6400 sx Arcticset II 2692' 2692' Production 10790' 9-5/8" 900 sx Class 'G' 10826' 8979' Scab Liner 436' 3-1/2" 169 c.f. LARC 10024' - 10460' 8409' - 8719' Open Perfs 10464' - 10486', 10512' - 10522', Sqzd Perfs 2350' - 2352', 10225' - 245', 10252' - 262', Perforation depth: measured Sqzd Perfs cont. 10277' - 287', 10296' - 316', 10325' - 345', 10360' - 375', 10390' - 440' Covered Perfs 10570'- 10610', 10630'- 10666', 10678'- 10685', 10694'-703', 10714'-724' true vertical O Perfs 8721-8737, 8755-8762, S Perfs 2350-2352, 8554-8568, 8573-8580, 8590-8597, 8604-8618, S Perfs 8624-8638, 8649-8659, 8670-8705 C Perfs 8796-8824, 8838-8864, 8873-8878, 8884-8891, 8899-8906 Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 TBG @ 9950'. Tubing Tail @ 10054'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" ROT 3-H PKR @ 9950'. Cement PKR behind 3-1/2" liner f/-10460' to -10220'. 5-1/2" Camco BAL-O SSSVN @ 2207'. ~i::. i~ii~ ~i .... ~"ii ~ '~'~"'~ ~,.~7 ~i 13. Stimulation or cement squeeze summary "~;;. ~ ~:' ,- ' ';~ !.L, ~..~i? Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ' ~ ' ~'' ~!" · _ 14. Representative Daily Average Production or I niection Data i~t-,,:-'¢', 0asi~nq Pressure -'TUbing,P~e'ssure Oil-Bbl Gas-Mcr Water-Bbl .~,~,.~ ,, ~ Prior to well operation 05/17/2002 14622 ~:~..~'it;i ;i)i ~i;:~: 1937 Subsequent to operation 06/11/2002 Well Shut-In 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations _ Oil_ Gas _ Suspended __ Service WATER INJECT 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DeWayne R. Schnorr~ Prepared b~/DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 09/20/2001 09/23/2001 09/23/2001 09/29/2001 11/02/2001 11/05/2001 11/08/2001 11/09/2001 11/10/2001 11/11/2001 01/08/2002 05/28/2002 06/06/2002 06/07/2002 06/08/2002 09/20/01 09/23/01 09/23/01 09/29/01 11/02/01 11/05/01 11/08/01 04-13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS DRILL-POST WORK: DRIFT W/DMY GUN DRILL-POST WORK: DG DRIFT DRILL-POST WORK: PERFORATE - 2.5" HSD @ 6 SPF - PJ2506 DRILL-POST WORK: MITIA PRE AOGCC MISC-NRWO: SAND PLACEMENT DRILL-POST WORK: TAG SAND TOP @ 9856' SLM, 9884' RKB MISC-NRWO: REVERSE OUT/RE-PERF/MUD ACID MISC-NRWO: FCO/PERF/ACID MISC-NRWO: MEMORY GR/PERF MISC-NRWO: ACIDIZE STATE WITNESSED MIT-IA SSSV MAINTENANCE: SSSV C/O OR STROKE SCMOO-B-GONE--SBG: FILL CLEAN OUT; SCMOO-B-GONE SCMOO-B-GONE--SBG: FILL CLEAN OUT; SCMOO-B-GONE SSSV MAINTENANCE: DRIFT/TAG EVENT SUMMARY UNABLE TO GET THROUGH FLOAT SHOE @ 10464' WLM WITH 2.30" SWAGE. PIECE OF PACKER RUBBER STUCK ON SPANGS. RAN 3.5" WIRE GRAB. RECOVERED SECOND IBP ELEMENT. RAN10' X 2.125" STEM & 2.30" SWAGE. WORKED TIGHT SPOT @ 10464' WLM UNTIL SMOOTH. TAGGED TD AT 10686' WLM (BOTTOM SHOT= 10486'). RDMO. NOTIFY DSO - LEAVE WELL SHUT IN. DRIFT W/2.5" DUMMY GUN TO 10,682' WLM PERFORATE - 10464 - 10486 FT MD WITH POWERJET 2506 CHARGES @ 6 SPF MITIA PRE AOGCC PASSED PUMPED 65 BBLS OF 6-7.5 PPGA FULLBORE SAND DUMP WITH 15K# OF 20/40 SAND (3K# OTTOWA+12K# C-LITE). PRESSURED UP ON FILL TO 2000 PSI AFTER 1 HR. EST. TOS -- +-9800'. 60/40 MW IN TBG TO 900', CRUDE TO 6600'. READY FOR SLICKLINE TAG. DFF W/3.5 CENT TO TOS @ 9856' SLM, 9884' RKB. - ............. > WELL LEFT SI. MIRU DS CTU #3. RIH W/2.5" BALL DROP NOZZLE. PUMP 1% SL KCL DOWN COIL & DISPLACE CRUDE IN WELLBORE. FIND SAND TOP AT 9904' CTDM. BEGIN REVERSE OUT, MAKING FREQUENT WIPER TRIPS. TAG HARD BTTM AT 10472' - PUMP BIO DOWN COIL TO LIFT SAND - NO PROGRESS.DROP 5/8" BALL ON NOZZLE - STILL NO SUCCESS. POH. MU MOTOR AND MILL. Page 1 11/0 9/O 1 11/10/01 11/11/01 01/08/02 05/28/02 O6/O6/O2 O6/O7/O2 06/O8/O2 04-13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS GOOD PRESSURE TEST RIH WITH MOTOR AND MILL. TAG AT 10467' CTMD. ONE STALL AT 10467'. MILL TO 10525'. SWEEP AND CHASE OOH. PU LUBRICATOR. PU DS CCL TOOL, SWS CCL/GR FOR FLAG. RIH. TAG AT 10465 CTMD. UNABLE TO WORK DEEPER. LOG UP AND FLAG PIPE AT 10400. POH. CONTINUED FROM WSR OF 11/9/01. PU 14' X 2.5" GUN LOADED 6 SPF, 60 DEG PHASE. RIH. CORRECT AT FLAG. PERFORATE 10464' TO 10478'. POH. ALL SHOTS FIRED. RIH WITH NOZZLE. START NH4CL WATER. INJECTION RATE IS 0.4 B/M WITH COIL STOPPED AT 8894 WITH A WHP OF 1150. JOB IN PROGRESS. CONTINUED FROM PREVIOUS WSR. INITIAL INJECTIVITY WITH NH4 CL IS 0.4 B/M WITH WHP-1187. FINAL INJ. WITH NH4CL IS 0.4 B/M AT WHP- 1687. INITIAL INJECTIVITY WITH 7.5 % HCL IS 0.4 AT WHP-1670. FINAL INJ WITH 7.5% HCL IS 1.5 B/M AT WHP-1086. INITIAL INJECTIVITY WITH MUD ACID IS 1.5 B/M AT WHP-1090. FINAL INJECTIVITY IS 1.5 B/M AT WHP-755. INITIAL INJECTIVITY WITH NH4 CL IS 1.5 B/M WITH WHP-761 FINAL INJECTIVITY OF NH4CL IS 1.5 B/M WITH WHP- 725. POH. FREEZE PROTECT TREE AND COIL WITH MEOH. **NOTIFY DSO TO RETURN WELL TO INJECTION AFTER C/O SWAB VALVE** **JOB COMPLETE** STATE WITNESSED MIT-IA TO 2600 PSI (PASSED.) AOGCC WITNESSED BY MR. JOHN SPAULDING. DRIFT TBG W/5-1/2" BRUSH & 4.5 GR TO 16' WLMD, TOOLS COVERED W/SCHMOO. <<<RETURNED WELL TO OPERATOR FOR INJECTION>>> MIRU CTU #3, RIH W/2.25" JSN, JET TBG W/2% KCI. INITIALLY TAG UP AT 7208' CTMD, CON'T JETTING DOWN TBG THROUGH SCHMOO. LOOKS TO BE AN OBSTRUCTION. POOH TO RUN VENTURI. LUB FULL OF SCHMOO. RIH JETTING W/SBG. DID NOT SEE AN OVERPULL THROUGH LINER. TAG FILL ABOVE PERFS AND JET THROUGH. TOOK 1800 PSI TO BREAK DOWN PERFS. SHUT DOWN FOR I HR SOAKING SBG. MORE PERFS TO UNCOVER. ORDER OUT MORE SBG. JET SCHMOO DOWN TO 10,690' CTMD, JET SBG BACK & FORTH ACROSS PERFS, POOH JETTING TUBING WITH SBG. RIG DOWN. LEFT WELL SI. <<<TURNED OVER TO DSO TO POI>>> RAN 2.25" GAUGE, TEL & SB. SAT DOWN @ 10525' SLM. NO SAMPLE. RAN BACK. TAG BOTTOM @ 10526 SLM +11'= 10537' CORRECTED DEPTH. RAN 4.5" CENTRALIZER & B/L BRUSH & BRUSHED SVN @ 2168' SLM. RAN 4.6" CENTRALIZER & TAG SVN @ 2168' SLM. SET 5-1/2" BTDP-1 SSSV. RD. SECURED WELL. NOTIFIED DSO OF WELL STATUS. WELL LEFT SHUT-IN. Page 2 04-13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 2 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL. (2 TESTS) 134 METHANOL WATER 220 60/40 METHANOL WATER 5 50/50 METHANOL WATER 582 1% SLICK KCL WATER 540 2% KCL WATER 96 2% SLICK KCL WATER 117 2% DOUBLE SLICK KCL WATER 734 EXTRA SLICK KCL WATER 76 1.5# BIOZAN 11 NH4CL WATER 130 CRUDE 523 SBG 3170 TOTAL 09/23/2001 11/10/2001 ADD PERFS THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-1/2" HSD POWER JET AT 6 SPF, 60 DEGREES PHASING, AND RANDOM ORIENTATION. 10464'-10486' 10464'-10478' Page 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ¥ TO: Camille Taylor Co'~ Chair THRU: Tom Maunder P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector NON- CONFIDENTIAL DATE: January 8, 2002 ...)SUBJECT: Mechanical I nteg rity Tests BPX DS-4 & 11 4-9, 4-13, 11-35 PBU Prudhoe Bay Packer Depth Pretest Initial 15 Min. 30 Min. 'WellI 4-09 ITypelnj.] S ] T.V.D. 17928 ~000 i~000 i~000 1~000 Ilntervall I P.T.,D.] 1760300 ]Typetest] P ]Testpsi] '1982 I Casing] 620 ] 2600 ] 2590 ] 2585 J P/F ] P Notes: WelIJ 4-13 I Typelnj.! S ] T.V.D. I 8210 I Tubing I 2000 I 2000 I 2000 I 2000 l lnterVall i P.T.D.] 17880310 TypetestI P ]Testpsi] 2O53 I Casing] 1050] 2600] 2600] 2600I P/F ] P Notes: WellI 11-35 JTypelnj.I S IT.V.D.I 8201 ITubingl 165011650 11650 ] 1650 Ilntervall I P.T.D.] 1940650 ]Typetest] P ITestpsi] 2050 I Casing] 1580] 2600] 2550 ] 2550 Notes: P.T.D. Notes: P.T.D. Notes: TypetestI ITest psi l I Casing I I I I I P/F I IType Inj. Type test Type INJ. Fluid Codes F: FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I.= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Both 4-09 and 4-13 were post rig workovers, while 11-35 recently was converted from a producer to an injector. All thre wells passed their respective MIT's and are in compliance with area injection orders. M.I.T.'s performed: _3 Number of Failures: 0_ Attachments: none Total Time during tests: 1.5 hfs cc: none M IT report form 5/12/00 L.G. MIT PBU FS-2 1-08-02js.xls 3/7/02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X ADPERFS/REPERF/ACID Pull tubing _ Alter casing _ Repair well_ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X 4. Location of well at surface 32' FSL, 440' FWL, Sec. 26, T11 N, R15E, UM At top of productive interval 1406' FNL, 1540' FWL, Sec. 34, T11 N, R15E, UM At effective depth 1404' FNL, 1497' FWL, Sec. 34, T11N, R15E, UM At total depth 1389' FNL, 1273' FWL, Sec. 34, T11N, R15E, UM (asp's 713270, 5951918) (asp's 709134, 5950361) (asp's 709091, 5950363) (asp's 708867, 5950371) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 04-13 9. Permit number / approval number' 'i,,--, 178-031 I!11 10. APl number 50-029-20305 11. Field / Pool UJ Prudhoe Bay Oil Pool C ~ 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 111' Surface 2656' Production 10790' Scab Liner 436' 10845 feet Plugs (measured) 8893 feet 10525 feet Junk (measured) 8764 feet Tagged PBTD @ 10525 (11/09/2_~) IBP Rubber on Bottom (09/11/2001) Size Cemented Measured Depth True Vertical Depth 20" 320 sx Acrticset II 147' 147' 13-3/8" 6400 sx Arcticset II 2692' 2692' 9-5/8" 900 sx Class 'G' 10826' 8979' 3-1/2" 169 c.f. LARC 10024' - 10460' 8409' - 8719' Perforation depth: Tubing (size, grade, and measured depth) Open Perfs 10464' - 10486', 10512' - 10522', Sqzd Perfs 2350' - 2352', 10225' - 245', 10252' - 262', measured Sqzd Perfs cont. 10277' - 287', 10296' - 316', 10325' - 345', 10360' - 375', 10390' - 440' Covered Perfs 10570' - 10610', 10630' - 10666', 10678' - 10685', 10694' - 703', 10714' - 724' true vertical O Perfs 8721-8737, 8755-8762, S Perfs 2350-2352, 8554-8568, 8573-8580, 8590-8597, 8604-8618, S Perfs 8624-8638, 8649-8659, 8670-8705 C Perfs 8796-8824, 8838-8864, 8873-8878, 8884-8891, 8899-8906 5-1/2", 17#, L-80 TBG @ 9950'. Tubing Tail @ 10054'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" BOT 3-H PKR @ 9950'. Cement PKR behind 3-1/2" liner f/-10460' to -10220'. 5-1/2" Camco BAL-O SSSVN @ 2207'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 10/31/2001 11/14/2001 OiI-Bbl Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl 26400 10555 Casing Pressure Tubing Pressure 1920 1936 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WATER INJECT 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · ORIGINAL Date November 15, 2001 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 09/20/2001 09/23/2001 09/23/2001 09/29/2001 11/02/2001 11/05/2001 11/08/2001 11/09/2001 11/10/2001 11/11/2001 09/20/01 04-13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS DRILL-POST WORK: DRIFT W/DMY GUN DRILL-POST WORK: DG DRIFT DRILL-POST WORK: PERFORATE - 2.5" HSD @ 6 SPF - PJ2506 DRILL-POST WORK: MITIA PRE AOGCC MISC-NRWO: SAND PLACEMENT DRILL-POST WORK: TAG SAND TOP @ 9856' SLM, 9884' RKB MISC-NRWO: REVERSE OUT / RE-PERF / MUD ACID MISC-NRWO: FCO/PERF/ACID MISC-NRWO: MEMORY GR/PERF MISC-NRWO: ACIDIZE EVENT SUMMARY UNABLE TO GET THROUGH FLOAT SHOE @ 10464' WLM WITH 2.30" SWAGE. PIECE OF PACKER RUBBER STUCK ON SPANGS. RAN 3.5" WIRE GRAB. RECOVERED SECOND IBP ELEMENT. RAN10' X 2.125" STEM & 2.30" SWAGE. WORKED TIGHT SPOT @ 10464' WLM UNTIL SMOOTH. TAGGED TD AT 10686' WLM (BOTTOM SHOT= 10486'). RDMO. NOTIFY DSO - LEAVE WELL SHUT IN. 09/23/01 09/23/01 09/29/01 11/02/01 11/O5/O 1 DRIFT W/2.5" DUMMY GUN TO 10,682' WLM PERFORATE - 10464 - 10486 FT MD WITH POWERJET 2506 CHARGES @ 6 SPF MITIA PRE AOGCC PASSED PUMPED 65 BBLS OF 6-7.5 PPGA FULLBORE SAND DUMP WITH 15K# OF 20/40 SAND (3K# OTTOWA+12K# C-LITE). PRESSURED UP ON FILL TO 2000 PSI AFTER 1 HR. EST. TOS = +-9800'. 60/40 MW IN TBG TO 900', CRUDE TO 6600'. READY FOR SLICKLINE TAG. D/T W/3.5 CENT TO TOS @ 9856' SLM, 9884' RKB. - ............. > WELL LEFT SI. 11/08/01 MIRU DS CTU #3. RIH W/2.5" BALL DROP NOZZLE. PUMP 1% SL KCL DOWN COIL & DISPLACE CRUDE IN WELLBORE. FIND SAND TOP AT 9904' CTDM. BEGIN REVERSE OUT, MAKING FREQUENT WIPER TRIPS. TAG HARD BTTM AT 10472' - PUMP BIO DOWN COIL TO LIFT SAND - NO PROGRESS. DROP 5/8" BALL ON NOZZLE - STILL NO SUCCESS. POH. MU MOTOR AND MILL. Page I 11/09/O 1 04-13 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS GOOD PRESSURE TEST RIH WITH MOTOR AND MILL. TAG AT 10467' CTMD. ONE STALL AT 10467'. MILL TO 10525'. SWEEP AND CHASE OOH. PU LUBRICATOR. PU DS CCL TOOL, SWS CCL/GR FOR FLAG. RIH. TAG AT 10465 CTMD. UNABLE TO WORK DEEPER. LOG UP AND FLAG PIPE AT 10400. POH. 11/10/01 CONTINUED FROM WSR OF 11/9/01. PU 14'X 2.5" GUN LOADED 6 SPF, 60 DEG PHASE. RIH. CORRECT AT FLAG. PERFORATE 10464' TO 10478'. POH. ALL SHOTS FIRED. RIH WITH NOZZLE. START NH4CL WATER. INJECTION RATE IS 0.4 B/M WITH COIL STOPPED AT 8894 WITH A WHP OF 1150. JOB IN PROGRESS. 11/11/01 CONTINUED FROM PREVIOUS WSR. INITIAL INJECTIVITY WITH NH4 CL IS 0.4 B/M WITH WHP-1187. FINAL INJ. WITH NH4CL IS 0.4 B/M AT WHP- 1687. INITIAL INJECTIVITY WITH 7.5 % HCL IS 0.4 AT WHP-1670. FINAL INJ WITH 7.5% HCL IS 1.5 B/M AT WHP-1086. INITIAL INJECTIVITY WITH MUD ACID IS 1.5 B/M AT WHP-1090. FINAL INJECTIVITY IS 1.5 B/M AT WHP-755. INITIAL INJECTIVITY WITH NH4 CL IS 1.5 B/M WITH WHP-761 FINAL INJECTIVITY OF NH4CL IS 1.5 B/M WITH WHP- 725. POH. FREEZE PROTECT TREE AND COIL WITH MEOH. **NOTIFY DSO TO RETURN WELL TO INJECTION AFTER C/O SWAB VALVE** **JOB COMPLETE** FLUIDS PUMPED BBLS 1 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL. 134 METHANOL WATER 220 60/40 METHANOL WATER 582 1% SLICK KCL WATER 200 2% KCL WATER 117 2% DOUBLE SLICK KCL WATER 734 EXTRA SLICK KCL WATER 76 1.5# BIOZAN 11 NH4CL WATER 130 CRUDE 2205 TOTAL 09/23/2001 11/10/2001 ADD PERFS THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-1/2" HSD POWER JET AT 6 SPF, 60 DEGREES PHASING, AND RANDOM ORIENTATION. 10464' - 10486' 10464'- 10478' Page 2 STATE OF ALASKA ALASKA ,,.,~L AND GAS CONSERVATION COMM,,.,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development RKB = 64' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 32' NSL, 4838' WEL, SEC. 26, T11N, R15E, UM 04-13i At top of productive intervalRECEIVED 9. Permit Number/ Approval No. 178-031 301-229 1420' SNL, 3478' WEL, SEC. 34, T11N, R15E, UM 10. APl Number At effective depthOCT0 ~: 2001 50-029-20305-00 1397' SNL, 3895' WEL, SEC. 34, T11N, R15E, UM 11. Field and Pool At total depth Alaska 0il & Gas Cons. Commissio~ Prudhoe Bay Field / Prudhoe Bay 1389' SNL, 4005' WEL, SEC. 34, T11 N, R15E, UM Anchorage Pool 12. Present well condition summary Total depth: measured 10845 feet Plugs (measured) Tagged PBTD (09/19/01) true vertical 8993 feet Effective depth: measured 10686 feet Junk (measured) Misc. fish in hole. Baker packer element lost 07/90, IBP true vertical 8878 feet rubber lost on 09/01. Exact depths unknown. Casing Length Size Cemented MD TVD Structural Conductor 111' 20" 320 sx Arcticset II 111' 111' Sudace 2692' 13-3/8" 6400 sx Arcticset II 2692' 2692' Intermediate Production 10826' 9-5/8" 900 sx Class 'G' 10826' 8979' Liner Scab Liner 437' 3-1/2" 22 Bbls I_ARC 10023' - 10460' 8409' - 8719' Perforation depth: measured 10464'- 10486', 10512'- 10522', 10570'- 10610', 10630'- 10666', 10678'- 10685', 10694'- 10703', 10714'- 10724'; Sqzd: 10222'- 10440' true vertical 8721' -8737', 8755' - 8762', 8796' - 8824', 8838' - 8864', 8873' - 8878', 8884' - 8891', 8899' - 8906' Sqzd: 8551'- 8705' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 5-1/2", 17#, L-80 to 10054'; Cut at 9890' Packers and SSSV (type and measured depth) Baker '3-H' packer at 9950'; Baker 'S-3 packer at 9753'; Camco BaI-O SSSV Nipple at 2207' 13. Stimulation or cement squeeze summary Intervals treated (measured) 9-5/8" Casing Leak, Perf'd 2350' - 2352' Treatment description including volumes used and final pressure 08/23/01: Pumped 400 sx Class 'E', followed by 100 sx Class 'G', Sqzd to 500 psi; 08/24/01: Pumped 70 sx Class 'G', Sqzd to 3500 psi; 08/26/01: Pumped 200 sx Class 'E', followed by 200 sx Class 'G'; See Attached Summary 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service Water & Gas Injector [] Daily Report of Well Operations 17. I hereby certify that the fore. going is true and correct to the best of my knowledge Signed TerrieHubble ,,~/~ ~ Title TechnicalAssistant Date ~ ~ t '...... Prepared By Name/Numbec Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Well: 04-13i, RWO Rig Accept: 08/19/01 Field: Prudhoe Bay Unit Rig Release: 09/01/01 APl: 50-029-20305-00 Permit: 178-031 Workover Rig: Do)/on 16 PRE-RIG WORK 05/:~0101 Set IBP at 10004' in the 5-1/2" tubing tail. 05/31/01 Pressure test IBP to 1000 psi, test good. Place 400 pounds of 20/40 river sand on IBP with sand top at 9993' (11' of sand). Place 200 pounds 20/40 carbolite from 9993' to 9979' (14' of sand). Total sand plug tagged with CT was 25' for a sand top of 9979'. Freeze protect well from 2000', leave shut-in for RWO. 07/11101 Chemically cut tubing at 9890'. Legal Well Name: 04-13i Common Well Name: 04-13i Spud Date: 8/19/2001 Event Name: WORKOVER Start: 8/1912001 End: Contractor Name: DOYON Rig Release: 9/1/2001 Rig Name: Doyon 16 Rig Number: ~te i~ity Description of Operations 8/19/2001 03:00- 15:00 12.00 MOB P DECOMP MOVED IN FROM 04-9i, RIGGED UP RIG ACCEPTED AT 1500 HOURS 15:00 - 16:30 1.50 KILL P DECOMP P/U LUB, BLEED OFF 100 PSI FROM IA. RETRIEVED BPV 16:30- 18:00 1.50 KILL P DECOMP HOOKED UP LINES TO WELL # 27 AND TEST TO 3000 PSI 18:00- 20:00 2.00 KILL P DECOMP WAIT ON KILL FLUID 20:00 - 22:30 2.50 KILL P DECOMP REMOVED LINES FROM WELL # 27 AND CONNECTED TO WELL 26 & PRESSURE TESTED TO 3000 PSI 22:30 - 00:00 1.50 KILL P DECOMP PJSM, REVERSE CIRCULATED OUT FREEZE PROTECTION DOWN FLOWLINE AND CONTINUE KILL WELL PUMPING DOWN TBG, RETURNS OUT ANNULUS TO FLOWLINE AT REPORT TIME 8/20/2001 00:00 - 01:30 1.50 KILL ~ DECOMP KILLED WELL WITH 8.6 PPG SEA WATER 01:30- 02:00 0.50 KILL ~ DECOMP OBSERVED DEAD 1/2 HOUR 02:00 - 02:30 0.50 KILL ~ DECOMP BLOW DOWN LINES AND BREAK OUT SAME 02:30 - 03:30 1.00 WHSUR ~ DECOMP P/U LUBRICATOR & SET BPV 03:30 - 04:00 0.50 WHSUR ~ DECOMP PRESSURE TESTED BPV FROM BACKSIDE TO 1000 PSI 04:00 - 05:30 1.50 WHSUR ~ DECOMP REMOVED XMAS TREE AND ADAPTER FLANGE 05:30- 14:30 9.00 BOPSUIq ~ DECOMP INSTALLED BOPE & FUNCTION TEST 14:30- 18:00 3.50 DEMOB P DECOMP MADE UP SPEAR, RIH ENGAGED HANGER, PULLED FREE AT 240,000 LB OVER ( 100,000 OVER ) 18:00- 20:00 2.00 DEMOB P DECOMP POOH LAID DOWN 5 JOINT'S 5 1/2" TBG, CAMCO SPOOLED AND CUT SSSV CONTROL LINE 20:00 - 21:30 1.50 DEMOB P DECOMP VlADE UP HALLIBURTON STORM PACKER RIH AND SET AT 100', POOH & TEST PKR TO 1000 PSI 21:30 - 00:00 2.50 DEMOB P DECOMP PRESSURE TEST BOPE 3500 PSI HIGH AND 250 PSI LOW PRESSURE 10 MIN HIGH 5 LOW ( TESTING BOPE AT REPORT TIME ) 8/21/2001 00:00 - 02:00 2.00 BOPSUF:P DECOMP PRESSURE TESTED BOPE 3500 PSI HIGH AND 250 PSI LOW 10 MIN HIGH 5 MIN LOW 02:00 - 02:30 0.50 BOPSUF~P DECOMP PULLED TEST PLUG 02:30 - 03:30 1.00 CASE P DECOMP RTTS SET AT 100', PRESSURE TESTED CASING TO 3000 PSI CHARTED 30 MIN 03:30 - 05:00 1.50 CASE 3 DECOMP SET WEAR BUSHING, RIH WITH RTTS RETRIEVING TOOL 05:00 - 06:30 1.50 PULL ~ DECOMP POOH AND LAID DOWN RTTS 06:30 - 18:00 11.50 PULL 3 DECOMP POOH LAID DOWN 5 1/2" TBG ( 237 JTS ) RECOVERED SEAL ASSEMBLY INCLUDING MULE SHOE 18:00 - 19:30 1.50 PULL ~ DECOMP SERVICED RIG, CLEANED RIG FLOOR, L/D TBG EQUIPMENT 19:30 - 20:30 1.00 CASE ~ DECOMP PRESSURE TESTED CASING TO 3000 PSI ( PRESSURE DROPPED 400 PSI IN 30 MIN ) 20:30 - 21:00 0.50 CASE 3 DECOMP LOAD DRILL PIPE IN SHED 21:00 - 21:30 0.50 CASE 3 DECOMP CHANGED WEAR BUSHING 21:30 - 00:00 2.50: CASE P DECOMP LOAD 9 X 6 3/4" DRILL COLLARS IN SHEAD, MADE UP RTTS START RIH PICKING UP DRILL COLLARS AND 3 1/2" DRILL PIPE, AT REPORT TIME 290' IN HOLE 8/22/2001 00:00 - 04:00 4.00 CASE P DECOMP RIH WITH RTTS BHA PICKING UP 3 1/2" DRILL PIPE, SET RTTS AT 2800' 04:00 - 05:00 1.00 CASE P DECOMP ~RESSURE TESTED CASING TO 3000 PSI, PRESSURE DROPPED 500 PSI IN 5 MIN 05:00 - 08:30 3.50 CASE P DECOMP LOCATING LEAK ( PRESSURED GOOD AT 2420', CON'T TEST SET RTTS AT SEVERAL INTERVALS, LOCATED LEAK BE'rWEEN 2325' AND 2420' ) 08:30 - 11:00 2.50 CASE P DECOMP POOH WITH RTTS BHA, MADE UP RBP BHA Printed: 9/4/2001 5:03:30 PM ................ Legal Well Name: 04-13i Common Well Name: 04-13i Spud Date: 8/19/2001 Event Name: WORKOVER Start: 8/19/2001 End: Contractor Name: DOYON Rig Release: 9/1/2001 Rig Name: Doyon 16 Rig Number: ~:: ~ ~ :~ ~ ~i~ity' ~ Description of Operations ...... 8/22/2001 11:00 - 14:00 3.00 CASE P DECOMP RIH WITH RBP TO 2600', BROKE CIRCULATION 14:00 - 16:30 2.50 CASE P DECOMP SET RBP AT 2600', POOH 3 STDS, DUMPED 10 SX BARACARB ON TOP OF RBP 16:30 - 19:30 3.00 CASE P DECOMP RIGGED UP SCHLUMBERGER, RAN CCL STRIP, PERFORATED WITH 3 1/8" GUN 8 SQUEEZE HOLE'S FROM 2350'-2352', RIGGED OUT SCHLUMBERGER 19:30 - 00:00 4.50 CASE ~ DECOMP PUMPED 150' HOT SEA WATER DOWN IA CIRCULATING OUT ARTIC-PAC BETWEEN 9 5~8" X 13 3~8" ANNULUS TO SLOP TANK, RECOVERED 40 BBL + / - ARTIC-PAC AT REPORT TIME 8/23/2001 00:00 - 08:30 8.50 CASE ~ DECOMP CIRCULATED OUT ARTIC-PAC, CIRCULATED 9 5~8" X 13 3/8" CSG WITH H-VIS SWEEPS BARA SCRUB AND DIRT I MAGNET 08:30 - 11:00 2.50 CASE ~ DECOMP MADE UP HALLIBURTON COMPOSlT EZSV CEMENT RETAINER AND RIH TO 2250' : 11:00 - 11:30 0.50 CASE P DECOMP BROKE CIRCULATION AND SET CEMENT RETAINER AT 2250' 11:30 - 14:30 3.00 CASE P DECOMP PJSM, RIGGED UP HALLIBURTON CMT UNIT, PUMPED 10 BBL FRESH WATER, PRESSURE TESTED LINES TO 3000 PSI, PUMP 400 SX "158 BBL" ( CLASS "E" 12.0 PPG CMT SLURRY ) FOLLOWED BY 100 SX "20.5 BBL" ( CLASS "G" CMTAT 15.8 PPG CMT SLURRY ) DISPLACED WITH 16 BBL WATER, ( RECOVERED 40 BBL CMT OUT CA ) PULL OUT OF CMT RETAINER 30', REVERSED OUT, CIRCULATED 2 DP VOL. ( FINAL SQUEEZE PRESSURE 500 PSI ) ( NOTE!!! SEE DIMS CEMENT REPORT FOR FULL DETAILS ) 14:30 - 15:30 1.00 CASE ~ DECOMP POOH WITH CMT RETAINER STINGER, LAID DOWN SAME 15:30-00:00 8.50 CASE ~ DECOMP PJSM, PICK UP 3 1/2 DP RIH 60 JTSATATIME, POOH STAND BACK IN DERRICK WHILE WAITING ON CEMENT 8/24/2001 00:00 - 01:30 1.50 CASE = DECOMP POOH WITH 17 STANDS 3 1/2" O.E. DP 01:30 - 03:00 1.50 CASE ~ DECOMP MADE UP MILL BHA RIH TAG CEMENT AT 2219' 03:00 - 09:30 6.50 CASE ~ ~DECOMP DRILLED OUT CEMENT AND CEMENT RETAINER @ 2250, DRILL OUT CMT TO 2355' 09:30 - 13:00 3.50 CASE ~ DECOMP WASH AND CLEAN OUT TO 2587' 13:00- 13:30 0.50 CASE P DECOMP PUMPED HI VIS SWEEP 13:30 - 15:30 2.00 CASE P DECOMP PRESSURE TEST CASING TO 3000 PSI, DROPPED 300 PSI IN 15 MIN, AT 2000 PSI DROPPED 125 PSI IN 15 MIN, PRESSURE HELD AT 1000 PSI 15:30 - 18:00 2.50 CASE P DECOMP POOH WITH MILL BHA 18:00 - 19:30 1.50 CASE P DECOMP RIH WITH O.E. DRILL PIPE TO 2446' 19:30 - 21:30 2.00 CASE P DECOMP RIGGED UP HALLIBURTON CMT UNIT, PJSM, PUMPED 10 F/WATER PRESSURE TESTED LINES TO 3500 PSI, PUMPED 70 SX ( 14 BBL 15.8 PPG SLURRY "G" CMTW/ 2% CACL2 ) DISPLACED WITH 16.5 BBL FRESH WATER, PULLED 3 STANDS TO 2161', REVERSED OUT" NO CMT RETURNS" ( DOWN SQUEEZED 2.5 BBL PRESSURED TO 3500 PSI., SHUT IN WITH 3500 PSI ON SQUEEZE ( SEE CEMENT REPORT FOR DETAILS ) 21:30 - 00:00 2.50 CASE 3 DECOMP WAIT ON CMT, PRESSURE DROPPED TO 3100 PSI IN 2 HOURS & 10 MIN, REPRESSURED TO 3500 PSI, NO PRESSURE DROP IN LAST 50 MIN, WAIT ON CMT AT REPORT TIME Printed: 9/4/2001 5:03:30 PM ~ ~PL~RATION Page3 of 6 Report ...... Legal Well Name: 04-13i Common Well Name: 04-13i Spud Date: 8/19/2001 Event Name: WORKOVER Start: 8/19/2001 End: Contractor Name: DOYON Rig Release: 9/1/2001 Rig Name: Doyon 16 Rig Number: HoU~s ~i~i~ ~de UP~ Phase Description of Operations · : :. · : .. : , 8/25/2001 00:00 - 00:30 0.50 CASE P DECOMP WAIT ON CMT 00:30 - 02:00 1.50 CASE P DECOMP POOH WITH OPEN ENDED DRILL PIPE 02:00 - 04:00 2.00 CASE P DECOMP M/U 8 1/2" BIT BHA, RIH TAG CMT AT 2313' 04:00 - 08:00 4.00 CASE P DECOMP DRILLED OUT CMT TO 2578' 08:00 - 09:00 1.00 CASE P DECOMP CIRCULATED HI VIS SWEEPS 09:00 - 14:30 5.50 CASE P DECOMP PRESSURE TESTED CASING SQUEEZE AS FOLLOWS: PRESSURED TO 2000 PSI DROPPED TO 1800 PSI IN 5 MIN, DROPPED TO 1700 PSI IN 30 MIN DROPPED TO 1658 PSI IN 55 MIN, PRESSURED TO 2250 PSI DROPPED TO 1975 PSI IN 5 MIN, DROPPED TO 1840 IN 30 MIN PRESSURED TO 2000 PSI, 5 MIN STILL HOLDING, DROPPED TO 1975 PSI IN 10, DROPPED TO 1900 PSI IN 30 MIN 14:30 - 16:00 1.50 CASE P DECOMP POOH WITH BIT BHA 16:00 - 19:30 3.50 CASE P DECOMP M/U RTTS, RIH TO 2360', SET RTTS AT 2360' ( 8' BELOW 8 SQUEEZE HOLES @ 2350~2352 AND 10 ABOVE F.O. @ 2370' 19:30 - 21:00 1.50 CASE P DECOMP PRESSURE TESTED CASING AS FOLLOWS: PRESSURED TO 3000 PSI ON F.O. AT 2370' DROPPED 650 PSI IN 10 MIN, PRESSURED ON SQUEEZE HOLES AT 2350~52 TO 3050 PSI PRESSURE DROPPED 150 PSI IN 20 MIN, PRESSURED TO 3500 PSI ON SQUEEZE HOLE DROPPED 50 PSI IN 20 MIN, INCREASED PUMP PRESSURE TO 4000 PSI ON SQUEEZE HOLES ESTABLISHED CIRCULATION OUT CA., CIRCULATE OUT CONTAMINATED CEMENT TO SLOP TANK, PUMP RATE START 1 BPM ENDING 2 BPM AT 2200 PSI 21:00 - 00:00 3.00 CASE ~ DECOMP RELEASED RTTS AND PULL TO 2328' AND SET RTTS, CONTINUE CIRCULATE OUT CONTAMINATED CEMENT AT 3 BPM 2800 PSI AT REPORT TIME 8/26/2001 00:00 - 01:30 1.50 CASE P DECOMP CONTINUE CIRCULATED OUT CONTAMINATED CMT FROM 13 3~8" ANNULUS 01:30 - 05:00 3.50 CASE P DECOMP RELEASED RTTS, POOH, M/U CEMENT RETAINER 05:00 - 07:30 2.50 CASE P DECOMP RIH SET RTTS AT 2310' 07:30 - 10:00 2.50 CASE P DECOMP PJSM, HALLIBURTON PUMPED 10 BBL FRESH, PRESSURE TESTED LINES TO 4000 PSI, PUMPED 200 SX CLASS "E" CMT ( 77 BBL 12.0 PPG SLURRY ) FOLLOWED BY 200 SX CLASS "G" CMT ( 41 BBL 15.8 PPG SLURRY ) DISPLACED WITH 17 BBL FRESH WATER., UNSTUNG FROM RETAINER AND REVERSED OUT TWO DP VOLUMES. C.I.P. AT 0915 HOURS ( SEE CEMENT REPORT FOR DETAILS ) 10:00 - 11:00 1.00 CASE ~ DECOMP POOH WITH RETAINER RUNNING TOOL 11:00 - 12:30 1.50 CASE ~ DECOMP WAIT ON CEMENT, SERVICED RIG 12:30 - 15:00 2.50 CASE ~ DECOMP M/U 8 1/2" BIT BHA, RIH TO 2262' ( EST 50' ABOVE TOP OF CEMENT ) 15:00 - 21:30 6.50 CASE ~ DECOMP CIRCUATE WHILE WAITING ON CEMENT 21:30 - 00:00 2.50 CASE 3 DECOMP TAG CEMENT AT 2298', DRILL OUT CMT AND DRILLING ON CEMENT RETAINER AT 2312' AT REPORT TIME 8/27/2001 00:00 - 05:00 5.00 CASE :' DECOMP ~DRILLED OUT CMT TO 2360' RIH TO 2577' ( 23' ABOVE RBP / 05:00 - 07:30 2.50 CASE P DECOMP PUMPED SWEEP, PRESSURE TESTED CASING TO 3000 Printed: 9/4/2001 5:03:30 PM .......... Legal Well Name: 04-13i Common Well Name: 04-13i Spud Date: 8/19/2001 Event Name: WORKOVER Start: 8/19/2001 End: Contractor Name: DOYON Rig Release: 9/1/2001 Rig Name: Doyon 16 Rig Number: ~:~te ~ ~ ~ ~i~i~ ~ ~ Description of Operations 8/27/2001 05:00 - 07:30 2.50 CASE P DECOMP PSI, PUMPED SECOND SWEEP ;07:30 - 09:00 1.50 CASE P DECOMP POOH WITH BIT BHA 09:00 - 11:00 2.00 CASE P DECOMP RIH WITH RBP RETRIEVING TOOL TO 2600' 11:00- 12:00 1.00 CASE P DECOMP CIRCULATE DOWN, ENGAGED RBP 12:00 - 14:00 2.00 CASE P DECOMP POOH ( NO RECOVERY ) 14:00 - 16:30 2.50 CASE P DECOMP RIH WITH RBP RETRIEVING TOOL, ENGAGED RBP AT 2665' SET RBP CONFIRMED RETRIEVING TOOL ENGAGED, 16:30- 18:30 2.00 CASE P DECOMP POOH WITH RBP 18:30 - 19:00 0.50 CASE P DECOMP PULLED WEAR BUSHING, SET TEST PLUG 19:00 - 00:00 5.00 CASE P DECOMP PRESSURE TEST BOPE ( WEEKLY TEST ) AT REPORT TIME 8/28/2001 00:00 - 02:00 2.00 CASE :~ DECOMP FINISHED TESTING BOPs TO 250 PSI LOW FOR 5 MINUTES AND 3,500 PSI HIGH FOR 10 MINUTES. UPPER AND LOWER KELLY COCKS DID NOT PRESSURE TEST. ALL OTHER TESTS HELD w/NO LEAKS OR PRESSURE LOSS. 02:00-06:30 4.50 CASE :) DECOMP M / U BHA AND RIH WITH 3-1/2" DP TO 9,172'. 06:30 - 07:30 1.00 CASE :~ DECOMP CUT AND SLIPPED DRILL LINE 07:30 - 08:00 0.50 CASE N DECOMP P/U KELLY AND CHANGED OUT LOWER KELLY COCK VALVE. 08:00 - 09:30 1.50 CASE :~ DECOMP RIH WITH 3-1/2" DP FROM PIPE SHED TO TOP OF PACKER AT 9,922'. 09:30 - 14:00 4.50 CASE :~ DECOMP P / U KELLY, BROKE CIRCULATION. CIRCULATED HI-VIS SWEEP, ROTATED AND POLISHED PBR. 14:00 - 20:30 6.50 CASE P DECOMP POOH AND SLM. L ! D POLISH MILL AND LOCATOR ABOVE 4 5/8" OD BULL NOSE. SLM = 9,596.54', DP TALLY -- 9,593.71'. 20:30 - 00:00 3.50~ CASE P DECOMP M / U STINGER AND CASING SCRAPPER. STINGER 14.31' LONG BELOW 9-5~8" CASING SCRAPPER. RIH wi BHA ON 3-1/2" DP. 8/29/2001 00:00 - 02:00 2.00 CLEAN P COMP HELD PJSM. RIH wi BHA ON 3-1/2" D. P. TO 9,905'. TAGGED UP ON TOP OF PBR w/9-5/8" CASING SCRAPER AT 9,905'. 02:00 - 02:30 0.50 CLEAN P COMP TAGGED TOP OF PBR AT 9,905', ROTATED AND CIRCULATED ON TOP OF PBR. 02:30 - 10:00 7.50 CLEAN P COMP HELD PJSM. POOH AND L / D 255 JOINTS OF 3-1/2" D.P. 10:00 - 10:30 0.50 CLEAN P COMP P/U KELLY AND BROKE SAME. 10:30 - 12:00 1.50 CLEAN :~ COMP POOH L / D 47 JOINTS OF 3-1/2" D. P. TOTAL JOINTS L / D 302. 12:00 - 13:30 1.50 CLEAN :) COMP HELD PJSM. BROKE OUT AND L / D 9 6-3/4" D. C. 13:30 - 14:00 0.50 CLEAN ~ COMP M / U RETRIEVING TOOL, PULLED WEAR BUSHING, L / D RETRIEVING TOOL. 14:00 - 15:30 1.50 RUNCOI~ COMP RIGGED UP TO RUN 5-1/2" 17# SLHC TUBING. 15:30 - 20:30 5.00 RUNCOI~ COMP HELD PJSM. M / U TAIL PIPE ASSEMBLY AND PACKER. RIH WITH 5 1/2", 17#, L-80, SLHC TUBING. RAN 68 JOINTS, 3,011'. MAKE UP TORQUE 4,800 fi/lbs, MAXIMUM MAKE UP RPM 10. 20:30 - 22:00 1.50 RUNCOP, P COMP R / U HOWCO SLICK LINE AND RUN 4.75" GAUGE RING TO TOP X NIPPLE. 22:00 - 23:00 1.00 RUNCOI~ P COMP R / U AND PRESSURE TESTED TUBING TO 3,500 FOR 30 MINUTES. OK. Printed: 9/4/2001 5:03:30 PM Legal Well Name: 04-13i Common Well Name: 04-13i Spud Date: 8/19/2001 Event Name: WORKOVER Start: 8/1912001 End: Contractor Name: DOYON Rig Release: 9/1/2001 Rig Name: Doyon 16 Rig Number: ~ ~i~i~ ~ Description of Operations ,, 8/29/2001 23:00 - 00:00 1.00 RUNCOr P COMP CONTINUED TO RUN 5 1/2" TUBING. 8/30/2001 00:00 - 04:00 4.00 RUNCOr P COMP HELD PJSM. CONTINUED TO RIH w/5-1/2" 17# SLHC TUBING TO 6,009'. 04:00 - 05:30 1.50 RUNCO~ COMP R / U HOWCO SLICK LINE AND RAN 4.75" DRIFT. 05:30 - 06:00 0.50 RUNCO~P COMP PRESSURE TESTED TUBING TO 3,500 PSI f/30 MINUTES, OK. 06:00 - 09:00 3.00 RUNCO~ COMP CONTINUED TO RIH w/5-1/2" 17# SLHC TUBING TO 7,715'. 09:00 - 10:00 1.00 RUNCO~ COMP R / U HOWCO SLICK LINE AND RAN 4.75" DRIFT, PRIOR TO M / U SSSV. 10:00 - 10:30 0.50 RUNCOI~ COMP PRESSURE TESTED TUBING TO 3,500 PSI f/30 MINUTES, OK. 10:30 - 11:00 0.50 RUNCOI~!:) COMP M / U SSSV, R / U CONTROL LINE SPOOLS, CONNECTED CONTROL LINES TO SSSV AND PRESSURE TESTED TO 5,000 PSI, OK. 11:00 - 17:00 6.00 RUNCOI~I:' COMP CONTINUED TO RIH w/5-1/2" 17# SLHC TUBING TO 9,905'. LANDED STOP RING IN TOP OF PBR AT 9,905'. 17:00 - 21:30 4.50 RUNCOF~I:' COMP RU HOT OIL TRUCK AND DISPLACED WITH INHIBITED SEAWATER HEATED TO 130 DEGREES. 21:30 - 23:00 1.50 RUNCOr~F' COMP SPACED OUT TUBING. ADDED SPACE OUT PUP JOINTS. MU HANGER AND CONTROL LINE AND TESTED SAME. 23:00 - 00:00 1.00 RUNCOF~P COMP R / U SLICKLINE AND RAN 4.75" GAUGE RING TO SSSV. 8/31/2001 00:00 - 01:00 1.00 RUNCOr~F' COMP HELD PJSM. R / D CONTROL LINE SPOOL AND EQUIPMENT. NOTE: A TOTAL OF 54 STEEL BANDS RUN ON CONTROL LINE. 01:00 - 01:30 0.50 RUNCOI~ COMP M / U LANDING JOINT AND RIH w/TUBING HANGER. 01:30 - 03:.30 2.00 RUNCOI~P COMP R / U AND PRESSURE TESTED TUBING AND TUBING HANGER. 1st ATTEMPT FAILED, PULLED TUBING HANGER TO FLOOR, RETESTED TO 3,500 PSI f/30 MINUTES, OK. 03:30 - 04:00 0.50 RUNCOI~ COMP HELD PJSM. R / U HOWCO SLICK LINE. 04:00 - 06:30 2.50 RUNCOI~' COMP RIH w/SLICK LINE TO PULL DUMMY SLEEVE FROM SSSV. HAD TO MAKE 3 ATTEMPTS TO LATCH AND PULL DUMMY SLEEVE TO SURFACE. 06:30 - 08:30 2.00 RUNCOr~ COMP RIH w/SLICK LINE, LATCHED AND PULLED BALL / ROD FROM RHC SLEEVE IN X NIPPLE. 08:30 - 10:30 2.00 RUNCOI~F~ COMP RIH w/SLICK LINE, LATCHED AND PULLED RHC SLEEVE FROM X NIPPLE. 10:30 - 12:30 2.00 RUNCOI~P COMP RIH w/SLICK LINE AND RESET DUMMY SLEEVE IN SSSV. 12:30 - 13:30 1.00 RUNCOItP COMP CLEARED DRILL FLOOR OF ALL EXCESS EQUIPMENT. 13:30 - 14:00 0.50 RUNCOItF~ COMP :HELD PJSM TO COVER PUMPING OF COREDRILL N AND DIESEL FOR FREEZE PROTECT. 14:00 - 15:00 1.00 RUNCO~ P COMP PUMPED 40 BBLS OF COREDRILL N AND 144 BBLS OF DIESEL TO FREEZE PROTECT WELLBORE. PUMP RATE 3 BPM, PRESSURE 400 PSI. 15:00 - 17:00 2.00 RUNCO~ COMP SHUT DOWN PUMPS. OPENED TUBING TO IA AND ALLOWED DIESEL TO U-TUBE. 17:00 - 18:00 1.00 RUNCO~ COMP LANDED TUBING HANGER AND RILDS. DROPPED BALL/ ROD AND ALLOWED SAME TO FALL. COMPLETION EQUIPMENT SET AT THE FOLLOWING DEPTHS: ITEM LENGTH Printed: 9/4/2001 5:03:30 PM ......... Legal Well Name: 04-13i Common Vvell Name: 04-13i Spud Date: 8/19/2001 Event Name: VVORKOVER Start: 8/19/2001 End: Contractor Name: DOYEN Rig Release: 9/1/2001 Rig Name: Doyen 16 Rig Number: ~::: :~ ~:~:: ~i~ity ::1,,1~ ~h~e Description of Operations 8/31/2001 17:00- 18:00 1.00 RUNCOI~ COMP DEPTH SEAL / LOCATER ASSEMBLY 24.21' 9,926.00' TOP OF LOCATER 9,902.20' TAIL PIPE ASSEMBLY 126.53' j9,769.06' I XN NIPPLE ASSEMBLY 21.39' 9,747.67' 9-58" x 5-1/2" PKR ASSEMBLY 25.07' 9,722.60' X NIPPLE ASSEMBLY 21.43' 9,701.17' 181 JTS 5-1/2" 17.0# SLHC TBG 7,496.77' 2,204.40' SSSV ASSEMBLY 27.46' 2,176.94' 50 JTS 5-1/2" 17.0# SLHC TBG 2,074.05' 102.89' 5-5-1/2" 17.0# SLHC PUP JTS 36.88' 66.01' 1 JT 5-1/2" 17.0# SLHC TBG 41.86' 24.15' TUBING HANGER 3.90' 20.25' 18:00 - 21:30 3.50 RUNCOI~ COMP HELD PJSM. SET PACKER. OPENED IA. TESTED TUBING TO 3,000 PSI. PRESSURE BLED DOWN 400 PSI IN 15 MINUTES. FLUID CAME OUT OF IA. RETESTED-FAILED. SURGED PRESSURE BY PUMPING UP TO 4,500 PSI QUICKLY AND THEN BLEEDING OFF QUICKLY. REPEATED SURGING. RETESTED TUBING TO 3,000 PSI FOR 30 MINUTES. OK. 21:30 - 22:30 1.00 RUNCOI~P COMP OPENED OA AND TESTED IA. TESTED TO 3000 PSI. PRESSURE BLED OFF. FLUID LEAKED ABOVE HANGER INTO STACK. RETIGHTENED LDS. RETESTED IA FOR 30 MINUTES. OK. 22:30 - 23:00 0.50 RUNCOkP COMP LAID DOWN LANDING JOINT AND SET BPV. 23:00 - 00:00 1.00 RUNCO~ !:) COMP HELD PJSM. N / D BOPs. 9/1/2001 00:00 - 04:00 4.00 RUNCO~ COMP N / D BOPs. 04:00 - 05:00 1.00 RUNCO~/P COMP CHANGED OUT TUBING HANGER SEAL. 05:00 - 07:30 2.50 RUNCOF~ COMP INSTALLED TREE TEST PLUG. N / U ADAPTOR FLANGE AND TREE. 07:30 - 08:30 1.00 RUNCOF~ COMP FMC RIGGED UP AND TESTED CONTROL LINES TO 5,000 PSI, OK. 08:30 - 10:00 1.50 RUNCOI~ COMP FMC PRESSURE TESTED TUBING HANGER AND SEALS TO 5,000 PSI, OK. FILLED TREE WITH DIESEL AND TESTED TREE TO 3,500 PSI f/30 MINUTES, OK. CLEARED TREE OF DIESEL. PULLED TEST PLUG. SECURED WELL AND CELLAR AREA. RELEASED RIG AT 1000 HR 09 / 01 / 2001. Printed: 9/4/2001 5:03:30 PM Well: 04-13i, RWO Rig Accept: 08/19/01 Field: Prudhoe Bay Unit Rig Release: 09/01/01 APl: 50-029-20305-00 Permit: 178-031 Workover Ricj: Doyon 16 POST RIG WORK 09/09/01 Tag sand at 9970', jet to tag IBP at 10000', jet as pulling out of hole at 80%. Make up Baker fishing BHA. Set down in PBR at 9930'. 09/10/01 Made several attempts to pass through PBR at 9930', without luck. Pull out of hole to change toolstring. Run in hole and ran through PBR with no problems. Sat down at 9975'. Washed down to 9985', appears to be sand. Pull out of hole, found pieces of rubber and junk in equipment. Run in hole, dry tag at 9973', jet to 9998', reverse FCO to 9995'. Run in hole with Baker fishing BHA. Tag IBP and latch at 10004'. Jarred up with no apparent movement. Release fish, circulate hole over to dead crude. 09/11/01 Latch IBP, pull freely with no jarring. Pulled out of hole, no fish. Run back in hole with same fishing assembly, work on IBP. Made three passes onto IBP, pull out of hole with very little recovery of material. Run in hole with overshot fishing assembly, tag IBP at 10019'. 09/12/01 Pulled out of hole, recovered complete IBP, less rubber elements. Freeze protect well. 09/19/01 Ran in hole with wire grab, recovered metal shavings, IBP element and chunk of shale. Ran dummy perf gun, tight at tubing tail. Tag TD at 10684' wlm. Ran dummy gun, unable to pass out of tubing tail. 09/20/01 Unable to get through float shoe of 3ol/2" scab liner at 10464'wlm, there is a piece of rubber stuck on spangs. Ran wire grab and recovered second IBP element. Ran swage and worked tight spot at 10464' wire until smooth. Tagged TD at 10686' wIm (bottom shot at 10486'. Leave well shut-in. 09/23/01 Drift with 2-1/2" dummy gun to 10682' wIm. Perforate 10464' to 10486' with powerjet 2506 charges at 6 spf. 09/29/01 MITIA, passed. STATE OF ALASKA ALASKA oIL AND GAS CONSERVATION COMM~,.sSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: I-I Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 32' NSL, 4838' WEL, SEC. 26, T11N, R15E, UM At top of productive interval 1420' SNL, 3478' WEL, SEC. 34, T11N, R15E, UM At effective depth 1398' SNL, 3886' WEL, SEC. 34, T11N, R15E, UM At total depth 1389' SNL, 4005' WEL, SEC. 34, T11N, R15E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service RECEIVED AUG 0 1 ?.001 Alaska 0il & Gas Cons. Commission Anchorage 6. Datum Elevation (DF or KB) RKB = 64' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 04-13i 9. Permit Nur~ber 178-031 ,~ 10. APl Number 50- 029-20305-00 ·. ' 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 10845 feet Plugs (measured) / 8993 feet '-' 10673 feet Junk (measured) 8869 feet IBP set at 10004' (05/01); Sand on top at 9979' (05/01) Tagged PBTD at 10673' (02/00) Length Size Cemented M D TVD Structural Conductor 111' 20" 320 sx Arcticset II 111' 111' Surface 2692' 13-3/8" 6400 sx Arcticset II 2692' 2692' Intermediate Production 10826' 9-5/8" 900 sx Class 'G' 10826' 8979' Liner Scab Liner 437' 3-1/2" 22 Bbls LARC 10023'- 10460' 8409' - 8719' Perforation depth: measured 10512'- 10522', 10570'- 10610', 10630'- 10666', 10678'- 10685', 10694'- 10703', 10714'- 10724' Sqzd: 10222' - 10440' true vertical 8755' - 8762', 8796' - 8824', 8838' - 8864', 8873' - 8878', 8884' - 8891', 8899' - 8906' Sqzd: 8551'- 8705' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 10054' Packers and SSSV (type and measured depth) Baker '3-H' packer at 9950'; Camco BaI-O SSSV Nipple at 2201' 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation August 18, 2001 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Skip Coyner, 564-4395 [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Prepared By Name/Numbec Terrie Hubble, 564-4628 17. I hereby certify that is true and correct to the best of my knowledge Signed Title Drilling Engineer Date Skip Coyner Conditions of Approval: Notify Commission so representative may witness '~.,~{~)(,.~ ~:~, ~"'~ .~~ I p rova, No. Plug integri~ BOP Test ~. Location clearance Mechanical Integri~ Test ~ Su~r~~~;~~ Approved by order of the Commission ..J. :~. H~r Commissioner Date ~/'~ ~ Form 10-403 Rev. 06/15/88 L ~ ~-"~ ~ ~'~ ~J ~ ~ Submit In Triplicate RD/l/ ,, BP ALESI(A DRllLIH8 ~ ~ BP Exploration DOYON 16 Well' 04-13 Workover AFE: 4J9128 Classification' AFE Amount: Capital Work Over $1,250,000 Days: 12 Estimated Workover Date: July 26, 2001 Prepared By: Skip Coyner WELL OBJECTIVES: 1. NO ACClDENTS 2. NO SPILLS OR ENVIRONMENTAL VIOLATIONS 3. NO POLICY OR REGULATORY VIOLATIONS 4. MEET OR EXCEED COST AND QUALITY OBJECTIVES 5. REVIEW AND FOLLOW ALL PROCEDURES No portion of this work is so urgent that time cannot be taken to do it without injuring yourself or others Approved By: Drilling/WO Engineer Date Distribution: Steve Rossberg I Copy D. Babcock 1 Copy S. Coyner 1 Copy Well File 1 Original Doyon Rig 16 6 Full copies Baker- Mail Slot 1 Copy Baroid - Mail Slot 1 Copy Doyon - Mail Slot 1 Copy Schlumberger- Mail Slot 1 Copy Halliburton - Mail Slot Contacts Drlg. Superintendent Drilling/WO Engineer Pad Engineer Drilling Superintendent Date Attachments: Tubing Tally Current Well Schematic Proposed Well Schematic Back Up Plan Well Schematic Halliburton Cement Recommendation Drill Site 4 Plat Name Work Home Cell Steve Rossberg 564-5637 345-7634 240-8069 Skip Coyner 564-4395 622-0030 440-0191 Dan Babcock 564-5735 746-0274 250-1466 Current Well Information Well Name: APl Number: Well Type: Current Status: 04-13 50-029-20305 Injection The well has IA x OA communication BHP: BHT: 3450 psi @ 8800' TVDss Ivishak 210 o F @ 8800' TVD ss. Mechanical Condition: Tubing: 5-1/2", 17 #/ft, L-80 to the packer at 10711'. A 3-1/2" CT liner is hung in the tail pipe at 10786'. The 3-H packer has an 18' PBR and Iocator seal assembly pinned to 74,000#. There is an SSSV nipple with control lines at 2201'. See current schematic. Casing: There is a leak in the 9-5/8" casing: +/- 2 gpm at 2700 psi. The IA x OA CMIT tested to 2000 psi. OK. An "FO" tool is un-cemented at 2370'. A cemented "FO" tool is at 2496'. TD / PBTD / Fill: Kick Off Point: Maximum Angle: Max Dogleg of interest: PBTD 10845' MD 3400' MD 48° at 7400' MD 5.2°/100' at 7500' MD Well Head: Tbg. Spool: Tbg. Hanger: Tbg. Head Adapter: Tree: BPV Profile Nipple: SSSV: Control line clamps SS Control line bands: Gray, 13-5/8" (5M) Gray, 13-5/8" (5M) Gray, Gen II, 13-5/8" x 5" (5M) 4.562" CAMCO, BAL-O Flapper type SSSV 28 Standard Clamps 4 steel bands Open Perfs: Squeezed Perfs: 10512' -10522', 11570' -10610', 10630' -10666', 10678' -10685' 10222' -10262', 10277' -10345', 10360' - 10375', 10390' -10440' Tubing Fluids: Annulus Fluids: Sea water / diesel Sea water / diesel 9-5/8" PPPOT, lC: MIT, IA: CMIT IA x OA: Passed 2/03/01 Failed 5/14/00 Passed 5/14/00 (2000 psi) Completion: Materials Required for Workover Operations 10,000' lx10' 1 1 1 1 1 1 5-1/2", 17#, L-80, NSCT Tubing Locator Seal Assembly for BOT PBR: 6" OD x 4.75" ID Baker, 9-5/8" x 5-1/2" SB-3 Stacker/Packer (back up plan) 5-1/2", "X" Nipple 5-1/2", "XN" Nipple 5-1/2" SSSV Nipple Tubing hanger and adapter flange with control line fittings (if needed) 5"x 5000 psi carbon tree (if needed) 04-13 RWO Page 2 Short Scope There is pressure communication between the IA and OA indicating a 9-5/8" casing leak. The 9-5/8" packoffs have tested good. The IA x OA communication will be repaired by cementing the OA. The 5-1/2" tubing will be replaced with premium, L-80 tubing. This well is being converted to a WAG injector. Drilling Hazards and Contingencies ***See Pad Data Sheet for details of previous wells drilled on DS 04 1) Hydrogen Sulfide DS 04 is considered an H2S drill site. However, Standard Operating Procedures for H2S precautions should be reviewed and followed at all times. The most recent level of H2S measured near DS 04-13 bottom hole location was 615 ppm from well 04-40 on 1/10/01. The highest concentration seen on DS 04 to date is 1500 ppm from well 04-49. (See Pad Data Sheet). Reference: Hydrogen Sulfide under Standard Operating Procedures 2) Well Control Pressures · Production Section max anticipated BHP: · Production Section max surface pressure: · Planned completion fluid: 3450 psi (7.5 ppg EMW) @ 8800' TVD - Ivishak 2570 psi (based on BHP & full gas column at 0.1 psi/ft) 8.5 ppg sea water / 6.8 ppg diesel Drilling Program Overview Surface Issues Rig Move Issues and Shut-in Requirements: There is no surface shut in requirements for the rig move to 04-13. The nearest adjacent wells are 04-27 (60' away) and 04-26 (59' away). Workover Fluid Program and Properties I Sea water I Present Casing/Tubing Program- Csgrrbg OD #/Ft Grade Conn Length Top (MD) Btm (MD) 20" 94 H-40 Welded 111' Surface 111' 13-3/8" 72 L-80 BTC 2692' Surface 2692' 9-5/8" 47 N & S BTC 10826' Surface 10826' 3-1/2" CT liner 9.3 L-80 CT 912' 10027' 10460' 5-1/2" tubing 17 L-80 AB Mod 9930' Surface 9930' Proposed Tubing Program: I ~-l/2"tubing I 17 I L-80 I NSCT I 10690' I Surface I 10690' 04-13 RWO Page 3 04-13 RWO Detailed Operations Pre-Rig Operations 1. Flush the tubing with + 350 bbl of produced water. Set an IBP in the 5-1/2" tubing tail at _+ 10,010' MD. Pressure test IBP to 1000 psi (note: pressure limited due to IA x OA communication). Dump + 25' of sand (or CaCO3) on top of the IBP. 2. Chemically cut the 5-1/2" tubing at_+ 9900' MD'. 3. Circulate the well with produced water. 4. Freeze protect the tubing, IA and OA with diesel from 2000' to surface. 5. Set a BPV and remove the wellhouse. 6. Clear and level the pad in preparation of the rig move. Ri_cl Ol~erations * Review the Hydrogen Sulfide Standard Operating Procedures prior to opening the well * * Complete a pre-rig inspection with the DS Operator prior to the rig moving on the well * * Notify the AOGCC representative 24 hours in advance to witness BOP testing * 1. Note tubing and annular pressures (trapped gas). Bleed-off as required prior to MIRU. MIRU workover rig. RU to the tree to circulate out the diesel freeze protection. Pull BPV with lubricator. Confirm the amount of diesel used to freeze protect on the hand over form. Circulate out the diesel freeze protection and displace it with seawater. Confirm the well is dead. Install the TWC and test to 3500. Nipple down the tree and adapter. Send tree and adapter in for inspection and/or repairs. The adapter and tree will be reused if possible. NORM test all well head and retrieved completion equipment. Reference 'De-Completions' RP for details. 2. Nipple up and test the BOPE. Test the BOP equipment to 250 psi Iow and 3500 psi high. Test the annular to 250 psi Iow and 3500 psi high. Pull the TWC with lubricator. 3. PU landing joint and screw into the tubing hanger. Pull and lay down the tubing hanger. Note the length from the drill floor to the bottom of the tubing hanger = "B" to be used for space out later. Send in the hanger for inspection. Pull and lay down the control line. Four steel bands and 26 clamps were run on the control line. Have spooling unit rigged up to recover the control line. An SSSV Nipple will be run in this well when re-completed. Inspect all completion equipment for NORM. Reference: SSD Decompletion RP . . , Pull and lay down the 5-1/2" tubing from the cut at 9900'. Try not to exceed 50% of the 5-1/2" tubing body tensile rating (198,500 lbs). NOTE: Estimated buoyed string weight in seawater down to the cut is _+146,400# + the blocks, etc. RIH with an overshot and fishing BHA on drill pipe. Dress the overshot to catch the 5-1/2" tubing stub. Use a cut lip guide with mill control. Check the string weight. Engage the fish with the pump idling and note the pressure increase. Kill the pump and swallow the fish. Pull the PBR seal assembly, which is pinned to shear at + 74,000# (jar if necessary). Pump a Hi-Vis sweep and circulate the well clean with seawater. POOH. LD the fish and overshot. Note the condition and caliper the OD/ID of the seal assembly. A leak exists between the 9-5/8" and 13-3/8" casing string. Set a 9-5/8" RTTS at +/- 100'. Close the pipe rams and test the wellhead to 3000 psi. Bleed off, open and monitor the OA while pressure testing. Even though the PPPOT-IA passed, the leak may still be in the wellhead. If no leak is found in the wellhead, proceed with step 6 below. There is a cemented "FO" tool at 2496' and an un-cemented "FO" tool at 2370'. The current leak is small but it has communication to the surface in the OA; therefore, the leak is probably in (or above) the top "FO" tool. RIH with a 9-5/8" RTTS and RBP to locate the leak. Bleed off and monitor the OA while pressure testing. Set the RBP at _+ 2800' and set the RTTS at _+ 2600'. Test the RBP to 3000 psi. Re-set the RTTS at + 2430' (between the "FO" tools). Test below the RTTS to 3000 psi. Re-set the RTTS at + 2200' (above both "FO" tools). Test below the RTTS to 3000 psi. Then test above the RTTS to 3000 psi. Re-set the RTTS and re-test as needed to locate the leak. 04-13 RWO Page 4 7. Once the leak is located, dump sand on the RBP, POOH and prepare to cement the OA. . . 10, 11. 12. 13. RU WL. Run a CCL strip log from +/- 2700' to 1000' to confirm the location of the "FO" tools, etc. Perforate 8 squeeze holes in the 9-5/8" casing just below the "FO" tool at 2370' or as appropriate. Note: Arctic Pack was left in the OA in 1978). RD WL. Close the rams and establish circulation through the perforations. (Note: it is assumed that the "FO" tool is not functional and we do not intend to use it). Set a Cement RTNR +/- 100' above the squeeze holes on drill pipe. Break circulation with heated produced water and circulate the OA clean in preparation for cementing. Recover and properly dispose of the Arctic Pack from the OA (+ 137 bbl). Pump detergent, Hi-Vis sweeps and heated seawater, etc. as necessary to remove the Arctic Pack fluid and clean the OA. Pump at maximum rate while displacing and cleaning the OA. RU Halliburton complete with squeeze manifold (drill pipe & OA). Test to lines 3000 psi. Close the annular BOP and pressure the IA to +/- 500 psi with the rig pump and monitor the IA while cementing. Mix and pump + 400 sx of Type "E" Permafrost cement. Tail in with 100 sx of Premium + 2% CaCI2. Displace the drill pipe to the RTNR with fresh water. Reverse + 2 bbl of dead oil (or other freeze protect fluid) down the OA to clear the valves, etc. Shut in the OA. Pressure up below the RTNR to 1000 psi. Bleed off the IA. Pull out of the RTNR and LD 1 int. Reverse circulate + 200 bbl of produced water (+ 100° F). POOH. Note: Pilot test the cement slurries using actual mix water. The desired pump time is _< 2 hours. Run compressive strength tests to determine drill out time. Catch and monitor surface samples for initial set time. After initial set of the cement, RIH with an 8-1/2" bit and BHA. Drill out the RTNR and cement to 20' above the perforations. Test the casing to 3000 psi. Drill the remaining cement and re-test the casing to 3000 psi. RIH. Clean out sand and debris to the RBP at +/- 2800'. Circulate the hole clean at max rate with seawater. Sweep the hole with Hi-Vis pills as needed while drilling cement. LD 2800' of drill pipe. RIH with a bit and casing scraper to the RBP. Circulate bottoms up. LD 2800' of drill pipe and the BHA. RIH with RBP retrieving tool. Wash down to the RBP and circulate the hole clean above the RBP. Catch and release the RBP. POOH. Lay down remaining drill pipe and tools. Run 5-1/2", 17#, L-80, NSCT tubing with a new (or re-dressed) seal assembly for the existing PBR. Above the seal assembly, run a 10' pup, a 5-1/2", "X" nipple and another 10' pup. Run the SSSV Nipple with 4.562" ID at _+ 2,200' MD. Run 10' pup joints above and below the SSSV Nipple. Be sure to drift the "X" nipple and SSSV before RIH. Drift and Rabbit the tubing. Run and test the control line for the SSSV. Back up plan: If the PBR is not re-usable (from step 4 above), a stacker/packer will be run. If so, run the old PBR seal nipple w/o seals to align the tubing tail in the old PBR. Run the old seal nipple followed by a 10' pup jnt, an "XN" nipple (w/RHC sleeve) and another 10' pup jnt. Run a mill out extension and the new SB-3 stacker/packer. Above the stacker/packer, run equipment as described in the previous paragraph. 5-1/2", 17#, L-80, NSCT Collapse Burst Tensile ID Make-up Torque 100% 6280 psi 7740 psi 397,000 lb 4.892" ID 4950 ft-lb rain 80% 5020 psi 6190 psi 317,000 lb 4.767" Drift 6050 fi-lb max **Use "Best-O-Life 2000" Thread Compound 14. Tag the old PBR and "space out" the tubing. MU the tubing hanger, control lines and landing joint. Length from DF to the 1st collar below the Tubing head = "A" Length from Drill Floor to the bottom of Tubing Hanger - "B" Length of Seal Assembly to the bottom of its Iocator -- "C" Pick up Length for Flowing Temperature Compensation -- "D" A - B + C - D = Length of subs needed below the Hanger 04-13 RWO Page 5 15. 16. 17. Close the pipe rams and displace the IA with clean seawater containing corrosion inhibitor followed by 140 bbl of diesel. Tie in the IA to the landing joint. U-tube + 46 bbl of diesel from the IA into the tubinq to freeze protect to 2000'. Allow the tubing and IA to equalize. Open the pipe rams. Lower the tubing ~nd sting into the packer. Land the tubing hanger in wellhead. RILDS. Back up plan: If the stacker/packer was run, sting into the PBR with the stripped down seal nipple and land the tubing hanger. RILDS. Drop the ball/rod. Pressure up on the tubing and set the packer. In either case, test the packer seals, IA and tubing hanger to 3000 psi for 30 minutes. Test the tubing to 3000 psi for 30 minutes. Set a BPV in the tubing hanger. Back out the landing joint and circulate any remaining diesel, etc. out of the BOPE with seawater. Lay down the landing joint. ND BOPE. NU the 5" x 5,000 psi Tree. Test the tree to 3500 psi for 30 minutes using a TWC. Replace the TWC with a BPV using a lubricator. 18. RD and MO Rig 16. * Complete a post-rig inspection with the DS 04 Operator prior to the rig moving off the well * Post-Rig Operations 1. Retrieve the BPV. 2. RU CTU. RIH and circulate the sand (or CaCO3) off the IBP in the 5-1/2" tubing tail (recover the freeze protect fluid). Retrieve the IBP. Rd CTU. 3. Hook up flow lines. Hook up control lines. Replace the wellhouse. 4. POP. 04-13 RWO Page 6 TUBING TALLY SHEET Well- Well: 04-13 No. Item 1 52 1 1 1 1 1 185 1 1 1 1 1 2 2 2 1 RKB - Tbg Hd Flange Gray- Tubing Hanger & Pup Jnt. 5-1/2, 17#, L-80, LTC-Mod Tubing 5-1/2" Pup Jnt. 5-1/2" Flow Coupling CAMCO SSSV 5-1/2" Flow Coupling 5-1/2" Pup Jnt. 5-1/2, 17#, L-80, LTC-Mod Tubing 5-1/2" Pup Joint: AB-Mod PBR w/Seal Nipple BOT, 3-H Packer Mill Out Extension 5-1/2" X-O 5-1/2, 17#, L-80, LTC-Mod Tubing 5-1/2" CAMCO "DB" Nipple 4-1/2" pup joints Shear out sub Length 27.50 5.60 2152.31 9.40 6.02 6.17 6.01 10.04 7701.07 6.15 19.49 5.33 6.54 0.92 77.84 2.50 10.02 1.23 Date: 6/11/85 Top I.D. O.D. 27.50 4.892 33.10 4.892 5.500 2185.41 4.892 5.500 2194.81 4.892 5.500 2200.83 4.562 5.500 2207.00 4.892 5.500 2213.01 4.892 5.500 2223.05 4.892 5.500 9924.12 4.892 5.500 9930.27 4.750 6.000 9949.76 4.750 8.312 9955.09 5.625 6.250 9961.63 4.892 7.375 9962.55 4.892 5.030 10040.39 4.313 5.000 10042.89 4.892 4.500 10052.91 4.892 4.500 End Of Tubing 10054.14 04-13 RWO Page 7 2692' Well No.: 04-13i (Current) ;_~.¥.- ~':::-'.- IA x OA Communication ~ FO Tools at 2370' & 2496' 13-3/8", 72#, L-80 BTC 5-1/2", 17#, L-80 Tubing BOT, 7" x 6" x 4.75" PBR 3-H PKR at 9950' 5-1/2" Tail Pipe assembly 3-1/2" CT Liner: 10027'- 10460' 10826' Perforations: 10512' - 10685' 9-5/8", 47ff Casing 04-13 RWO Page 8 2692' Well No.: 04-13i (Proposed) Cement circulated to surface Between the 9-5/8" & 13-3/8" FO Tools at 2370' & 2496' 13-3/8", 72#, L-80 BTC New 5-1/2", 17#, L-80 Tubing BOT, 7" x 6" x 4.75" PBR 3-H PKR at 9950' 5-1/2" Tail Pipe assembly 3-1/2" CT Liner: 10027'- 10460' 10826' - Perforations: 10512' - 10685' _ ~.';iiii~iii~iiiii~:iiiiii~i~, 9-5/8", 47#, L-80 Casing 04-13 RWO Page 9 2692' 10826' Well No.: 04-13i .;~,;~ (Back Up Plan) ~ Cement circulated to surface iBetween the 9-5/8" & 13-3/8" FO Tools at 2370' & 2496' 13-3/8", 72#, L-80 BTC New 5-1/2", 17#, L-80 Tubing SB-3 Stacker/Packer BOT, PBR Seal Nipple Guide 3-H PKR at 9950' 5-1/2" Tail Pipe assembly 3-1/2" CT Liner: 10027' - 10460' Perforations: 10512'- 10685' 9-5/8", 47#, L-80 Casing 04-13 RWO Page 10 Up-coming workovers: Prodhoe Bay workovers: Prodhoe Bay ~,~.~ ---(~ '-~ Subject: Up.coming Date: Tue, 31 Jul 2001 18:47:36-0500 From: "Coyner, Vern M" <CoynerVM@Bp.Com> To: 'tom_maunder@admin.state.ak.us'" <tom_maunder@admin.state.ak.us> As you know we are in the midst of a workover campaign at GPB. Thus far, we have done tubing swaps on SI producers. The next two are tubing swaps & casing repairs on SI injectors. It is now my understanding that a sundry notice must be filed for work on injectors. This is in the works but has not yet been done. My appologies ~ it's my fault. I would ask for permission to proceed with the first workover: 04-09i. APl# 50-029-20207 AOGCC #1760300 This workover entails: * Replace corroded tubing with new, L-80, premium tubing * Locate leak(s) in the 9-5/8" casing and squeeze cement as appropriate * Restore both tubing and IA mechanical integrity * Convert the well to Water/Gas injection. Your attention in this matter is greatly appreciated. Sundry Notice to follow. If you have any questions, please advise. Note: well 04-13i is exactly the same workover plan. APl# 50-029-20305 AOGCC #1780310 Sundry Notice to follow for this well, too. Skip Coyner Drlg/VVO Engr (907) 564-4395 (907) 440-0191 <<DS 04-09 Back Up Plan.ppt>> <<DS 04-13 Back Up Plan.ppt>> iDS04-09 Back Up Plan.ppt Type: Microsoft PowerPoint Show (applicationlvnd.ms-powerpoint) Name: DS 04-09 Back Up Plan.ppt Encoding: base64 t i Name: DS 04-13 Back Up Plan.ppt ~DS 04-13 Back Up Plan.pptI Type: Microsoft PowerPoint Show (applicationlvnd.ms-powerpoint) ! Encoding: base64 1 of 1 8/3/01 1:14 PM Re: RWO's, 4-09i & 4-13i Subject: Re: RWO's, 4-09i & 4-13i Date: Thu, 02 Aug 2001 15:51:05 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Coyner, Vern M" <CoynerVM@BP.com> Skip, Thanks for the information. ! hope our discussion helps the work. The only other item I can think of is that when the rig are testing the "squeezes", I would recommend that a chart recorder be employed. When an injector is employed in MI service, the pressure test of the annulus must be acceptable. The Commission does not allow an injection well to be in gas or MI service with an MIT failure. Good luck. Tom Maunder, PE Petroleum Engineer AOGCC "Coyner, Vern M" wrote: To answer some of your questions from this morning: 1. During the leak rate test on 4-09i, returns were taken from the OA. 2. During the leak rate test on 4-13i, returns were taken from the OA. 3. Well 4-09i was circulated with seawater during rig prep. 4. Well 4-13i was circulated with seawater during rig prep. 5. The CCL to be run in 4.09i will start at +/- 3000'. Thanks for catching that one. 6. On both wells, we will run the new completion, button up the tree, freeze protect & then set the packer. No diesel in the stack. Skip Coyner Drlg/WO Engr (907) 564-4395 (907) 440.019I Tom Maunder <tom maunder~.admin.state.ak, us> '1 Petroleum Engineer Alaska Oil and Gas Conserva'don Commission I of 1 8/3/01 12:37 PM Pr¢' - WELL: 04-13 Annular Communication FROM: HISTORICAL REPORT 7/5/96 Beginning TO: 07/05/96 WELL TYPE: W ! PROBLEM: T x IA x OA Communication. DATE 3/26/95 7/9/95 7141% DESCRIPTION OF WORK T/I/O=2200/1420/1000. MITIA PASSED @ 3000 psi: lost 220 psi in 30 min. Well on PWI inj. Screening for 11-27 & State MIT. 1 1/5 bbl meth, all recovered. Final WHP's 2200/500/75 T/I/O=2000/800/750 MITIA PASSED; Bled IA from 800 psi to 600 psi in 10 minuets. Both gas and liquid were bled from IA. IA was then pressured to 2200 psi 180 psi was lost in 30 min. OA gained 325 psi in the same 30 min. Pumped 2.5 BBLs of methanol. CMIT IA X OA PASSED; Pressured both IA and OA to 2210 psi they lost 50 psi in 30 minutes. Pumped an additional 1 BBL of methanol for a total of 3.5 BBLs. Final WHP=2000/750/750 T/I/O=1800/700/650 MITIA to 2500 psi PASSED; IA FL @ surface. MITIA lost 170 psi in 30 mins. Pumped 3 bbls of methanol total. Final WHP's = 1800/300/700. Annular Communication FROM: HISTORICAL REPORT 7/5/96 Beginning TO: WELL: 04-13 WELL TYPE: WI O7/O5/96 PROBLEM: T x IA x OA Communication. DATE 10/31/92 2~4~93 2~7/93 2/8/93 11/3/93 11/4/93 DESCRIPTION OF WORK T/I/O=850/590/490 psi. Review of 3 pen data indicates that rate of TxIA communication continues to be too small to detect with conventional LDL operations at this time. Well history under review to determine if AOGCC should be notified. T/I/0=1000/1200/1100, well on injection, installed 3-pen recorder. OA has increased. T/I/O=1100/750/750. DSO dropped inject, press from 1550 to 1100 psi. The IA & OA tracked and they dropped from 1050 to 750 psi(3-pen froze). T/I/O=1100/380/380, well on inj. Changed 3-pen. T/I/O = 1750/900/750, injecting water. Shot FL's pre-MIT for waiver compliance: IA & OA both at surface. T/I/O = 1800/870/820, injecting water. Shut in injection and performed IAxOA CMIT to 2000 psi for Waiver Compliance: PASSED. IA lost 120 psi/30 mink OA lost 160 psi/30 min. Repeated MIT: IA lost 100 psi/OA lost 160 psi/30 min. Returned to injection. 7/1/94 7/2/94 713194 T/I/O= 1950/1250/1150, injecting water. IA fluid level @ surface. Prep for State witnessed MITIA. T/I/O= 2000/1150/1020, Injecting Water. OA FL @ surface. Prep for witnessed IA x OA CMIT. Performed State Witnessed MITIA to 2125 psi: PASSED. "-125 psi/30 min. OA increased from 1125 to 1400 psi, as expected. Performed 9x13 comb MIT to 2070/2000 psi(IA/OA): PASSED. +20 psi/30 rain on IA\ -60 psi/30 min on OA. Annular Communication HISTORICAL REPORT 7/5/96 FROM: Beginning WELL: 04-13 WELL TYPE: WI PROBLEM: T x IA x OA Communication. TO: 07/05/96 DATE 9/21/92 9/22/92 10/6/92 10/18/92 10/19/92 10/20/92 DESCRIPTION OF WORK Notified of T X 9 communication. Injection well showed "up on UIC Report .... exception .... list. Initial T/9:750/6 psi. After Bleed T/9:750/200 psi. After 1 hour the"9-5/8 .... had increased from 200 psi to 325 psi. Well is" currently waivered for 9 X 13 communication to liquid. Well and annulus history will be reviewed to determinemost appropriate leak detection options (if any). "T/9/13: 800/580/450psi. Initial FL's: 9-5/8 .... @" "surfacer 13-3/8 .... @ surface. Stung into T X 9 packoff 50 psi. Bled to 0 psi. Stung into 9 X 13 packoff- 0psi. No evidence of communication via wellhead "Well last passed a 9-5/8 .... MIT during October 1991. A" waiver compliance MIT to 2000 psi has been scheduled. "Following the MIT, it is recommended to RU a 3pen .... recorder, bleed the 9-5/8 .... pressure down and monitor th rate of pressure buildup to determine if/how much the leak has worsened and if it is large enough to detectwith conventional leak detection options. Completed annual waiver compliance combo 9 X 13 MIT to "2000 psi (PASSED) with the Tubing at ~ 500 psi. 9-5/8 ...... declined 30 psi while the 13-3/8 .... declined 80 psi durinthe 30 minute test. This may be indicative of a "slightly leaking 13-3/8 .... shoe. Plan to bleed 9-5/8' ...... 'below tubing pressure and monitor rate of 9-5/8 ...... pressure buildup. Initial T/I/O=480/520/400 psi. Bled IA to 200 psi in 15 min. RU 3 pen recorder to monitor rate of T to IA PBU. T/I/O=850/620/520 psi.(AM) IA has increased --10 psi during the past 12 hours. T/I/O=900/520/420 psi. (PM) 10/21/92 T/I/O=800/520/420. Monitoring for rate of IA buildup. Annular Communication HISTORICAL REPORT 7/5/96 FROM: Beginning TO: 07/05/96 WELL: 04-13 WELL TYPE: WI PROBLEM: T x IA x OA Communication. DATE 6/4/91 6/8/91 6/12/91 6/23/91 7/1/91 10/30/91 7/15/92 DESCRIPTION OF WORK T/9/13 (1940/1500/1460 psi). 9-5/8 and 13-3/8 are both fluid packed. Bled 9-5/8 from 1500 to 380 psi in 5 minutes\ all dirty diesel. Bled 13-3/8 from 1460 to 520psi in 5 minutes\ bled some water then arctic pack. T/9/13 (750/320/220 psi). Review of 3 Pen recorder 'data "for past 7 days indicates Tubing X 9-5/8 .... x 13-3/8" ..... 'communication. Both 9-5/8 .... and 13-3/8 pressures are"tracking the tubing pressure. Both the 9-5/8 and 13-3/8 were bled on 6/4/91 from --1500 psi to ~500 psi. Pressures on both tend to rise ~4 psi/hr. Will continueto monitor the rate of pressure buildup. Recommend periodic bleeding with monitoring. "Checked 3-pen recorder. All lines open to 3-pen, in" working order. Continuing to monitor. T/9/13 (960/1000/960 psi). Replaced 3 pen chart\ chart shows that 9-5/8 and 13-3/8 pressures have been fairly steady in the range of 600 to 800 psi. Review of recent annulus pressure trends indicates well is continuing to operate within the waiver guidelines. No further AC eval required at this time. Completed annual waiver compliance testing. Combination "9-5/8 .... X 13-3/8 .... MIT to 2000 psi passes. There is som "evidence of a slight 13-3/8 .... leak developing, however, "13-3/8 .... MIT to 2000 psi with the 9-5/8"" @ 560 psi .... PASSED. The 13-3/8 .... pressure declined 200 psi during .... the 30 minute test, while the 9-5/8 .... pressure remained"at 560 psi. Completed combination 9 X 13 MIT to annual waiver compliance testing (PASSED). WELL: 04-13 Annular Communication FROM: HISTORICAL REPORT 7/5/96 Beginning TO: 07/05/96 WELL TYPE: W I PROBLEM: T x IA x OA Communication. DATE 12/1/90 4/28/91 4/29/91 5/1/91 5/15/91 5/19/91 5/24/91 6/3/91 DESCRIPTION OF WORK "Approved, revised, Waivered Well Notice received and" "distributed. New Waiver Guidelines: 1) Operate 9-5/8 ...... annulus at <2000 psi. 2) Increase the 13-3/8"" operating"pressure limit from 1000 tp 2000 psi. 3) Perform annual, "combination 9-5/8 .... /13-3/8 .... MIT to 2000 psi. 4) Report" pressures daily on the Troubled Well Report. T/9/13 (2000/1860/1740 psi) 9-5/8 FL @ surface. 13-3/8 FL @ surface. Rigged up a 3 pen chart recorder to see how closely 9/13 pressures track tlhe tubing. T/9/13 (1720/1980/1920 psi). Rigged up 3-pen chart recorder. T/9/13:2020/1880/1780 psi. Well is waivered for "9-5/8"" X 13-3/8 .... communication to A/L. Per waiver .... guidelines, 13-3/8 .... annulus pressure is allowed to"operate up to 2000 psi. Well is operating within Waiver guidelines. RD 3 pen. No further AC eval required at this time. 3-pen left on well. During past week 13 tracking 9-5/8. 9-5/8 increased from 1950 to 2040 and 13 increased from 1850 to 2000.DSO bled. Continuing to monitor. Change out 5 day chart. T/9/13 (2200/1480/1320) T/9/13 (2080/1740/1700 psi). Well is on SWI. Review of 3 Pen recorder data for past 7 days indicates "possible Tubing X 9-5/8"" communication in addition to .... the already documented 9-5/8 .... X 13-3/8 .... communication."9-5/8"" pressure is tracking the tubing pressure." T/9/13:(2000/1680/1640 psi). It is recommended to "bleed the 9-5/8 .... and 13-3/8 .... pressure down and monitorthe rate of pressure buildup. Annular Communication HISTORICAL REPORT 7/5/96 FROM: Beginning TO: 07/05/96 WELL: 04-13 WELL TYPE: WI PROBLEM: T x IA x OA Communication. DATE 10/14/88 lO/15/88 10/16/88 10/17/88 10/21/88 10/26/88 10/20/89 10/11/90 11/4/90 DESCRIPTION OF WORK "Failed MIT, 9-5/8 .... x 13-3/8"" leak." All packoffs tested good. "Passed MIT with both 13-3/8 .... & 9-5/8 .... under pressure" "verifying 9-5/8"" leak is above 13-3/8 .... shoe." Verbally notified State. Approval granted to leave well on injection for 1 week with a formal request to extend injection past one week. Formal Sundry applicaton for continued H20 injection submitted to State. Received State approved Sundry for continued water injection service. "Simultaneous 9-5/8 .... and 13-3/8 .... MIT to 2180 psi - PASS (For Waiver compliance) Completed annual waiver compliance testing. Well is in waiver compliance. Combination 9/13 MIT @ 2000 psi. 9-5/8 Delta Pres.= 20 psi in 30 mink 13-3/8 Delta Pres.=100 psi in 30 rain: PASSED. "Completed combination 9-5/8 .... / 13-3/8 .... MIT to 2000 psi with the well shut-in (PASSED). Both annuli decreased 130 psi during 60 minute test. Initial T/9/13:(200/2040/2040 psi). Final T/9/13: (200/1910/1910 psi). 11/6/90 Revised waiver circulating for Management approval. GeoGuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'ri'N: Sherrie NO. 9930 Company: 12/15/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 4-8 '~ ~c> l~) INJEC PROFILE 9 511 0 9 I 1 D.S. 4-13 "7_~. ~] INJECPROFILE 951109 I 1 D.S. 4-17-~(~ '~..O INJECPROFILE 951118 I 1 D.S. 4-19 ~ ;2.~/ DUAL BURST TDT-P 951112 I 1 D.S. 4-28 ~ f' ,,3~~c~.~~13 INJECTION PROFILE 951110 I 1 D.S. 5-4 PROD PROFILE 9511 15 1 1 D.S. 9-04A PROD PROFILE 9511 1 0 I 1 D.S. 14-16 ~[. ~1~_. PROD LOG WlTH DEFT 951107 I 1 D.S. 14-19 ST1 ~~'-~ PROD PROFILE 951119 I 1 D.S. 16-02 ~(~t { ~"(~ MI INJECTION PROFILE LOG 9 5111 9 I 1 D.S. 18-23A ~ '~ I ~ ~ LEAK DETECTION LOG 95111 4 1 I SIGNED:~~_~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'n'N: Sherrie APR 2 ? 1995 Alaska Oil & Gas Cons. CoDIIItiSSiOD A~chorage NO. 9431 Company: 4/26/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S 2-24 ~3.-"7 ! CNT-D 040695 I 1 D.S. 3-13 "/C~- '71 PERFRECORD 040795 I 1 D.S, 3-13 ~ i ' ~ PERFRECORD 040895 I 1 D.S. 4-13 '7 ~'- ~ ~ INJECTION PROFILE 040795 I 1 D.S. 9-10 '7 ~' 3 ;:7,_! PERFRECORD 040595 I 1 D.S. 9-12 '7~ -'7 PERFRECORD 040795 I 1 D.S. 9-23 & ~ -_~ GAS LIFT SURVEY 040695 I 1 D.S. 15-17 ,~/I/''c~ c~ CNT-G ~ 040595! I 1 D.S. 18-24 ~c~. ~......~TBG. CUTTER RECORD 040695 I 1 ..... SIGNED: .... DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. well: 04-13 Spud Date: 03/26/78 Original RKBE: 64' Top of Formation: 10095' Annular Fluid: Diesel/9.0 NaC1 Reference Log: BHCS ARL._ Alaska, Inc. - Prudhoe Ba~ API #: 50-029-20305-00 Completion: 06/11/85 Hanger Type: Gray Retro Max Hole Angle: 48° ~ MD: 7400' Date: 04/12/78 Tie In: Ann. Comm: Waivered Well: TxlA & IAxOA Communication; Water Injection Only ALL DEPTHS ARE RKB J-1 kC.1 J-2,3 J-4 J-5,6 J-7,8,9 C-3,4 J-lO P-1 CT Liner Completion 01/18/95 J-11 J-12 Type:INJECTOR Status:Workover Hanger:28' Angle ~ TS:44° Angle @ TD:44° Date: 00/00/00 DRILLING MD TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. Jewelry (J) DeDth Description 1 2201' 2 9930' 3 9950' 4 10024 ' 5 10027 ' 6 10040' 7 10053 ' 8 10054' 10034' 10 10460' 11 11743' 5-1/2" Camco BAL-O SSSV Nipple ID=4.562" 5-1/2" BOP PBR ~ly 9-5/8" x 5-1/2" B0T 3-H Peunmue~t Packer 5-1/2" G Lar~ Sub/PBR ID=3" 5-1/2" x 3-1/2" G Lar~ Sub/PBR ID=2.992" 5-1/2" Camco KB Ab-Go Nit~ple (Behind CT Liner) ID=4.313" 5-1/2" B0T Shearout Sub (Beh/nd CT Liner) 5-1/2" Tubirg Tail (Behind CT Liner) ELM Tubing Tail (I/Dg~ 10/03/90)(Beh~ CT Liner) 3-1/2" Davis Lynch Float shoe FISH: ~ Bowspring Centz~lizer (Lost 10/01/90) FISH: Baker Packer Element (Lost 07/10/90) ID: 5-1/2" x 3-1/2" G Landing Sub/PBR ID=2.992" Casing andTubing (C) Size Weight Grade 1 13-3/8" 2 9-5/8" 3 5-1/2" 4 3-1/2" 5-1/2" TOD Bottom Description 72# N-80 0' 2692' Casirg 47# N-80 0' 10826' Casirg 17# L-80 10023' 10027' Liner-Scab 9.2# L-80 10027' 10460' Liner-Scab 17# L-80 0' 10054' Tubirg-NPC Perforation Data (ELM DEPTHS) (P) Interval Zone FT SPF Date Comments 1 10222-10262 4 40 0 11/30/94 SQZ 10277-10345 3 68 0 12/30/94 SQZ 10360-10375 2 15 0 12/30/94 SQZ 10390-10440 2 50 0 12/30/94 SQZ 10512-10522 2 10 1/4 01/11/87 APERF 10570-10610 2 40 1/4 07/04/84 APERF 10630-10666 2/lB 36 4 07/04/85 APEEF 10678-10685 1B/lA 7 4 07/04/85 RPESF 10694-10703 IA 9 4 07/04/85 RPSRF 10714-10724 IA 10 4 07/04/85 RPSZF Datum 8700' SS=10507' MD PBTD=10812' 8800' SS=10649' MD TD=10845' Revision Date: 03/15/95 by ENH/PTB Reascn: CT Liner Correcti~ Previcus Reascn: 02/12/95 well 04-13 ~2 STATE OF ALASKA .... ALASi'-"~ OIL AND GAS CONSERVATION )MMISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, AnchOrage, AK 99510-0360 4. Location of well at surface 33' FSL, 441' FWL, Sec. 26, T11 N, R15E, UM At top of productive interval 1391' FNL, 1871' FWL, Sec. 34, T11N, R15E, UM At effective depth 1329' FNL, 1402' FWL, Sec. 34, T11N, R15E, UM At total depth 1322' FNL, 1352' FWL, Sec. 34, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 64' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-13i 9. Permit number/approval number 78-31 10. APl number 50 - 029-20305 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 111' Sudace 2692' Production 10826' Liner 435' 10845 feet Plugs(measured) 8993 feet 10782 feet 8947 feet Junk(measured) Size Cemented 20" 320 sx AS II 13-3/8" 6400 sx AS II 9-5/8" 900 sx Class G 3-1/2" 22 bbls LARC Measured depth 111' 2692' 10826' 10024-10459' True vedicaldepth 111' 2692' 8979' 8409-8717' Perforation depth: measured 10512'-10522', 10570'-10610'; 10630'-10666'; 10678'-10685'; 10694'-10703'; 10714'-10724' true vertical 8755'-8762'; 8796'-8824'; 8838'-8864'; 8873'-8878'; 8884-8891'; 8899'-8906' Tubing (size, grade, and measured depth) 5-1/2", 7#, L-80, 10054' MD Packers and SSSV (type and measured depth) BeT 3-H Packer @ 9950' MD Camco BAL-,,,O SSSVl~/'" ["~ ~,1~ ¢ 22Q.1'~D,, 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure MAP, ?_9 995 0il & Gas Cons. Commission Anrt. hnrR" 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 24178 Tubing Pressure 2042 Subsequent to operation - - 18861 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~"~"~' ~ Title Engineering Supervisor FOrm 10-404-'Rev 06/15/88 A ID ^^. V"7 I%AID'~ 2044 Service I niector Date ~/~/~ ~ SUBMIT IN DUPLICATE-~- 4-13i DESCRIPTION OF WORK COMPLETED CEMENT SQUEEZE & SCAB LINER INSTALLATION FOR INJECTION PROFILE MODIFICATION 12/15/94' RIH & tagged PBTD at 10704' MD. 12/22/94' RIH w/CT to bottom & pumped gelled sand slurry containing a total of 900 lbs of 20/40 mesh sand to place an isolation sand plug across the lower perforation open intervals located at: 10512 - 10522' MD (Z2) 10570 - 10610' MD (Z2) 10630 - 10666' MD (Z2/1B) 10678 - 10685' MD (Z1B/1A) 10694 - 10703' MD (Z1A) 10714 - 10724' MD (ZIA) POOH w/CT leaving top of sand plug at 10495' MD. Ref Log: BHCS 4/12/78. Rigged down. RECEIVED 12/29/94' MAR 29 1995 RIH & tagged top of sand at 10474' MD. Alaska Oil & Gas Cons. Commission I 2 / 3 0 / 9 4 · Anch0ra ,- MIRU CTU & PT equipment. RIH w/CT & reciprocated an acid wash across the open perforations located above the sand plug at: 10222 - 10262' 10277 - 10345' 10360 - 10375' 10390 - 10440' MD (Z4) MD (Z3) MD (Z2) MD (Z2) Ref Log: BHCS 4/12/78. Pumped 40 bbls Xylene @ 1.6 bpm, followed by 80 bbls 12% HCI w/10% Xylene @ 1.6 - 2.25 bpm, followed by 460 bbls Seawater Flush. Switched to pumping 15 bbls of Latex Acid Resistive cement, followed by 48 bbls Thixotropic cement w/20 ppb aggregate, followed by 17 bbls Latex Acid Resistive cement, to squeeze the perforations (listed above). Placed 56 bbls cement behind pipe & obtained 1200 psi squeeze held for 1 hour. Jetted contaminated cement to 10470' MD. POOH w/CT. Rigged down. 1/1 6/95 - 1/1 8/95: MU & RIH w/CT conveyed Scab Liner assembly, consisting of Float Collar w/check valves, followed by 14 joints of 3.5" OD, L-80, FL4S Liner & one 3.5" Pup joint (435' total liner length). Hung the liner assembly by 'G' landing sub putting the liner from 10024' MD at top, to 10459' MD at bottom. Disconnected from liner top & POOH w/CT. RIH w/CT mounted stinger & stung into liner top. Circulated 150 bbls of Hot Seawater, then pumped 33 bbls of Latex Acid Resistive Cement down the CT & through the check valves, to cement the Liner in position while isolating the squeezed perforation intervals above the sand plug (listed above). Attained 1000 psi max squeeze pressure & displaced 22 bbls of cement into the 3-1/2" x 9-5/8" annulus. Unstung from the liner top & POOH w/CT. RIH w/jetting nozzle & jetted biozan contaminated cement from liner to 10435' MD. POOH w/CT. RD. 2/3/95 - 2/4/95' MIRU CTU & PT equipment. Made RIH w/CT mounted mill & milled through liner cement to cement & sand interface at 10448' MD. POOH w/mill. RIH w/jetting nozzle & circulated biozan gel to jet out the sand plug to 10710' MD, to uncover the lower open perforations (listed above). POOH w/CT. RD. Returned the well to produced water injection & obtained a valid injection rate. ARCO Alaska, Inc. Date: Subject: From/Location- Telephone: To/Location: P.O. Box 100360, , ~rage, AK Jan 28, 1994 Transmittal #: ARCO Cased Hole Finals · John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94016 9961o~ ~, Number 1-3 1-11 1-22 c/0-11i 2-29A ! 1-18-94 ;f¢-~q ~ 3-2 { .1-19-94 3-2 ! 1-15-94 -~.~.-~31 3-16 l 1-10-94 ,,~'%-t2.~-~/ 3-22 i 1-19-94 ' ~5~:~ ~ I 16-94 i 1-10-94 ~[-~0~ 3-35 i 1-21-94 3-36 ~ 1-20-94 ~-~ 4-13 [ iLog Date i Tool Type i Run, (M-D-Y) ! P0r__~ ~ +! Scale 1-14-94 ! Tubing Puncher' ! 1, 5" 1-14-94 ! Perf Record ! 1, 5" 1-13-94 ~. Bridge Plug ~ ¢~1, 5" Contractor Sch Sch Sch i CNL i' 1, 5" i Sch i~ Bridge Plug ~ 1, 5" t Sch i Leak Determin IP~I¢.~, 5"i~-¢~ Sch i Perf Record ~ - ' 1, 5'~ "1' Sch !0\ Bridge PlugIL~,.~ 1, 5" ! Sch ! Leak Determin (¢~J~(~'; ..-(~, Sch ! Leak Detect 15~,'~ I t PerfRecord' "i ' 1,5'~ i I ' '~ch i Prod CompI Record ~ 1, 5" IS q-tu~O!,.,/ 15-7 ! 1-22-94 t Tubing Cutter ~.~. 1, 5" i~15-7 ! 1-17-94 i Tubing Puncher~(~&,l, 5" ~'~'~! 17-13 f 1-8-94 i Patch Setting ~ 1, 5" ~l-~Oj 18-1 i 1-20-94 i Dual BurstTDTP f 1, 5" Number of Records:24 Sch .Sch Sch Sch Sch Sch Sch Sch Sch Sch /~John E. DeGrey PBOE Document Control Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon ~': state of AlaSka-,. Mobil ,;~. :~ .~ . RECEIVED FEB 0 1 1994 Alaska 0il & Gas Cons. Commission Anchorage Please acknowledge receipt by signing and returning a copy of transmittal. ARCO Alaska, Inc. Is & Subslcllary of AtlantlcRIchfleldCompany ' A R C 0 A I... A,.~; K A, P.O. BOX t ANCHORAGE, ALA3'K A DATE: 6-27-9t REFERENCE: ARCO CAS'ED HOLE FINAL~' 1-'25 5-'St -9t LEAK DETECTION * 2-S 5-St-9t PROD PROF'ILE 3-t;~ 5""St'"9~ INJ PROFIL. E 4-t :~ 5-29-9t INJ I::'I:~OFIL. E ~'"33 6-8-9~ CBT PFC 9-8 '3-3~-9t F'ERF BREAK DOWN 9--2S 6-~ -'9~ PROD PROFILE ~-S 5--23-9~ F'O~'F BRIEAKDOWN * ~ 6-9A' 5-29-'9~ GR-CCL RLJN t , .5" RUN t, .5" RUN t, 5 · R[J N I , '5" R LJN t , 5" R~N t, RUN t, 5" RUN t, .., RUN t , 5" RUN t , 5" PLEASE ,~IGN AND RETURN TFIE ATTACHED COPY AS RIECFIF'T OF DATA. RECEIVED BY HAVE A NICE DAY! $ONYA WALLACE AT(]-t529 APF'ROVED 'I'RAN$~ 9t CAMCO CAMCO CAMCO (:ANCO ,S'CI--I A T L.. A ;S' CAMCO C A M C [3 CAMCO C A M C 0 D I S'TR I BUI'I ON CENTRAl_ FILES CHEVRON D&M EXTEN£ION E:XPL. ORATION EXXON MARAI'HON MOBIL ~ PHILLIP,S' F'B WEI..L. F'Ii..E,S' R & D ~ BF'X · .. ,~'FATE OF ALA~'KA I'EXACO * 'THE CORRECTED AF'I~. FOR 2-3 l~' 50-.~29-20077 ** THE COF(RECTED WEi..L NtJMBEF,: FOR THIS' LOG I5" t6-?A RECEIVED JUL 11991 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA '_AND GAS CONSERVATION C¢ '~IISSION REPORT UF SUNDRY WELL OPP_.RATIONS 1. OPerations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 33' FSL, 441' FWL, Sec. 26, T11 N, R15E, UM At top of productive interval 1391' FNL, 1871' FWL, Sec. 34, T11N, R15E, UM At effective depth 1329' FNL, 1402' FWL, Sec. 34, T11N, R15E, UM At total depth 1322' FNL, 1352' FWL, Sec. 34, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 64' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-13 9. Permit number/approval number 78-31 10. APl number 50 - 029-20305 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10845 feet Plugs(measured) 8993 feet feet Effective depth: measured 10782 feet true vertical 8947 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 111' 20" 320 sx AS 11 111' 111' Sudace 2692' 13-3/8" 6400 sx AS 11 2692' 2692' Production 10826' 9-5/8" 900 sx Class G 10826' 8979' Liner Perforation depth: measured 10222'-10262', 10277'-10345', 10360'-10375', 10390'-10440', 10512'-10522', 10570'-10610', 10630'-10666', 10678'-10685', 10694'-10703', 10714'-10724' true vertical 8551'-8580', 8590'-8638', 8649'-8659', 8670'-8705', 8755'-8762', 8796'-8824', 8838'-8864', 8873'-8878', 8884'-8891', 8899'-8906" Tubing (size, grade, and measured depth) 5-1/2" 7#, L-80, 10054' MD Tubing Pressure 1949 Packers and SSSV (type and measured depth) BeT 3-H Packer @ 9950' MDca~bBAL-O SSSV 2 2201' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) N/A i~'i ~! i~' ~:: ~! .'i!.!j ~ Treatment description including volumes used and final pressure ' h~r ~,~:" 14. Representative Daily Average4~,-ti~,~i~ or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 16016 850 Subsequent to operation 16285 425 1915 Water Injector 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Date ~/~c'/~'/~ SUBMIT IN DUPLICATE 16. Status of well classification as: Oil__ Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.,,~j~_ (~ ,,_~[~~ Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 (~1 I1~1 Ink REPORT OF Wi~,IJ OPER .IONS DS 4-13 Perforating Operations: ARCO Alaska, Inc. perforated DS 4-13 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 9/21/90. The interval perforated was the following: 10390'-10440' MD (Reference Log: BHCS dated 4/12/78). Injection water was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 9/21/90. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. Perforated 10390'-10440' at 1/2 SPF (ref: BHCS of 4/12/78). SI well, POOH, and confirmed all shots fired. Rigged down and secured well. WDM: 6/14/91 STATE OF ALASKA ALASKA .... 'AND GAS CONSERVATION C(' /IlSSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate ~ Pull tubing Alter casing Repair well , Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 33' FSL, 441' FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1391' FNL, 1871' FWL, Sec. 34, T11N, R15E, UM At effective depth 1329' FNL, 1402' FWL, Sec. 34, T11N, R15E, UM At total depth 1322' FNL, 1352' FWL, Sec. 34, T11N, R15E, UM 5. Type of Well Development '-X'-, Exploratory Stratigraphic Service ~'~'~v~ 6. Datum of elevation(DF or KB) 64 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-13~ 9. Permit number/approval number 78-31 10. APl number 50 - 029-20305 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10845 feet 8993 feet Plugs(measured) 10712' MD; 8897' TVD Effective depth: measured 10712 feet true vertical 8897 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 111' 20" 320 sx AS II 111' 111' Surface 2628' 13-3/8" 6400 sx AS II 2692' 2692' Production 10762' 9-5/8" 900 sx CI 'G' 10826' 8979' Perforation depth: measured 10222-10262'; 10277-10345'; 10360-10375'; 10390-10440'; 10512-10522'; 10570-10610'; 10630-10666'; 10678-10685'; 10694-10703'; 10714-10724' · true vertical 8564-8592'; 8603-8651 '; 8661-8671'; 8682-8717'; 8767-8774'; 8786-8824°; 8839-8865'; 8873-8878'; 8885-8891'; 8899-8906' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 10054' MD Packers and SSSV (type and measured depth)BeT 3-H packer @ 9950' MD; Camco Ba,-0 SSS~ii~.,,~ ~ F ~) 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure MAT ~ 9 1~99~ Alaska 0il & Gas Cons. C0mmissiort Anch0ra.~e 14. Prior to well operation Subsequent to operation Representative Daily Average production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 18269 20580 Tubing Pressure 1947 2058 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE DS 4-13i DESCRIPTION OF WORK COMPLETED SELECTIVE STIMULATION FOR PROFILE MODIFICATION 4/6/91: MIRU CT & PT equipment to 4000 psi. RIH w/CT & tagged bottom at 10728' MD. Pumped 82 bbls of sand slurry, containing 13,760 lbs of sand, to isolate open perforations at: 10512 - 1 10570 - 10630 - 10678 - 10694 - 10714 - 0522' MD (Z2) Ref. Log: BHCS 10610' MD (Z2) 10666' MD (Z2/1B) 10685' MD (ZIA) 10703' MD (Z1A) 10724' MD (ZlA) 4/12/78. Tagged final top of sand at 10440' MD. POOH. Rigged down. 4/1 4/91 .' A Selective Stimulation for an Injection Profile Modification was performed as follows: MIRU CT & PT equipment to 4300 psi. RIH w/CT & selectively treated perforations at: 10222 - 10262' MD (Z3) 10277 - 10345' MD (Z3) 10360 - 10375' MD (Z3) 10390 - 10440' MD (Z3) Ref. Log: BHCS 4/12/78. Pumped: a) 5 bbls 12% HCI w/30% Xylene, followed by b) 4 bbls Diesel, followed by c) Shutdown for acid soak. POOH w/CT. Loaded backside of wellbore w/60/40 Meth/Water. RIH w/CT mounted inflatable packer, & set packer in tubing at 10028' MD (middle of element). PT packer OK, then resumed pumping: d) 71 bbls 12% HCI w/30% Xylene, followed by e) 97 bbls 12-3% HCL-HF, followed by f) 195 bbls 2% NH4CL, followed by g) 5 bbls Diesel. POOH w/Packer. Rigged down. Returned well to produced water injection. 5/1 5/91 .' Performed a fill cleanout of sand plug down to 11741' MD. 5/1 6/91: RIH & tagged bottom at 10712' MD. P, E C E I V F. MAY 2 9 ]999 Returned well to fulltime injection & obtained a valid injection rate. AJaska OJJ & Gas Cons, Commissio~ Anchorage ..... STATE OF ALASKA --- ALASKA -AND GAS CONSERVATION C£ ,vIISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X__ Plugging Perforate ~ Pull tubing Alter casing Repair well ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 33' FSL, 441' FWL, Sec. 26, T11 N, R15E, UM At top of productive interval 1391' FNL, 1871' FWL, Sec. 34, T11N, R15E, UM At effective depth 1329' FNL, 1402' FWL, Sec. 34, T11N, R15E, UM At total depth 1322' FNL, 1352' FWL, Sec. 34, T11N, R15E, UM 5. Type of Well Development ~ Exploratory Stratigraphic Service X 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-13i 9. Permit number/approval number 78-31/90-094 10. APl number 50 - 029-20305 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10845 feet Plugs(measured) 8993 feet Effective depth: measured 10743 feet true vertical 8919 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 111' 20" 320 sx AS II 111' Sudace 2628' 13-3/8" 6400 sx AS II 2692' Production 10762' 9-5/8" 900 sx CI 'G' 10826' feet True vertical depth 111' 2692' 8979' Tubing Pressure 1829 2120 Injector SUBMIT IN DUPLICATE ~ Perforation depth: measured 10222-10262'; 10277-10345'; 10360-10375'; 10390-10440'; 10512-10522'; 10570-10610'; 10630-10666'; 10678-10685'; 10694-10703'; 10714-10724' true vertical 8564-8592'; 8603-8651 '; 8661-8671'; 8682-8717'; 8767-8774'; 8786-8824'; 8839-8865'; 8873-8878'; 8885-8891'; 8899-8906' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 10054' MD Packers and SSSV (type and measured depth) BeT 3-H packer @ 9950' MD; Camco Bal-0~ I~ 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure APR 9 t991 Alaska 0il & Gas Cons. G0mm'tsslon 'Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average prgduction or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure .... 19715 -- 24161 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 RQ,4.I~I::t r,. 13 W,~rn,',r AT("t.izlTQ KW _IW[:) DS 4-13i DESCRIPTION OF WORK COMPLETED SELECTIVE STIMULATION TREATMENT 7/1/90: A Selective Stimulation using an Inflatable Packer was performed as follows: MIRU CT & PT equipment to 4500 psi. RIH w/CT mounted Inflatable Packer. Inflated & set packer at 10672' MD, isolating perforations at: 10222 - 10262' MD (Z3) Ref. Log: BHCS 4/12/78. 10277- 10345' MD (Z3) 10360 - 10375' MD (Z3) 10512 - 10522' MD (Z2) 10570 - 10610' MD (Z2) 10630 - 10666' MD (Z2/1B) Perforations treated below the Packer were: 10678 - 10685' MD (Z1A) 10694 - 10703' MD (ZlA) 10714 - 10724' MD (Z1A) Pumped: Ref. Log: BHCS 4/12/78. a) 30 bbls 12% HCI w/Xylene, followed by b) 20 bbls 2% Citrate Acid, followed by c) 20 bbls Diverter, followed by d) 20 bbls 2% NH4Cl, followed by e) 25 bbls 5% HOOH, followed by f) 35 bbls 2% NH4Cl, followed by g) Shutdown. Waited one hour then resumed pumping: h) 30 bbls Diverter, followed by i) 30 bbls 12% HCI, followed by j) 5 bbls 2% NH4Cl, followed by k) 20 bbls 2% Citrate Acid, followed by I) 15 bbls 2% NH4Cl, followed by m) 15 bbls 5% HOOH, followed by n) 35 bbls 2% NH4Cl, followed by o) 29 bbls 12% HCl, followed by p) 5 bbls 6% HCl - 1.5% HF, followed by q) 5 bbls 3% HCl, followed by r) 38 bbls 2% NH4Cl,J~followed by s) 30 bbls Meth/Water, followed by t) 35 bbls Fresh Water. POOH w/Packer. Rigged down. RECEIVED APR 2 9 t99t Alaska 0il & 6as Cons. Commission Anchorage 9/21/90: Added perforations: 10390 - 10440' MD (Z3) Ref. Log: BHCS 4/12/78. Returned well to injection & obtained a valid injection rate. ARC(] ALASKA, tNC. .----- P.O. BOX ,i00S60 ANCHORAGE, AI_A,?KA 975i~,-) DATE' REFERENCE'' ARCO CASED HOLE FINALZ 4-9 t0-S-90 INJECTION. F'ROFILE RUN t, 5:" 4-t 3 i ¢,-3-9i'''' INJECTION PROFILE F;:UN t "~'" 6-4 t0-6-90 PRODLICT]:ON PROFILE RtJN I , 5" 6-6 t 6'-4-9':) PIT;~ RUN I , 5" 6-9 t0-'5-90 PRODUC]"ION I::'ROFILE RUN i , 5" 6-'i0 i6,-4-9;3 PRODUCTION PROF:ILE RUN t , ':~" t t-2 i 0-'i 4-90 COLLAR/PERF R'UN t , .,.="" 'i2'-8B i 0-:~-9':) LEAl<: DETECTION I'<UN i, 'i:' i 4-i c. t 0-'i 9-96, CL/..L.F~F;~/PE. RI::' I:,.:UN 'i , 5. ~ ,i a.-":'.¢.*,. ~ ._. t ¢:"-i,, ~-~;'"";, , ,.. F:OLLAF;:/I::'FRF_ _ I:;.'.iJN i., ~":_, ' F'L. EAI..'E ZIGN A~I)_R!i;TURN THI-Z ATTACHED COPY AS' RECEI:F'T Cji:= DATA,. APPF~'.O VF£D . TRAN$:~ 9(":¢i.i 4 SALLY HOFFECKE:R~ A T 0 -- i ~ ":' o (;AMC() CAMCO C ?.~ H C 0 C A f,,i C 0 CA~.~CO (]AMC(] A 'i" L. a ~,' A'f'L_AX A i I_A2¢ D I ~":. T R i B U T ]; 0 N ~ CE:'NTRAL Fit_EY ,,.-"- F:_ I..1E V R 0 N D & H · ,,.'" EEXT EN.'~ T F.'N ., .... EXI::'t_ORAT i ON · I,': EXXON hi A R A T H 0 N · ,,-'"' MOB ;[i~ · ~ P I"t I I_ 1.. :[ F:' 5' F'B WE[I_L F']:L.r..!.~',., I:;: & D ~ BF:'X '"' ~'F'ATE [.)F AL.A:::KA 'It' ,, 'T' E:_' X A C 0 R,._,'-"' r_- rtE R,_ ~-...~::,,. C;r-'',_ ARC[3 CASED HOLE ,i: ~ klfli'- ,, ,_,..'-',:' F' i_ E A S E ::.-;.' i (..;- N A N D i;..' Ii!; T'ij R N T H E A'f"T' A C i--ii:: O C U i::' 'i"' A S 1';: E C ii:: .[ F:' T' u I-:' P ;:':', 'i" A .. HAVF' A Ni,:S:E DAY! :"-:AL.L.Y HOF'F"~::'"'"K E F.'.,...,.., i) ISTRIBUTION · ~' C:ENTRAL FILES 'Ir ':".,,- L. ,"~ I::. \;' R 0 N. D & M · "',~EXTE'hi;S: I Oi'-.} EXF'LOF.'.AT I F~kI...,, · ,-'"" EXXON .. :~: H 0 B '[ L F:' B W E t... I... i::' l; i... E,ii: t:;.:,:.=~ D :~ .B F'X · ,-'"' S'TA'i'E OF- AL. ASI<;A T E X A C: 0 T Fiiii; C': 0 R i:;.'. !!:' C '".;" E D A F' 1.11: F 0 R F' W D W i - 2 A I S 5 6,- (:':;, 2:: 9.-'2"'2 9'2 4 ..... 3, t ,. RECEIVED OCT 1 9 1990 Alaska Oil & ~ Cons. Commission An~horal~e A R C 0 A L. A 2 K A, ]; i"...t C., P. (]. D 0 X i ,:} (:;, S 6,3 ANCHC)F:.AGE, AI._A:?KA 995'.i ,::) _ ?:, A T E ' '? - S ,3, .-- 9 F:..' IE F E R E N C E ' A t::,' rj: O C A 3£ E D i.-i 0 i.. [:- F' Z N A !.. S' F' R O D t..j C "[' ,1.: 0 i"-.! F:'R O F'I L.. i'_.:: F'RODU[":T ! Obi J::' F;..' O I.: .[ i_ ii.:. A i< D F. T E C: "I" i '] i".! i N J i:: C T ! CJ N F' R 0 F' .!' LiE I N ,.J iii] C 1" i 0 i',! i::' R 0 i::' ]' i... E P F::..'.] T:' U C 'i" i C1 i"'.! F:' R O F' J' i.. E i N J E C ","' i 0 N F' F::. 0 F' i t... E F:' R O D U C '!- Z rg N i::' R i;.'j i::' ! i_ ii{. L_ E A i< 'r., E']' ~::' r' "r I ;'i i".i .'.' . L.. :.: I ;.. : GR COLLAR ,'.".~ i::..' COL_L. AF(' LEAK DETECTION/F:'i F'!_ E A $ F.i: S .i C,- i'-i A N D F;.'. E"f' U R N T H i::: A T T A C i.-ttii. D C 0 ~ Y A Z 1:;.: E C E I P T 0 F' D A T A., F;.'. ii:' C: E t VE:C:, B",,' ............. ~_~.~..~.__._ ........ HAVE: A NICti:.: ;~:AI..i...",;' HOFF'EC':K ER. A 'i' (] .-- i 5. 2 9 D i £'T R I B U 'i" ! Ci N :,*.. CtFN T F;-':A L FILES -,,.""C: I--t E V R O N · II: E..': X T E N $ i 0 N E X F:' L 0 FL'. A 'i" I C) i'.! '"' F: X Y f') N "'Il' ~ o o - H A RA'I-HOi'.J :~: MOBIl_ R£¢EIVED 41aska 0il & Sas Cons. Commission ARCO AL.A~;'I<A; I F' 0 A N C FI 0 R. A DATE ' 6/t/90 REFERENCE:' ARCO CASED HOLE F'INAL~ OWDW NW 5-t8-90 OWDW-~E 5~-i9-90 OWDW-Z'W. 5-i 9-90 . PRODUCTION F'ROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE INJECTION PRCIFILE PRODUCTION PROFILE INJECTION PROFILE PRODUCTION F'ROFILE PRO'OUCTION PROFILE PRODUCTION PROFILE F'UHP-IN TEiMF' SURYEY F'UMF'-IN TEMF' SURVEY F'UHP-IN TEHF:' 2'URVEY RLJN. i, 5' RUN t, 5' RUN i , _.":~' RUN i, 5" RUN i , 5" RUN i, 5" R U N i, "3" RUN I, 5' F,'LINi , 5.' I;,'UNt, 5' R U N.i , 5" I;,'UNt , 5' RUN i , 5: ' CAMCO CAi'iCO C A f.i C 0 C A i'd C 0 L: ;~:~ i'"l L; LJ C A M'C 0 f'; A M C C A id t'.'.' 0 C A r'i C 0 C A ~"i r/.: t] C A M C 0 C A M C O C A M C 0 PI_EASE ,~IQN AND RETURN THE ATTACHED ..OF'¢ A~ RECEIF'T OF DATA HAVE A NICE DAY! SALLY HC1F:FECK FR ATO-t 5~9~ JUN - 4 99B Alas Oil & Gas Cons, CommiSsion ;Anchorage APPROVE ........ '/RANS:~ 90'204 DISTRIBUTION CENTRAL FILES CHEVRON D & M EX'TENSION EXF'LORATION EXXON MARATHON MOBIL F'HILLIF'S F'B WEL_L. F'IL_E:2 R & D BF'X .~I'A-I'IE OF ALA~'KA TEXACO ARCO Alaska, Inc, Prudhoe Bay .-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager February 9, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 4-13, Permit No. 78-31 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/JCB/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 4-13)W1-3 ARCO Alaska, Inc. is a Subsidiary or' AtianticRichfieldCompany AR38 -6132-C STATE OF ALASKA ALASK/~'tL AND GAS CONSERVATION C !MISSION APPLIC RON FOR SUNDRY AI-,PROVALS 1. Type of Request: Abandon Suspend Operation shutdown __ Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Variance Perforate Other 5. Type of Well Development X Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 33' FSL, 441' FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1391' FNL, 1871' FWL, Sec. 34, T11N, R15E, UM At effective depth 1329' FNL, 1402' FWL, Sec. 34, T11N, R15E, UM At total depth 1322' FNL, 1352' FWL, Sec. 34, T11N, R15E, UM 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-13 9. Permit number 78-31 10. APl number 50 - 029-20305 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 111' Surface 2628' Production 10762' 10845 feet Plugs(measured) 8993 feet 10782 feet 8947 feet Junk(measured) Size Cemented 20" 320 SX AS II 13-3/8" 6400 sx AS II 9-5/8" 900 sx CI 'G' Measured depth 111' 2692' 10826' True vertical depth 111' 2692' 8979' Perforation depth: measured 10222-10262'; 10277-10345'; 10360-10375'; 10512-10522'; 10570-10610'; 10630-10666'; 10678-10685'; 10694-10703'; 10714-10724' true vertical 8564-8592'; 8603-8651'; 8661-8671'; 8767-8774'; 8786-8824'; 8839-8865'; 8873-8878'; 8885-8891 '; 8899-8906' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 10054' MD Packers and SSSV (type and measured depth) BOT 3-H packer @ 9950' MD; Camco Bal-0 SSSV @ 2201' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation February 1990 16. If proposal was verbally approved Name of approver Date approved Service Injector 17. I hereby/l=ertify that th,.? foregoin~ is true and correct to the best of my knowledge. Signed ~'~~.,~.,~-j.~-~ Title Operations Engineering Manager FOR COMMIfiSII3N USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance //i.:_~.' (./ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commissioner Commissioner Returned Form 10-403 Rev 06/15/88 15. Status of well classification as: Oil Gas Suspended Date I Appr°val N°' ,~~~' Date SUBMIT IN TRIPLICATE Drill Site 4-13i Lower Romeo Interval ARCO Alaska, Inc proposes to perform the following stimulation treatment: 1. Make a gauge ring run to TD with a 4-3/8" gauge ring. 2. MIRU CTU with 4.19" x 9-5/8" inflatable packer and tubing end Iocator. 3. RIH with CT. Locate the tubing end and adjust the depth accordingly. The tubing tail depth is 10025'MD according to the CCL of 7/3/85. 4. Fluid pack the CT x injection tubing annulus. 5. Continue downhole and set the inflatable packer at 10672'MD. 6. Load the following fluids: a. 1250 gal 12% HCI with 20% dispersed xylene and additives b. 2500 gal of 12% HCI with additives c. 2500 gal of 6% HC1:1.5% HF with additives d. 4000 gal of 3% HCI with additives e. 5000 gal 2% NaCI water f. 3000 gal 5% HOOH in 2% NaCI (100 deg F) g. 2700 gal 2% NaCI water with 50 Ibs/Mgal HEC and 1000 lbs BAF h. 100 bbl warm methanol (70 deg F). 50 bbls are to dissolve BAF and freeze protech CT. i. 200 to 300 bbl warm (90 deg F) fresh water in an upright tank with a fire hose. j. 300 bbl seawater for fluid packing and maintaining pressure on the CT x inj tbg annulus. 7. MIRU transports, pump trucks and associated equipment. 8. Pump the following fluids down the coiled tubing to stimulate the Lower Romeo interval. (10678'MD to 10724'MD)' a. 3 0 bbl of 12% HCI with 20% dispersed xylene b. 24 bbl of diverter - gelled 2% NaCI with BAF c. 24 bbl of 2% NaCI water d. 3 6 bbl of 5% HOOH in 2% NaCI e. I Coiled Tubing Volume (24 or 32 bbl) of 2% NaCI water f. Shut down for 2 to 3 hours g. 1 0 bbl of diverter - gelled 2% NaCI with BAF _~ ,. h. 3 0 bbl of of 12% HCI with additives i. 3 0 bbl of 6% HC1:1.5% HF with additives j. 4 8 bbl of 3% HCI with additives k. 2 0 bbl of diverter - gelled 2% NaCI with BAF I. 2 4 bbl of 2% NaCI water · m. 36 bbl of 5% HOOH in 2% NaCI - n. I Coiled Tubing Volume (24 or 32 bbl) of 2% NaCI water o. Shut down for 2 to 3 hours p. 1 0 bbl of diverter - gelled 2% NaCI with BAF q. 3 0 bbl of of 12% HCI with additives r. 30 bbl of 6% HC1:1.5% HF with additives s. 4 8 bbl of 3% HCI with additives t, 4 8 bbl of warm Methanol (65 deg F) to dissolve BAF and freeze protect the CT. 9. Release CT packer and POOH. Slowly pump seawater down the CT x inj tubing annulus to displace the fluids. 1 0. RD and release CTU, pump trucks and transports. Reference Log BHCS 4/12/78 Drill Site 4-13i Tango Interval Selective Stimulation Procedure ARCO Alaska, Inc. proposes to perform the following stimulation treatment: 1. Make a gauge ring run to TD with a 4-3/8" gauge ring. 2. MIRU CTU with 4.19" x 9-5/8" inflatable bridge plug and tubing end Iocator. 3. RIH with CT. Locate the tubing end and adjust the depth accordingly. The tubing tail depth is 10025' MD according to the CCL of 7/3/85. Flag the tubing. 4. Place and set the bridge plug at 10550'MD. POOH. 5. RIH with CT and 4.19" x 9-5/8" inflatable packer. Set the packer at 10490'MD. 6. Load the following fluids: a. 1000 gal of 12% HCI with 20% xylene and additives b. 1000 gal of 12% HCI with additives c. 1000 gal of 6% HC1:1.5% HF with additives d. 1250 gal of 3% HCI with additives e. 5000 gal 2% NaCI water f. 1000 gal 5% HOOH in 2% NaCI (100 deg F) g. 1500 gal 2% NaCI water with 50 Ibs/Mgal HEC and 250 lbs BAF h. 100 bbl warm methanol (70 deg F) i. 200 to 300 bbl warm (90 deg F) fresh water in an upright tank with a fire hose. j. 300 bbl dead crude for fluid packing and maintaining pressure on the CT x inj tbg annulus if the inflatable packer is not used. If the packer is used, then load 300 bbl of seawater for fluidpacking the CT x inj tbg annulus. 7. MIRU transports, pump trucks and associated equipment. 8. Pump the following fluids down the coiled tubing to stimulate the Tango interval. (10512' MD to 10522' MD): a. 2 4 bbl of 12% HCI with 20% dispersed xylene b. 2 4 bbl of 2% NaCI water c. I 2 bbl of 5% HOOH in 4% NaCI d. I Coiled Tubing Volume (24 or 32 bbl) of 2% NaCI water e. Shut down for 2 to 3 hours f. 1 2 bbl of of 12% HCI with additives g. I 2 bbl of 6% HC1:1.5% HF with additives h. 1 5 bbl of 3% HCI with additives i. 1 2 bbl of diverter - gelled 2% NaCI with BAF j. 2 4 bbl of 2% NaCI water k. 1 2 bbl of 5% HOOH in 4% NaCI I. I Coiled Tubing Volume (24 or 32 bbl) of 2% NaCI water m. Shut down for 2 to 3 hours n. I 0 bbl of diverter - gelled 2% NaCI with BAF o. I 2 bbl of of 12% HCI with additives p. 1 2 bbl of 6% HC1:1.5% HF with additives q. I 5 bbl of 3% HCI with additives r. 4 8 bbl of warm Methanol (65 deg F) to dissolve BAF and freeze protect the CT. 9. Release CT packer and POOH. Slowly pump seawater down the CT x inj tubing annulus to displace the fluids. 1 0. RD and release CTU, pump trucks and transport. Reference Log BHCS 4/12/78 6 5 4 2 COILED 'I'UBINt~ UNIT BOP EOU ! PHENT 1. 5000 PSI ?" WELLHEAD CONNECTOR FLAI~O£ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/$" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX H]REL]NE BOP EOUIPMENT _ 1. 5000 PSI ?" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WlR£LINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ~F?F:R Al AX'K~. I'NF:. P. I'1. P, IlY. ~ (.~.~7./:.r.) ANCI"iRR'AF;F. Al A:.?KA DAT~' A-~7-RR F,'FFFF;:.r--Nr:F' A~'~:rl r:A.¢:,'FT'~ t--Inl F r.:'l'i',,IAI ~-.-t~t /,.-'l -RF~ .T.N..IFF:TT. F1N F'r4'0F-]~I..F' RUN 't -4, 5" ~-t i ~-~-RR .~F"rNNFR'/TFHF'FR'~TIIRF ,~tlF:VFY RIlN t , ~'~" .'.'~- ~ 9 5- t F~-SR GAMMA R'AY-~f'.'.I R'I ItC 't., ~,; · 4-~,'4. 5-tg-RR TN,IE[]TTON F'RRF]'I. F RIIN t-4, 4---'t 7.., ~]-t 9-R~ TFMF:'F.'r-;,'.AT!!RF; Xt.!F;'VF!'Y F;:.I. IN ~ -4: ..'5' . ,,.. ~ . . · 7-..'79 &-R-RR A.'D.I.IFF.,.F F'FRFORATTNR R'FC. FIRO E'llN t · .. RETIJI-i'N TI-IF ATTA.f':I-IET) f.']{IF:'Y AS,' RE[:F;]]F.:'T OF DATA,. HArt-': A ? 2 7 1988 I:'FRE;Y RF~NNF"TT ~ Alaska 0il & Gas Cons. Commission A T R-- ~ ~ 2 C) Anchorage ~ T .~TR ~ ~t IT T DN .. '"' F: F N'I" !:;.' A i F" · .. ,I. I... f:: .... '"' P N T ! I T F:' X" ~ Ct-.tt.--VRFIN F'R I,I1~1.. !.. I:TI..I:.? D ,.*..: H -"- FXTFN,X'];f]N FXPI. FIR'ATTON -- ~ ............. -~- · "- F'KXRN ~ ..... ~,~TA'TF.', :OF MAF:ATt4Db' '"' TFXAf':R .,,. .MOB ! !.. - FI T 1' '~'' f'1'1" 'r ,~. RT T.q' nTl'.q [I'T'T ,? ~ C I.-I ARCO ALas'ka, Inc, F:'.O. Box ~O-0S60 Anchc~rage, A 99510 DATE: March 2'7, R E F' E R E N C E: r--~ R C 0 ¥.--t 4 S--i 6-87 4-4 S-i ~-87 4-6 :3--i 6-87 4-t L'3 S--t 3-87 4--1 G :3 .... t .5-8 7 '7 -- t S .- '7 - 8 '7 7..--2 S-6...-87 7-5 S.-8--87 '? .... 6 S, ... c~. --8 '7 7-9 5---6-~7 V .... 1 0 :3 ..--8 --- 8'7 7-.t 7 S-t t-87 '7 .... t 8 ¥.-.. 9-.. 8'7 t 3-2t S--t 2-87 t 4-4 3-22 .... 3 r J "z t FJ- ,~ S- t 4-8 '7 1 987 C'. a ~ ecl I-! o I. e I= i n a L F'rodLtc:'l:ion F'rofi l.e RLtn t, 5 C;R/CCI._ Run t, 5 In.j, I::'ro'f'i I.e Run '1, '."~ Ir,.j, F'ro'fi le Rut, 1, 5 F:' u. m r.~ I n "f' e m p ~I... o,.;j R u n t , '.:3 ~".~ /F Run t, '5 ,-.-I- inner I. uid Dens'ity ~"~ Run t ~; [ inner/FL u id De'ns i +. y ,S'pinner Run t, 5 ¢" ) ar. inner/'femP. Ru.n t, 5 ,~:pinner/Fl. uid Dens:ify Run ~?p inr, er/'remp ~ I:(un t, F'roduct:ion F'rofi I.e Run t, 5 ~;' p i n n e r / F I. ,~ i d D e n s' i t' y R ~ ~ t , 5 In.j~- F'rofi Le Run t, 5 'l'emp/F'l.o~m~'ter/Fl,~id I)en~i~y Run l..eak De'tec'~./Dif'f'.Temp/FLo~. Run t, 5 C a rfl c C a m c o C a fn c o C' a m c o (?, 8 fll C (3 fL:: a m c: o C a m c o C a m c o C' a m c o C8 nlc 0 C a m c: o Camco C a m c o Ca nIc o C a m c o g 'n a 'nd r e !' u r n 't' h e a t:.t: a c: h e d cz,,u;.> y a '..;' ~" e c: e i p t o f I::' l. ea.~e .,.; i . R,':;, c e i v e d B v ~. ~,~ ...................... i'.,.---7- ....... I..IAVE A NICE DA'¥~I~ ~ , .~. ~ ^lnska Oil & Gas Cons. Gommlomofl R o.s' a n n e F:' e e k Anchomoe A 'i'O - t ':::...- ,.-..":' ":':, D I *,5.-' T R I B U T I 0 N d ,3 't.' a ,. .Il. '"' C e r'~ '~' r a L I::' i L ~;;, .:.;' .,- F:' h i I. L i p z; '11' ,,. :I,':. C'. h e v r o'n F' B t,.J e I. I. F i I.e.s D & M F;,',:~* D '"' ""' 0 I'l i 0 , , '"' E x t' e'n.':J.' i o r'~ E x p i. o r a 't' i o'r'~ ..- ..... ,~ 11' .. , :~.,;. - .., -, - , II' ~'' -"~ " ' ' ' "'s:. :,:.,,.'.:,'!: a t'e :' o:f-A la~l<a '"' E x x (::, ri '11' · i".t a r a 't h o n :II: '1" e x a c o II, ,,,. Mob i L STATE OF ALASKA ALASK ,)IL AND GAS CONSERVATION COMN, 31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown [] Stimulate [] Plugging [] PerforateJ~' Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 64' RKB Feet 3. Address 6. Unit or P~,ope~;ty nar~eyvruanoe [~a ~os[ Office Box 100360, Anchorage, AK 99510 Un i t 4. Location of well at surface 33' FSL, 441' FWL, Sec. 26, T11N, R15E, UM 7. Well number DS 4-13 At top of productive interval 1391' FNL, 1871' FWL, Sec. 34, T11N At effective depth 1329' FNL, 1402' FWL, Sec. 34, T11N At total depth 1322' FNL, 1352' FWL, Sec. 34, T11N 11. Present well condition summary Total depth: measured 10845 true vertical 8993 , R15E, UM , R15E, UM ~ R15E~ UM 8. Approval number 78-31 9. APl number 10. Pool Prudhoe Bay 0il Pool feet Plugs (measured) feet Effective depth: measured 10782 feet Junk (measured) true vertical 8947 feet Casing Length Size Structural Conductor 111' 20" Surface 2692' 13-3/8" Intermediate Production 10826' 9-5/8" Liner Perforation depth: Cemented Measured depth True Vertical depth 320 sx AS 11 111' 111' 6400 sx AS 11 2692' 2692' 900 sx Class G 10826' 8979' measured 10222'-10262' 10277'-10345' 10360'-10375' 10512'-10522' , , , , 10570'-10610' 10630'-10666' 10678'-10685' 10694'-10704' 10714'-10724' , , , , true vertical 8564'-8592' 8603'-8651' 8661'-8671' 8767'-8774' 8786'-8824' 8839'-8865' 8873'-8878' 8885'-8891' 8899'-8906' , , , Tubing (size, grade and measured depth) 5½" 17#, L-80, 10054'MD Packers and SSSV (type and measured depth) BOT 3-H Packer @ 955'MD Camco Bal-O SSSV ¢. 2207'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED JAN 2 ]987 Alaska 011 & Gas Cons. Commission Anchorage 13. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 12484 10 Tubing Pressure 1468 Subsequent to operation 13212 10 1449 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run Il 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ,.~-~' Signed 2~~~~i~.~~ Form 10-404 Rev. 12-1-85 JCA (263-4361) Title Operations Enqineerin§ Manager Submit in Duplicate SUMMARY OF OPERATIONS Began perforating operations on 1/10/87. Shut-in well. RU perforating unit, pressure tested equipment. RIH w/gun #1, shot intervals 10512'-10522'MD (1/5 spf), and 10360'-10375'MD (1/5 spf), POOH, all shots fired. RIH w/gun #2, shot interval 10325'-10345'MD (1/5 spf), POOH, all shots fired. Secure well. Shut down due to weather. Resume perforating operations on 1/11/87. RU perforating unit, pressure tested equipment. RIH w/gun #3, shot intervals 10296'-10316'MD (1/5 spf), POOH, all shots fired. RIH w/gun #4, shot intervals 10225'-10245'MD (1/5 spf), POOH, all shots fired. Secure well, RD. Placed well back on injection. Depths referenced to BHCS 4/12/78. RECEIVED JAN 2 1987 STAT16/1-8 ', STATE OF ALASKA " ALASKA _ AND GAS CONSERVATION CC 'dlSSlON ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name o~ OperatOr 7. Permit Number ARCO Alaska, Inc. 78-31 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20305 4. Location of well at surface 9. Unit or Lease Name 33' FSL, 441' FWL, Sec. 26, TllN, R15E, UM Prudhoe Bay Unit ...... At Top Producing Interval 10. Well Number 1391' FNL, 1871' FWL, Sec. 34, TllN, R15E, UM 4-13 At Total Depth 11. Field and P0ol 1322' FNL, 1352' FWL~ Sec. 34~ T1LN~ R15E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKBJ ADL 28325 , 12. Date Spudded03/26/78 13' Date T'D' Reached04/14/78 i4' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re I 16' N°' °f C°mpleti°ns04/19/78* N/A feet MSL 1 17. Total Depth (MD+TV'D) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thicknes~ of PermafroSt 10845'MD, 8992'TVD .... 10782'MD~ 8947'TVD YES E~X NO [] 2207 feet MDI 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/SP, BHCS/CaZ/GR, FDC/CNL/GR, CNL/CCL/GR 2;~. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 9z~.0f/; H-40 S, rf. 1Il'' 30" 370 sw _A_S 11 13-3/8" 72.0¢A N-80 Surf. 2692' 17~" 6gOO mx AR ll - 9-5/8" 47.0~ N-80/RS-~. 5 Surf. 10826' ]_2~" q~D ~× C1~.~.~ C. 7" , 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) 5% 10054' 9955' See attachment ,, 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, GTC.) 12/05/78 Flowing , DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-M'CF WATER-BBL CHOKE SIZE GAS-OIL RATIO 12/07/, 8 11,8 TEST PERIOD I~ 2080 lO~?. g ~0o /,~ Flow Tubing i Casing Pressure CALCULATED OIL-EEL GAS-MCF WATER-EEL O1[ GRAVITY-APl (corr) Press. 925 --- 24-HOUR RATE ~ 4160 2044 0 27 28. CORE D/~'TA , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED .JAN 2 ~z 19~7 Alaska Oil & Gas Cons. Commi~ior~ Anchorage Form 10-407 JGA (263-4361) Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS .- NAME Include interval tested, pressure data, all ~luids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sadlerochit 10095' 8523' I N/A Top Base Sadlerochit 10762' 8999' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~jJ~ Title Oper. En~r. M~r. Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other 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 or,Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- ' jection, Gas-Injection-: Sh~t:in, Other-explain. Item 28: If no cores taken, indicate "none". Attachment to Well Completion - DS 4-13 10222'-10262'MD 8564'-8592'TVD 1/5 spf 10277'-10345'MD 8603'-8651'TVD 1/5 spf 10360'-10375'MD 8661'-8671'TVD 1/5 spf 10512'-10522'MD 8767'-8774'TVD 1/5 spf 10570'-10610'MD 8796'-8824'TVD 1/4 spf 10630'-10666'MD 8839'-8865'TVD 4 spf 10678'-10685'MD 8873'-8878'TVD 4 spf 10694'-10703'MD 8885'-8891'TVI) 4 spf 10714'-10724'MD 8899'-8906'TIfD 4 spf JAN 2 3 ]~Tn~ Alaska Oil & G~s C~ns. CommJssio~ Anchorage ARC~) AlaSka, Inc. Prudhoe Bay ~ngineering Post Office Box '~00360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager December 23, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-13 Permit No. 78-31 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JGA:sd Enclosure cc: Standard Alaska Production Co. File P1 (DS4-13)W1-3 ARCO Alaska, Inc. is a Subsidiary ol~ AtlanticRichfieldCompany .... STATE OF ALASKA ALAS,.. OIL AND GAS CONSERVATION COMN....,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing El Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate~;] Other 2. Name of Operator ARCO Alaska, Inc. 3. AC, d reCs Foss: Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 33' FSL, 441' FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1391' FNL, 1871' T11N At effective depth 1329' FNL, 1402' T11N At total depth 1322' FNL, 1352' FWL~ Sec. 34~ T11N 11. Present well condition summary Total depth: measured 10845 true vertical 8993 FWL, Sec. 34, FWL, Sec. 34, R15E, UM R15E, UM R15E~ UM feet Plugs(measured) feet 5. Datum elevptionfDF or KB) 64 RKB 6. Unit or P..rop6r, tv name Fruanoe ~ay Unit 7. Well number DS 4-13 8. Permit number 78-31 9. APl nurr~J_20286 50-- 10. Pool feet Prudhoe Bay Oil Pool Effective depth: measured 10782 feet true vertical 8947 feet Casing Length Structural Conductor 111 ' Surface 2692' Intermediate Production 10826' Liner Perforation depth: measured true vertical Junk (measured) Size Cemented Measured depth True Vertical depth 20" 320 sx AS 11 111' 111' 13-3/8" 6400 sx AS 11 2692' 2692' 9-5/8" 900 sx Class G 10826' 8979' 10570'-10610' 10630'-10666' 10678'-10685' 10694'-10704' 10714'-10724' 8796'-8824' 8839'-8865' 8873'-8878' 8885'-8891' 8899'-8906 Tubing (size, grade and measured depth) 5½" 17#, L-80, 10054'MD Packers and SSSV(type and measured depth) ' ~ B0T 3-H Packer @ 955'HD 6amco Bal-0 SSSV @ 2207'HD 12.Attachments Description summary of proposal~ Detailed operations p~gra;~ &BOPSketch ~3,. 13. Estimated date for commencing operation December 30, 1986 14. If proposal was verbally approved Name of approver Date approved 15.1 hereby/c~rtify that//t/~ f~r,~go~is true and correct to the best of rny knowledge Signed d/~/~~~~ Title Operations Engineerinq ManagerDate Commission Use Only Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance 8Ri~iHAL SIGHED BY LOHHIE: C. SI~ITil Approval No. ~pproved C~ Stt~3seqtteTtt Work by order of Commissioner the commission Date Submit in triplicate Form 10-403 Rev 12-1-85 QGA (263-436'1) ARCO Alaska, Inc. proposes to perforate DS 4-13 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. REF' BHCS 4/12/78 Proposed Perforation Intervals' 10222' - 10375'MD 10512' - 10522'MD STATE OF ALASKA ALASt. OIL AND GAS CONSERVATION COMI~ SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 64' RKB Feet 3. Aden)eSs~ Office Box 100360, Anchorage, AK 99510 6. Unit or Pf.,oper,t,y narrj, e FruQnoe r~ay Unit 4. Location of well at surface 33' FSL, 441' FWL, Sec. 26, T11N, R15E, UM 7. Well number DS 4-13 At top of productive interval 1391' FNL, 1871' At effective depth 1329' FNL, 1402' At total depth 1322' FNL~ 1352' FWL, Sec. 34, T11N 11. Present well condition summary Total depth: measured 10845 true vertical 8993 FWL, Sec. 34, T11N FWL, Sec. 34, T11N , R15E, UM , R15E, UM , R15E, UM 8. Approval number 78-31 9. APl number 5O-- 029-20286 10. Pool Prudhoe Bay 0ii P0ol feet Plugs (measured) feet Effective depth: measured 10782 true vertical 8947 Casing Length Structural Conductor 111 ' Surface 2692' Intermediate Production 10826' Liner Perforation depth: measured true vertical feet Junk (measured) feet Size Cemented Measured depth True Vertical depth 20" 320 sx AS 11 111' 111' 13-3/8" 6400 sx AS 11 2692' 2692' 9-5/8" 900 sx Class G 10826' 8979' 10570'-10610' 10630'-10666' 10678'-10685' 10694'-10704' 10714'-10724' 8796'-8824' 8839'-8865' 8873'-8878' 8885'-8891' 8899'-890t Tubing (size, grade and measured depth) 5½" 17#, L-80, 10054'MD Packers and SSSV (type and measured depth) BOT 3-H Packer @ 955'MD Camco Bal-O SSSV fa ?2F)7'Mf~ 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf 0 0 Water-Bbl Casing Pressure Tubing Pressure 0 0 0 8350 10 1412 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run Ill] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,(,~ ~/~)~~./ Title Operations Engineering Manager Form 10-404 Rev. 12-1-85 JCA (263-4361) Submit in Duplicate SUMMARY OF OPERATIONS ARCO Alaska, Inc. has converted DS 4-13 to water injection service. The well is part of the Flow Station 2 waterflood project. The well began receiving water on July 7, 1985. STAT16/1-8 ARCO Alaska, Ir~ .~ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 TeLephone 907 263 4248 · Donald F. Scheve .- .... .-.~ Operations Engineering Manager October 17, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Subject: DS# 4-13 Dear Mr. Chatterton: Attached is the Application for Sundry Approval to continue water Injection into Well 4-13 as required per Rule 7 of Area Injection Order No. 4. Very truly yours, D. F. Scheve Attachment Standard Alaska Production Co. L. L. Gantt, ATO. 1520 J. W. Groth, ATO 1570 T. ^. Billingsley/M.A. Lucich PRB 24 T. G. Zibell/L. J. Sennett, PRB 24 PRB Files (4-13)~ Oper. Eng. Files (4-13) Oil & t~s Cons. Commission ARCO Alaska, Inc. Is a Subsidiary o! AtlanlicRichlleldCompany AR3B--6132-C ~ ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order 1-1 Perforate I-I Other 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360~ Anchorage, AK 99510 4. Location of well at surface 33' FSL, 441' FWL, See. 26, TllN, R15E, UM At top of productive interval 1391' FNL, 1871' FWL, Sec.,34, TllN, R15E, UM At effective depth 1329' FNL, 1402' FWL, Sec. 34, TllN, R15E, UM At total depth 1322' FNL, 1352' FWL, Sec. 34, TllN, RI5E UM 5. Datum elevation (DF or KB) 64 ' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 4-13 8. Permitnumber 78-31 9. APInumber 50-- 029-20286 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 10845 ~eet 8993 feet Plugs (measured) Effective depth: measured true vertical 10782 feet 8947 feet Junk (measured) Casing Length Size Structural . Conductor 111 ' 20" Surface 2692 ' 13-3/8" Intermediate Cemented Measured depth ~ueVerticaldepth · 320 sx AS~ll 111' lll' 6400 sx AS 11 2692' 2692' Production i 10826' 9-5/8" 900 sx Class G 10826' 8979' Liner Perforation depth: measured 10222' 10262' 10277'-i0345', 10360',-10375' 10512'-10522' 10570'-10610' 10630'-10666~, 10678'-10685' , , 10694'-107003' 107t4 I-!O724',.:. true vertical :' 86'.1.5,, ',-8972 '" ':. .,,,..' . ,, · ' R~C~~, ~/"~,~) Tubing (size, grade and measured depth) (~C'~' 5½" 17tt, L-80, 10054'MD Packers and SSSV (type and measured depth) BOT 3-H Packer @ 9950'MD Camco Bal-O SSSV @ 2201'MD A~Cl~c~a~j~ 12.Attachments Description summary of proposal ~ Detailed operations program I-1 BOP sketch I-1 13. Estimated date for commencing operation N/A 14. If proposal was verbally approved Name of approver Date approved 15. I hereby, certify that.the foregoing is true and correct to the best of my knowledge Signed~-/f~._~~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Approved by Notify commission SO rePresentative may witness I Approval NO...~'~_ [] Plug Integrity F-I BOP Test [] Location clearanceI U ~ " ~pproved Copy Returned ORIGINAL SIGNED "¥ /,/~ ,,~ ~ ~ ~ by order of LONNIE C. SMITH Commissioner the commission Date INJECTION WELL ANNULAR COMMUNICATION VERBAL NOTIFICATION OF AOGCC PER AREA INJECTION ORDER #4 DATE: 10/17/88 TIME: 10:00 am NOTIFIED BY: Ellen Fitzpatrick AOGCC CONTACT: Mike Minder REASON: Injection Well 4-13 Annular Communication Per Rule 7 Requirements of Area Injection Order No. 4 DISCUSSl0'N: · DS 4-13 failed a State-witnessed MIT on 10/14/88. The 9-5/8" test pressure of 2160 psi declined to 1600 psi in 30 minutes. A repeat test had the 9-5/8" pressure decline from 2190 psi to 1940 psi in 30 minutes. During this repeat test, the 13-3/8" pressure increased from 520 psi to 1160 psi indicating 9-5/8" X 13-3/8" communication. The MIT was repeated on 10/16/88 (no State witness was present) with 2000 psi on the 13-3/8" and 2160 psi on the 9-5/8". Both casings passed the pressure test verifying that the 9-5/8" leak is above the 13- · 3/8" shoe and there is no leak from the casing to the formation. The tubing is intact with no bleeding required to maintain the 9-5/8" pressure below 1000 psi while tubing injection pressure is at 1750 psi. DS 4-13 will be a water injector only (no gas injection). Permission was requested to continue injection indefinitely unleSs annulus pressures indicate a tubing leak develops. If such evidence of a tubing leak occurs, a remedial workover plan will be developed. AOGCC RESPONSE: - Approval granted verbally to leave on injection for I week with a formal request to extend injection past one week. - State witness of 9-5/8" X 13-3/8" MIT is not required. Sundry Notice Req'd at this time? YES X NO Producti~upport Su~-~rintendent Orig: CC: Ann Comm Eng, PRB 24 Billingsley/Lucich Prod Sup Supt, PRB 20 Skaalure/Pierce Sr Wireline Supv, PRB 20 Kennedy/Wilder Field Area Eng, PRB 24 Sennett/Zibell DS Supv, FS#2 Clark/Robertson FS Supt, FS#2 Beaudry/Cavin DS Eng, DS#3 Surritt ATO-1586 Poel Office Box 100360 Anchorage, Alaeka 99510.0360 Telephone 907 263 4248 DmddE~ Opwa~m Englneedng Manager December 15, 1988 C. V "Chat" Chatterton Alaska Oil & Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: ~ Permit No. 77-37 ---------------- Dear Mr. Chatterton: Attached is the Application for Sundry Approval to continue water injection into Well 9-16 as required per Rule 7 of Area Injection Order No. 4. Very truly yours, D. F. Scheve Attachment CC: Standard Alaska Production Co. L. L. Gantt, ATO 1520 J. W. Groth, ATO 1570 T. A. Billingsley/M. A. Lucich, PRB 24 T. G. Zibell/L. J. Sennett, PRB 24 PRB Files (9-16) Oper. Eng. Files (9-16) DFS/TAB/prm 'DEC 2 o ]9,33 Alasl:~ 0il & INJECTION WELL ANNULAR COMMUNICATION VERBAL NOTIFICATION OF AOGCC PER AREA INJECTION ORDER #4 I I II DATE: * 12-12-88 TIME: 1:15 p.m. NOTIFIED BY: Ellen Fitzpatrick AOGCC CONTACT: Mike Mlnder 279-1433 REASON: Injection Well 9-16 Annular Communication ?.~,~ Per RUle 7 Requirements of Area Injection Order No. 4 , , . DISCUSSION: Water Injection Well 9-16 tubing x 9-5/8 annular pressure '~started tracking~ ~!on, pres_sure of 1700_.~__psi. · When 9-5/8" annulus pressure is bled tO builds up to 1700 psi in approxlmately~4 hours...~Nell was shut in and.passed MIT run on ~'". _!12-12-8~1. 9-5/8" annulus test pressure of 2100 psi decreased to 2060 psi I~-l-hour. Arco .,,,1~ plans to COntinue monitoring pressures with no additional work planned unless leak condition worsens. 9-16 is not a WAG well. AOGCC RESPONSE: Permission given to operate for 1 week. Send documentation on form 403 to operate beyond I week. I Sundry Notice Req'd at this time? YES X. NO.__ SIGNED: [ Orig: Productio~lupport Superintendent Ann Comm Eng, PRB 24 Prod Sup Supt, PRB 20 Sr Wireline Supv, PRB 20 DS Supv, PRB 14 FS Supt, PRB 14 DS Eng-ATO 1580 (8/28/88) I DEC 2 o Alasl:.~ 0il & C.~,~ " " STATE OF ALASKA ~IS ' ALASKA OIL AND GAS CONSERVATION COM SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend .' OperatiOn Shutdown ~ ~ Re-enter suspended well F'; Alter casing r'~ Ttme extension Change approved program Plugging '7 Stimulate. ? Pull tubing Amend order f Perforate [' Other 2 Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. 54' RKB feet · 3 Address 6. Un~ or Pmoertvn~me P. O. Box 100360, Anchorage· Alaska 99510 Pru~hoe B~y Unit 4. Location of wellatsurface 877'N & 175'E of SW cr, Sec 1, T10N, R15E, UM Attop ofproductive~nte~al 1414'N & 868'W of SE cr, Sec. 3, T10N, R15E, UM Ateffective depth 1553'N & 1395'W of SE ct, Sec. 3, T10N, R15E, UM At total ,w . 156 1425 of SE cr, Sec 3, T10N, R15E, UM 7. Well number DS 9-16 8. Permitnumber 77-37 9. APInumber 50-- 029-20257 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total deplh: measured true vertical 12589 feet Plugs (measured) 9195 feet Effective depth: measured true vertical 12546 feet Junk (measured) 9165 feet Casing Length Structural Conductor Surface 2727 ' Intermediate 11370' Production 1516 ' Liner Perforation depth: Size Cemented Measured depth ~ueVerticaldepth 13-3/8",72# 3100 SX 2727' 2727' 9-5/8",47# 1000 SX 11370' 8345' 7",29# 520 SX 12588' 9195' measured 11810'-11860' 11880'-11910' 11942'-12010' 12028'-12076' 12094'-12105' 12140'-12186' 122~0'-12248' 12298'-12333' 12350'-12370' 123~5' 12395'. true vertical 8649'-8684' 8698'-8719' 8742'-8789' 8802'-8836' · · · 8848'-8856' 8881'-8913' 8937'-8956' 8991'-9016' 9028'-9042' 9045'-9~56' Tubing (size, grade and measured depth, 5-1/2",17#, L-80, 10770'MD & 4-1/2", 1'2.6#, N-80, l1085'MD Packers and SSSV (type and measured depth, R [["C '?' ~, Baker FB-1, 11925; Baker FHL, 107~u~rc~l~a~)'B~i,~2~l~s{)~ak~l][0~'~'1' 12111'; ~ ;; .... 12.Attachments Description summary of proposal ~ Detailed operations program 13. Estimated date for commencing operation Continue Water In1action 14. if proposal was verbally approved BOP sketch nec 2 o Alasta Oil & Name of approver Mike Minder Date approved 12/12/88 15. I hereby/~ertify that the foregoing is true and correct to the best of my knowledge Signed..~.¢~f ¢~/~~ Title Operations'Engineering Manager Date 12/12/88 Commission Use Only Conditions of approval N~otify commission so representative may witness I Approval No. ~ Plug Integrity F'I BOP Test !'-I Location clearanceI ~-" ' ,Z~ --,7[::~ ~t'~~ ' by order of Approved by ~ Commissioner the commission Date Form 10-403 Rev 12-1-85 ARCO Alaska, Inc. Prudhoe Bay =ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager December 17, 1986 Mr. C. V. "Chat" Chatterton State of A1 aska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 4-13 Permit No. 78-31 It has come to our attention that an error was made on the most recently submitted completion notice concerning the above mentioned well. The status of Well DS 4-13 should have been listed as, Water Injector. Past correspondence to the State of Alaska has, however, referred to to this well as an injector. To correct this oversight and to insure proper status nomenclature, a corrected completion notice is attached along with a "Subsequent" Sundry Notice on the well's conversion to a water injector. Very truly yours, D. F. Scheve DFS/JGA:sd Enclosure cc: Standard A1 aska Production Company File: P1(DS4-13)W1-3 &taska 0i[ & Gas C:]n:~. Gomn~Jssio:i ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -. ALASKA ilL AND GAS CONSERVATION C~ AMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Water Iniector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 78-31 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20305 4. Location of welt at surface 9. Unit or Lease Name 33' FSL, 441' FWL, Sec. 26, Ti]iN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1391' FNL, 1871' FWL, Sec. 34, TllN, R15E, UM 4-13 At Total Depth 11. Field and Pool 1322' FNL, 1352' FWL, Sec. 34, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKB[ ADL 28325 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 03/26/78 04/14/78 04/19/78. N/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth whereSSSV set I 21. Thickness of Permafrost 10845'MD, 8992'TVD 10782'MD, 8947'TVD YES ~ NO [] 2207 feet MDI 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/SP, BHCS/Cal/GR, ~DC/CNL/GR, CNL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 Surf. ]11'' 30" q?f) sx AR ]] 13-3/8" 72.0~ N-80 Surf. 2692' 17~" 6&00 .~x AR ]] - 9-5/8" 47.05~ N-80/RS-95 Surf. 10826' 12~" 9Of~ .qx C18ss G 7" 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) 10570' - 10610'MD 8796'-8824'TVD ~; SPF ~ 1005&_' 9955' 10630' - 10666'MD 8839'-8865'TVD 4 SPF 10678' - 10685'MD 8873'-8878'TVD 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10694' - 10703'MD 8885'-8891'T~) 4 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10714' - 10724'MD 8899'-8906'TVD 4 SPF 27. PRODUCTION TEST Date First Production Method of Operation {Flowing, gas lift, etc.) 12/05 / 78 Fi owing Date of Test Hours Tested PRODUCTION FORIOIL-BBL GAS-MCF WATER-DEL CHOKE SIZE GAS-OIL RATIO 12/07/7~ 11.8 TEST PERIOD ~ 2080 ]022 fi ')n° /.~1 Flow Tubing Casing Pressure CALCULATE©..~ OIL-BBL GAS-MCF WATER-DEL OIL GRAVITY-APl (corr) Press. 925 --- 24-HOUR RATE ~' 4160 2044 0 27 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-~-80 JGA (263-4361) CONTINUED ON REVERSE SIDE "~'i ~:; . - 'L..-/ 29.~ 30. GEOLOGiCMARKERS" - . - ~ ~ . 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 Sadlerochit 10095' 8523' N/A Base Sadlerochit 10762' 8999 ' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed -,. . __~ Title ODer. En_~r. M_~r. Date __ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other 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". ARCO Ala.~ka, Inc. F:'.O. Box 1¢.JOS60 ~..~l~c. ho¥'@ge, Ala.~k@ DATE' I)ecember I t; 1986 REFEREi'~CE '. ,..,,.,,_.,.,',,-,r'.rt Ca.'-;ed Ho L.c.,._ Fi'ha L 'l"efnp/S'p in/Waterho t.d LIp F('un t , £..'p i n/Temp Run i , 'T' e m p / F' L o w m e t;. e r T e m p ~ L o g R 'T' e m P ,, ~ U. I' v e y F::. u. inj ~ F'rofi l.e.,.'Temp ,. CCL Tie i'n Log ~,. Te~'¢p Loq ....... '. . t-'.. ~..; F' L', m F; -- ~ n 'f' e m p ,. .? u. l- v e y F.' :: 'n 'I, F"~ .... ',..,'c + i on F'r c:f i F: E~ z .a !3 ',:"i e , _,=:..:;< A T C: - 'i =: 2 9 F'ni F'~: WeLL Fi i-.: ,~-: :'T -f a -i:. e of Alaska ~.. i E' X a ,'l_ (3 AF. iCO A~a~ka, Ir, c~ P~O~ Box ~g0S60 DATE' December 5 , t°°6 / ~! "~ r' N F,,_F,_RE CE:' ARCO Ca~.'ed t--Iol, e F'inal. i:;.', u r, I , R u 'nt , F.'.ur, I , # 5" 5" .U" 5" Y r.: h Ych ATL-i-i 52:.=' TRAN£ ~86798 -,- ,_..e'.,-~!'.,-a L r i Les Ex ,t. er~ i o'n Exp Lora± i E :=' X 0 ffia r a +. h ~.'.',-.i--. ; I ~ Phi L L i p_= F'B WeLL Fi Les F.: & D '"- 2oh i c, ': -"-/'," ~tate Of,rAta~ka '~' ARCO ALaska, Inc, F:',.O. Box i(')()S6(~ Anchorage, ALas°l,,m 995t (~ I)AI'E: Oqtober Si , i986 i',,E. FEF, E. NCE: ARCO Magnei'ic Tapes w/I.i.s'i'ing "~'4.-..9 7--9-.86 Magi'ape ECC:".:2476 CN-MS '"~4--t,3 7-.tt-86 Magi'ape EECC~:2475 (]N-MY ~4 .... 25 7-.31-86 Magi'ape ECC~:2509 CN--.MS F'Lease _sign and fei'urn ~!]e ai~i'ached copy a.s' rec:eipt' R ' r~ ~ ~ ~ i v e d ~, .~.~ .~. 0'3' '~" ~ Hn YE n N I C E ~~~~"/011 & Gas Com. Commission Ro~anne Peek ATO-t 'I'I:;~AN2 ~:86689 I) I STR I BUT ]]-ON of da ia ~ ,,~" Cen'l.'ra L F'i Ch evr on D & M [.]xt.'en.s' i on Exp Lorat.' i on Ex xon Mara t:hon Mob i [ F:'hi I. LiPs' F'B WeLL F'i Les R & D ~-'"' $oh Jo · "'~- 2tare of ALaska Texaco ARCO Alaska, Inc. P.O. Box Anchorage, Alaska 995 ~ ~ DATE: September tt, t986 REFERENCE: ARCO Cased Hole Final t 34 7-t5-86 ACBL/VDL/$IN/GR Run t, 5' 3-t0 ?-2t-B6 ACBL/VDL/$IN/GR Run t, 5' 4-t3 T-tt-86 Mufti=Space CNL/GR Run t, 5' tt-24 7-t4-86 ACBL/VDL/$IN/GR Run t, 5" IV tease gn ' R ec e~-' ~ fl~ Gas Cons. ~mmi~ion HAVRE DAY,':' : ~orage . Rosanne AT0-t529 TRAN$ ~86562 DISTRIBUTION Dre~ Dress Central Fires Chevron -ir T~ Extension Exptora'tion · ,-'"Exxon Hara~hon " Mob i l l' ARCO AI.a~k,.':~, ]]nc, . ...... F'.,O, Box I(..'.)(.)S6(-) DA"f'iE · ,.Jant.~aFy t 6, t 986 D,!; 4-8 .. . ;:.,...~ ,;.~ u 'r 'f a c e P 'r e .'.; .'..? u r e F' a !. I. o 'f 'f A R I.'.: 0 ~.. ~' ! .... i '" · ....O,S' 4 .-- 9 i D,~i: 4 - t S t 0..- 2.... 8 5 ,'.'.;' u 'r 'f" ,'..', c e i"' r e s' .'.-~ u r e != a I. I. o 'F t: A R CCI P I. e ...':'~ :i: e _~!: i g 'r'~ ,.':1 'ri d ¥' e .1: t~ 'r' 'r'~ '!: h e ...'.~ .1: t.. a c h 6? d (:: 0 P Y 8 ~.~: 'r' e c e J p '~' o '(: (:l 8 '1.- 8., I::..' e (:: e i v ~..:..', d B y ........................................................................... HAVlii] A NICE' DAY! I'.'.'.' e I. 1. y b'i.,::: F:'a 'r' I. a 'n cl A "f' 0 ..... I....,.'" 2 9 F D I ~.: T R I B U T ]: 0 N Nacka Oil & 6as Cons. Commission Anchor.~ge ARCO AlasKa. Inc. ~ Post Office L 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: November 7, 1985 Reference: ARCO CH Finals ~-2 --CE~/ 5-26-85 Run 1 5" Sch ~-6 -~Perf 7-4-85 1 5" Sch ~-6fq;ET 5-23-85 1 5" Sch ~-7 ~ CET 5-23-85 ' 1 5" Sch f~3~16'~ Co!lar/Perf 7-7-85 2 5" Sch 19'?Perf record 7-5-85 1 5" Sch ~4-13~Perf~,~,record 7-3-85 1 5" Sch *-/6-1j CET 5-22-85 v~-9- CET 5-10-85 v~-15 ~-CET 5-27-85 411-11~CET 7-16-85 ~4-5z/CET 7-29-85 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch Please sign as receipt of data. Received by ~~~..~. ~~~~ .~~?~' Para Lambert ~v~i, AT0 1429C gi~ 0ii ~ 6~s Trans 406 A,~s~0~a~e Chevron ' Phi 11 i ps , D & M PB Well Files Expl. Services R & D Ext.. Exploration. Sohio * Bxxon, state of' Alaska Marathon T~xa co · Mobil . ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 ']215 September 24, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 4-13 Dear Mr. Chatterton: Enclosed is a copy of the DS 4-13 Workover Well History to include with the Well Completion Report, dated 7/26/85. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L124 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AtlanticRichfieldCompany Daily Well History-Initial Report Instructions: Prepare and submit the "Initial Rel~e~t" on the first Dally work prior to spudding should be summarized District Alaska Field ?rudhoe Say Auth. or W.O. no. AFE 204331 Nabors 1ES Wednesday after a well is spudded or workover operations are started. .on th.e form giving inclusive dates only. ICounty or Parish Lease or Unit Title North Slope Borough ADL 28325 IState Alaska IWe"4~°'13 - w/o Re-c omp 1 e t ion AP1 50-029-20305 Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover Date 5/23/85 J.our Date and depth aa of 8:00 a.m. 5/23/85 5/24/85 5/25/85 thru 5/27/85 5/28/85 5/29/85 5/3o/85 5/31/85 Complete record for each day reported IA.R.Co's W.,. 21.66% Prior status If's W.O. 0430 hrs. 9-5/8" @ 10,826' 10,782' PBTD, 10,660' Cmt, Bled press off both ann Accept rig @ 0430 hfs, 5/23/85. 5-1/2" x 9-5/8" ann - 625 psi. 13-3/8" ann - 475 psi. Bled off gas f/both ann. 9-5/8" x 9-5/8" @ 10,826' 10,782' PBTD, 10,660' Cmt, Circ well w/8.5 sea wtr ND tree, NU & tst BOPE. Rn equalizing prong on T bar to ck f/press. Hook up ann to tank, flow diesel to AP tank; small flow vol. RU Schl, tst lubr to 1000 psi. RIH w/tbg puncher gun, perf 5' pup on top of PBR @ 9874'-9876.5' w/10 shots @ 4 SPF, POH, RD Schl. RU circ in to tbg, displ well to 8.5 ppg sea w tr. (SI press = 250 psi on tbg, 300 psi on ann). 9-5/8" @ 10,826' Circ hole vol twice & wt up to 9.2 ppg, monitor well; well dead. RIH w/spear assy, POOH w/tbg hgr. Pull 5½" tbg & compl jewelry, LD same. Tst pipe rams to 250/5000 psi. RIH w/fsh'g tls on 3½" DP, tag TOF @ 9849' DPM, rotate K-Anchor, POH. RIH, mill on pkr, CBU, POH. 9-5/8" @ 10,826' 10,782' PBTD, 10,660' Cmt, Mill'g on pkr _POH w/fsh; no rec'y. MU new spear assy on PRT, RIH, mill on pkr & Junk around pkr. 9-5/8'' @ 10,826' 10,782' PBTD, 10,660' Cmt, RIH Fin mill over pkr, POH w/fsh & Lb. RIH w/jet bskt to 10,671' DPM, wrk pipe free, junk around bskt. Rev circ thru Jet globe bskt & RIH to TD while circ'g, POH.~ RIH w/6" Jet globe bskt. 9-5/8" @ 10,826' 10,782' PBTD, TOH w/wsh pipe assy RIH w/6" Jet bskt, tag up @ 10,684', cut 1' core to 10,685', POOH, LD 6" globe bskt. RIH w/6" OD wshover assy, tag cmt @ 10,682' DPM, wsh to 10,692', TOH. 9-5/8" @ 10,826' 10,782' PBTD, TOH w/wsh pipe assy TOH w/wshover assy; rec'd 2 pieces coiled tbg. MU new wshover BHA, RIH, tag fsh @ 10,692', wrk over fsh & wsh dn to 10,693'; unable to go deeper, TOH to ck fsh'~-t~6 ~ The above is correct Signature ~dd ~__ ~ For form preparation and distribution, see Procedures Manual, Section 1(~, Drilling, Pages 86 and 87. Date Title 3 t '.~f,,- -,,. 7/25/85 ~'11~ Superintendent ARCO Oil and Gas Company ~ Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. iai Attach descr pti. on of all cores..Wor, k performed by Producing Section will be reported on "Interim" sheets until final Number all drill stem tests sequent -Y; ........ * on "Final" form 1) Submit "nterlm" sheets when filled out but not less frequently than every 30 days, or (2) completion. Report official or representa~vu -=o, on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. OIstrict ICounty or Parish IState Alaska North Slope Borough Alaska Field lLease or Unit IWell no. Prudhoe Bay I ADL 28325 I 4-13 W/O Date and depth as of 8:00 a.m. 6/o4/85 6/o5/85 6/06/85 6/07/85 6/o8/85 thru 6110185 6/11/85 The above is correct Complete record for each day while drilling or workover in progress 9-5/8" @ 10,826' 10,782' PBTD, Wsh over fsh. Cont fsh'g operations f/coiled tbg drlg assy; rec'd partial fsh. Cont wash over remainder of fsh @ 10,704'. 9-5/8" @ 10,826' 10,782' PBTD, POOH w/wsh over assy Cont wsh over fsh & cmt f/10,703' - 10,705'; unable to wsh deeper than 10,705' w/btm of fsh @ 10,707'. Circ & pmp slug Job, wrk & wsh over f/10,705' - 10,708'. Mx & pmp slug, POOH. 9-5/8" @ 10,826' 10,712' Fsh, 10,782' PBTD, POOH w/wsh over assy 9.1 ppg Brine Fin POOH, rec'd partial fsh. RIH w/fsh'g assy, tag TOF @ 10,711', wrk & wsh over fsh f/10,711' - 10,712'; unable to go deeper, POOH; no rec'y. MU & RIH w/8-1/4" shoe fsh'g tl assy. 9-5/8" @ 10,826' 10,782' PBTD, TIH w/jet bskt 9.2 ppg Brine RIH w/fsh'g assy, tag TOF @ 10,710' DPM, wrk & wsh over fsh; unable to get deeper than 10,710.5', POOH. MU & rn jet bskt, POOH. RIH f/2nd jet bskt rn. 9-5/8" @ 10,826' 10,782' PBTD, Mill on fsh/junk/cmt 9.2 pp~ Brine TIH w/jet bskt, circ, POOH. RIH w/mill assy, mill f/~0,707'-10,723'. 9-5/8" @ 10,826' 10,812' PBTD, RIH w/RTTS 9.2'ppg Brine Mill on junk/cmt f/10,723'-10,730', POOH. RIH w/Jet bskt, cut 1' core, POOH. RIH w/bit, tag TOC @ 10,734', drl cmt f/10,734'-10,812', C&C hole cln. Press tst 9-5/8" csg to 2000 psi; press dropped to 500 psi in 2 min, POOH. RIH w/scrpr to 10,070', POOH. RIH, set RTTS @ 2397' tst top FO; OK. RIH, set RTTS @ 2584', tst btm FO; OK. RIH w/RTTS to tst 9-5/8" csg. 9-5/8" @ 10,826' 10,812' PBTD, Rn'g 5½" CA 9.2 ppg Brine RIH w/RTTS, set @ 10,000', tst 9-5/8" csg to 2000 psi; OK. POOH, LD DP. Chg rams to 5½" &tst to 5000 psi. RU & begin rn'g 5½" tbg. /'~!'?,~(~i~ preparation and distri,l~on see Procedures Manual Section u, Drilling, Pages 86 and 87 IOate ITitle 7/24/85 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when opera'lions are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District JCounty or Parish I Alaska Field ILease or Unit I Prudhoe Bay Auth. or W.O. no. JTitie I AFE 204331 Nabors 1ES Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover Date and depth as of 8:00 a.m. 6/12/85 6/13/85 thru 6/14/85 North Slope Borough ADL 28325 Re-completion IAccounting cost center code State Alaska Well no. 4-13 W/O API 50-029-20305 IA.R.Co. W.'. ]Total number of wells (active or inactive) on thisI Icost center prior to plugging and 21.66% labandonment of this well 5/23/85 ] 0430 hrs. Complete record for each day reported 9-5/8" @ 10,826' 10,812' PBTD, Displ tbg/ann 9.2 ppg Brine Fin rn!g 239 its, 5½", 17#, L-80 8RD ABM compl string w/PBR @ 9950', 3H Perm pkr @ 9955', TT @ 10,054'. Instl & tst pack-offs to 5000 psi. ND BOPE, NU & tst tree to 5~00 psi. Remove BPV. Displ tbg & ann. 9-5/8" @ 10,826' 10,812' PBTD, RR Fin displ'g tbg to crude w/diesel cap. BPV. RR @ 1200 hrs, 6/13/85. Set pkr & tst; OK. Set Old TD I New TO liP80epth 10,812' Released rig Date ~Kind of rig 1200 hrs. 6/13/85 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Prudhoe Bay Potential test data We'll no.' D~te '" Reservoir Producing Interval Oil or gas Test time PrOduction Oil on test Gas per day Allowable EffeCtive date Pump size, SPM X length Choke size T.P. C.P. Water % The above is correct ;,..,.~!,j ~ Signature I Date Title For form preparation and d~tribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. ~- Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: September 25, 1985 Reference: ARCO CH Finals~ 3-26 Temp Log 'i~ ~3 ~-!~i"S p inner 11-1 Spinner 8-9-85 Run 1 5" GO 8-19-85 1 5" GO 8-14-85 1 5" GO Please sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 327 Ar~;horaoe Chevron' D&M Expl. Services Ext. ExploratiOn Exxdn Marathon Mobil Phillipsv PB Well Files R&D Sohio ~, ~state~-o~:Al aska Texa c~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date: September 12, 1985 Reference: ARCO CH Finals 4'9 Tubing Cutter 5-10-85 Run 1 5" Sch 4-13 Tubing Puncher 5-24-85 1 5" Sch Please sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 315 Chevron D&M Expl. Services Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R&D Soh i o State'" of Alaska Texa co ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer August 14, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas COnservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 4-13 DS 6-2 Permit No. 78-31 Permit No. 77-78 Dear Mr. Chatterton: Attached are "Well Completion Reports" for the above-mentioned wells. Very truly yours, D. F. Scheve DFS:JEB:pr Attachments cc: Sohio Alaska Petroleum Co. File P1 (DS 4-13) Wl-3 File P1 (DS 6-2) W1-3 RECEIVED Alaska Oil & Afdc;borax? ARCO Alaska, Inc. Is a Subsidiary of AflantlcRIchfleldCompany - ~ - STATE OF ALASKA '-~ ALASKA L ,~ AND GAS CONSERVATION CC' ,vllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 78-31 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20305 4. Location of well at surface 9. Unit or Lease Name 33' N & 441' E of SW. CT. Sec. 26, TllN, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1391' S & 1871' E of NW CT. Sec. 34, Ti]N, R15E, UM DS 4-13 At Total Depth 11. Field and Pool 1322' S & 1352' E of NW CT. Sec. 34, Ti]N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool 64' RKBI ADL 28325 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115'Water Depth, if offshore 116' No' of Completions 3/26/78 4/14/78 4/19/78 (perf' d 12/4/78)I N/A feet, MSLI Single 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD)19. Directional Survey I 20. Depth where SSSV set I 21.Thickness of Permafrost 10845' MD 9059' TVD 10782' MD 9014' TVD YES I~ NO [] 2261' feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/SP; BHCS/CAL/OR; FDC/CNL/OR; CNL/CCL/OR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,, 20" 94# weldl d H-40 Surf. 111' 30" 320 sx Arcticset II CMT 13-3/8" 72# butt N-80 Surf. 2692 17½" 6400 sx Arcticset II CMT 9-5/8" 47# butt N-80 & Surf. 10826' 12~4" 900 sx C1¢~$ O CMT RS 95 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) '10570' - 10610' MD 5~ 10003' . qRgn' 10630' - 10666' MD w/4 SPF 10678' - 10685' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10694' - 10703' MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USEI~ .... 10714' ~ 10724' MD TVD of perfs: 8796 - 8906' * Added on 7/04/85 w/1 shot/4 ft. 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 12/05/78I Flowing Date ~'(~t/78 H ° u r slte's~ed' TEsTPRODUCTIONpERIOD FORi~ OIL-BBL2080 GAS-MCF1022 WATER-BBL0 CHOKE20°SIZE I GAS-OIL491 RATIO FI°w TV~g Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. '- 24_HOUR RATE I~ 4160 20/42+ 0 27° 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Alaska Oil & Gas Cons. Cornm; Anch~,~rafi.¢ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' 30. '. GEOLOGIC MARKERS FORMATION TESTS , NAME. . Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10095 8523 None Base SadleroChit 10762 8999 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'¢~.,'7'f~...f.-~J..'~_?~_.A~~' Title Reg. Oper. Engr. Date.. INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc. Post offi'ce Bo,, 00360 Anchora~e,~Alaska 99510-0360 Telephone 907 276 1215 July 30, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT° DS 4-13 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J~]. Gruber Associate Engineer JG/tw GRU10/L94 Enclosure If RECEIVED AUG 0 ]985 Alaska Oil & Gas C~ons. Co{~mission Anchorag~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -~ ALASKA ~_ _ AND GAS CONSERVATION CG MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I-~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number " ARCO Alaska, Inc. 78-31 .... 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20305 , 4. Location of well at surface 9. Unit or Lease Name 33' FSL, 441' FWL, Sec.26, T11N, R1SE, UN Prudhoe Bay Unit ,,_ At Top Producing Interval '10. Well Number 1391' FNL, 1871' FWL, Sec.34, T11N, R15E, UM 4-13 At Total Depth 11. Field and Pool 1322' FNL, 1352' FWL, Sec.34, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 64' RKBI ADL 28325 12. Date Spudded03/26/78 13. Date T.D. Reached04/14/78 14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns04/19/78* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10845'MD,9059'TVD 10782'MD,9014'TVD YES ~ NO []} 2207 feet MD 1900' (approx) 2:~. Type Electric or Other Logs Run DIL/SP, BHCS/Cal/GR, FDC/CNL/GR, CNL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 Surf 111' 30" 320 sx AS II 13-3/8" 72.0# N-80 Surf 2692' 17-1/2" ~..,F64~-0~)-~x AS II 9-5/8" 47.0# N-80/RS-95 Surf 10826' 12-1/4" ' 9--'0~' 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} 10,630' - 10,666' 5-1/2" 10~054' 9955' 10,678' - 10,685' w/4 spf 10,694' - 10,703' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 10,714, - 10,724, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 12/05/78I F1 owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 12/07/78 11.8 TEST PERIOD I~ 2080 1022 0 20°I 491 .. Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 925 '" 24-HOUR RATE I~ 4160 2044 0 27 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED /~UG 0 fi; ].985 Alaska Oil & Form 10-407 * NOTE: Reoompleted 6/12/85. TEMP/WC61 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .. ~Eoi..bGi.~s.:M.Ai~,KERS -,'...., :~. -.7~. ~ :.?~.'.-.'-.: i./, .:- ~..: ' !,.... ,. ~F01~MATiON:i_~STS - · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , Top Sadl erochi t 10,095' 8523' N/A Base Sadl erochit 10,762' 8999' . 31. LIST OF ATTACHMENTS NONE 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ t/~j'~')(,~z ~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion),-so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc. Prudhoe Bay ~,~gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 23, 1985 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 4-13 Permit No. 78-31 Enclosed is the Subsequent Sundry Notice for work completed on the above-mentioned well. Very truly yours, D. F. Scheve DFS:JEB:pr Enclosures CC: SOHIO Alaska Petroleum Co. File Pi(DS 4-13)W4-3 ARCO Alaska, Inc, is a Subsidiary of AtlantlcRlchfleldCompan¥ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 33' N, 441' (Surface) E of SW cr Sec. 26, TllN, R15E, UM 7. Permit No. ~ 78-31 8. APl Number 50'- 029-20305 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-13 11. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 64' RKB I ADL 28325 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began re-perforating operation on 7-03-85. RU perforating unit and pressure tested equipment. RIH with gun #1, shot interval 10570' - 10590' MD (1 shot/4 feet; 6 shots total). Shut-in well, POOH, all shots fired. RIH with gun #2, shot interval 10590' - 10610' MD (1 shot/4 feet; 6 shots total). Shut-in well, POOH, all shots fired. RIH with gun #3, shot interval 10630' - 10650' MD (1 shot/4 feet; 6 shots total). Shut in well, POOH, all shots fired. RIH w/gun #4, shot interval 10650' - 10666' MD (1 shot/4 feet; 5 shots total). Shut-in well, POOH, all shots fired. RIH with gun #5, shot interval 10678' - 10685' MD (6SPF). Shut-in well, POOH, all shots fired. RIH w/gun #6, shot interval 10694' - 10703' MD (6SPF). Shut in well, POOH, all shots fired. RIH~w/gun #7, shot interval 10714' - 10724' MD (6SPF). Shut-in well, POOH, all shots fired. Secured well, RD. RECEIVED J u L 985 Oil & Gus Cons. Commission A nc:ho rage Ref: BHCS 04-12-78 14. I hereby c~rtify that the foregoing is tr. ue and correct to the The space below for Commission use best of my knowledge. Title Regional Op~r~on$ Enginee~ Conditions of Approval, if any: Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA --, ALASKA C._ AND GAS CONSERVATION COk, .,,'IISSION MONTHLY REPORT OF 13RILLINO AND WORKOVER OPERATIONS · Drilling well [] Workover operation~]~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 78-31 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20305 33' 4. Location of Well at surface FSL, 441' FWL, Sec.26, TllN, R15E, UM 6. Lease Designation and Serial No. ADL 28325 For the Month of June , 19 85 5. Elevation in feet (indicate KB, DF, etc.) 64 ' RKB 9. Unit or Lease Name Prudhoe Bay Unit lO. Well No. 4-13 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig @ 0430 hfs, 05/23/85. Killed well. ND tree. NU BOPE. Pulled 5-1/2" tubing. Milled pkr & recoverd. Cut 1' cmt core f/10,684'-10,685'. Fish (1-1/4" coiled tubing) in hole f/10,692' - 10,730'. Milled & washed to clean hole. Dropped BHA & 1 DC in hole. Recovered fish (TOF @ 10,668'). Drilled cmt to 10,812' (PBTD). Pressure test 9~5/8'' to 2000 psi. Pressure dropped to 500 psi. Ran RTTS. (see following sheet) 13. Casing or liner rgn and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Rep~;~Ct on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by th~. Dll~t~hnof/t~nsL~cceeding month, unless otherwise directed. Form 10-404 Submit in duplicate Monthly Report of Drilling and Workover Operations June, 1985 4-13 (cont'd) ITEM #12: 9-5/8" tested to 2000 psi - ok. Ran 5-1/2" tubing w/tail ~ 10,054', pkr ~ 9955' & SSSV ~ 2207' , . Disp to brine. ND tree. NU BOP. Disp tubing to crude. Displace 9-5/8" x 5-1/2" tubing annulus w/brine & diesel cap. Dropped ball, set packer. Set BPV. Secured well and RR ~ 1200 hrs, 06/13/85. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 2, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 4-13 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, , Gruber Associate Engineer JG/tw GRU10/L39 Enclosure If RECEIVED Ancho~ age ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA - ALASKA ~. AND GAS CONSERVATION CC MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL7~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 78-31 , 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20305 4. Location of Welt Surface: 33' FSL, 441' FWL, Sec.26, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 64' I 6. Lease Designation and Serial No. ADL 28325 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 4-13 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' 12. (Submit in Triplicate) [] Alter Casing [] Abandon Perforate [] Perforations Stimulate [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [~] ~, Other ~ 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 0430 hfs, 0,5/23/85. Killed well. ND tree. NU BOPE & tstd. Pulled 5-1/2" tubing. Hilled over pkr & recovered. Cut 1' cmt core f/10,684' - 10,685'. Recovered 5.3' of 1-1/4" coiled tubing. Tagged fish @ 10,692'. Washed down to 10,707'. POH, Recovered partial fish (9.65' in length). RIH & tagged T0F @ 10,702'. Washed over fish & cmt to 10,705'. Recovered partial fish (8.40' long). RIH & tagged TOF ~ 10,711'. Worked & washed over fish. Milled on fish/junk f/10,707' - 10,730'. (While POH w/mill assy BHA & DC were dropped downhole.) RIH & tagged fish @ 10,668'. Recovered BHA. Drld cmt f/10,734' - 10,812'. Tstd 9-5/8" csg to 2000 psi - dropped from 2000 psi to 500 psi in 1-2 min. Set RTTS ~ 2584' & tstd btm FO to 2000 psi - ok. Set RTTS ~ 10,000'; tstd 9-5/8" csg to 2000 psi - ok. Ran 5-1/2" completion assy w/tail ~ 10,054' pkr @ 9955', & SSSV @ 2207'. ND BOPE. NU tree & tstd to 5000 psi - ok. Set pkr. Secured well & released rig @ 1200 hfs, 06/12/85. RECEIVED 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢) O,/f~lJr~/ /~/~1¢~, Title Associate E.gineer The space bel~/vv for Commission use Date Conditions of Approval, if any: BV Order of Approved by COMMISSIONER the Commission Date .............. Form 10-403 GRU9/SN12 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay E neering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 18, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 4-9 DS 4-13 Permit No. 76-30 Permit No. 78-31 Attached are the "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve~~~ DFS/JEB/dh Attachments CC: Sohio Petroleum File Pi(DS 4-9)Wl-3 File PI(DS 4-13)W1-3 ARCO Alaska, Inc. 18 a SubsIdl.ry of AflantlcRIchfleldCompany RECEIVED J U N STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION CL~,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LI3I~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 33' N, 441' E of SW cr Sec. 26, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 64 ' RKB 6. Lease Designation and Serial No. ADT, 28325 7. Permit No. 78-31 8. APl Number 50- 029-20305 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-13 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Arco Alaska, Inc. proposes to perforate Well 4-13 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed perforation intervals: 10714'-10724' MD (10') (re-perf) 10694'-1070~~ MD (9') (re-perf) 10678'-10685' MD (7') (re-perf) 10630'-10666' MD (36') (re-perf) 10570'-10610' MD (40') (New perforation) Ref: BHCS 4-12-78 Work Reporte~ RECEIV ' J U N 2 '!0 Alaska 0il & Gas Cons. C0mm~so~0n' - o' Anchorage 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Title Regional Operations Engineer Conditions of Approval, if any: Approved by Ap,~roved Cocr~ R~t/jr nec~ By Order of COMMISSIONER the Commission Date Form 10-403 R,v 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. - .... Post Office Bo. 0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 13, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the May monthly reports for the.following wells: 3B-4 1Q-13 1R-6 2V-16 4-9 (workover) 3B-5 1Q-14 1R-7 L1-1 4-13 (workover) 3B-6 1Q-15 2V-13 L1-10 4-30 3B-7 1Q-16 2V-14 L2-24 4-31 3B-8 1R-5 2V-15 L2-28 9-34 9-35 9-16 (workover) 11-13 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L56 Enclosures RECEIVED J u N .l Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary ol AtlantlcRichfieldCompany STATE OF ALASKA ,'-- · ALASKA 0,6 AND GAS CONSERVATION CON,,,~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation)[~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 78-31 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20305 4. Location of Well atsurface 33t FSL, 441' FWL, Sec.26, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 64' RKB ADL 28325 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 4-13 11. Field and Pool Pr,udhoe Bay Field Pr,udhoe Bay Oil Pool For the Month of. May , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted r'ig ~ 0430 hr's, 05/23/85. Killed we]]. ND tree. NU BOPE. Pulled 5-1/2" 'cubing. Hi]ted pkr, & r,ecover,d. Cut 1' cmt cor,e f/10,684t-10,685', Recover`ed 5.3' of 1-1/4" coiled tubing. Tagged fish ¢ 10,692~ & washed down 'co 10,707~ as of 5/31/85, 13. Casing or liner ru.n and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--ReporCn this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. I=nrm ~ n-4n4 TEMP/MR62 Submit in duplicate ARCO Alaska, Inc. Post Office 5o4 100360 Anchor~§e, Alaska 99510-0360 ?ele~h©ne 907 276 May 16, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: DS 4-13 RErdEIV[D MAY I '.' '.Alaska Oil A Gas Cons. Commission Anchorage Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to do a workover on DS 4-13 in early June, 1985. If you have any questions, please call me at 263-4610. Sincerely, T. L. Fithian Area Drilling Engineer TLF/GLA/tw SN/L032 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360~ Anchorage, AK 99510 4. Location of Well Surface: 33' FSL, 441' FWL, Sec.26, T11N, R15E, UM 7. Permit No. 78-~1 8. APl Number 50-- 029-20305 9. Unit or Lease Name 10. Well Number h--1 '~ 11. Fi;Id' ~nd Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i I Pool __ RKB 64': Pad _~0' [ ADL 28325 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ~ Change Plans [] Repairs Made [] Other [] Pull Tubing ]~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170), ARCO Alaska, Inc., proposes to do a workover on DS 4-13 in early June, 1985. in the following manner: 1. MIRU workover rig. 2. Kill well. 3. ND tree. NU BOP stack and test. 4. Pull 5-1/2" completion assembly. 5. RIH and washover fish and cleanout to PBTD. 6. Recomplete with 5-1/2" completion assembly. The workover will be performed ' D ', "Alaska A subsequent su~ndry will be submitted following the completion of this workover detailing the added perforation intervals and completion details. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within permafrost intervals. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. ;~-b~e~]ue~t Work Reported 14. I hereby certify that_~ue and correct to the best of my knowledge. ~"~ Title Area Drillinq Engineer Signed The space below for Commission use Date Conditions of Approval, if any: Approved by COMMISSIONER ApproveO ~eturned By Order of the Commission Submit "Intentions" in Triplicate Form 10-403 ((;LA) SN/056 and "Subsequent Reports" in Duplicate Rev. 7-1-80 ARCO ALas'ka P,O, Box Anchorage, A t. as'ka 995t0 DATE' Sep'fember t~-..'", ~984 REF"FRE[NCE[' ARCO Cas'ed Hot. e Fin a I..~.~ 3;-7~'- 6--~ 0-84 D i 'l:"f 'f'emp -z._,-~o 6-4-84 CBl../VD ,.~1 ..... ,..i S-SO"'"~.- 7""8'-8 4 ACBI_/VDI../S i gna 't' ur e/l;R 4--t 73'/' ":5'. .... 25-.-84 C'.CL/F:'erf Record 7--6 -'""' 4--26-84 (;I-ii_ CH z.. . ., ."~C) ".~ t "~- t ~P ¢'"- ~': -. ,,...,.,-8 ::1. CI:."S/Sp inner t ''~.."- i 9. ' o "' ~ ,., 84 D i f f T e m p i6---8 ....... 6 .... it~-84 [;[;I.../F:'erf Record i 6-8 .... 6..--8-84 EF'L i 6.-..8 -"'-- ,..4....o.-oz~,., ,., , CCL/Per f Rec_ or d i ,5-8 "'"- 7-i 8-84 CET i6-8 /''' '5 .... 10-84 C:E:T i 7- t 0 '"'-- 6 - i ..,.=._.o ~t,.,. EF'L R ti n t 5 · 6-0 fi:un t 5" ,?;'ciq Run t ..,'='" I)A Rtll'i t 5" ,~cl"l R ut n t 5 · S c: h Run 2 5" r_;O Fi: tl'n:..} .'5" C. 0 R u Iq ") ':;'" c, c.: h .~;. _..- ,. Run t 5' S'ch Rt.tl3 t 5u ~*' ,., C h R u n t 5 · $ c h R t.t n t ':::._," £' c h Ruth t 55' ,'.?ch s'ign and re't'urn t'he at."~achect copy a..5' rec:eip'l: of d a ~: a, Ke L Ly McFar Land ATO-t 429F TRANS, ~63'7 l) I STR I BI.J T I Chevron I_:!:xpLora't-ion Service~' Extension Exptora't'ion Exxon 6et't'y Mara ~hon Mc, bi L Mob i i. E & P Phi L L ipz¢ Pr udhoe Bay We I. L R & D Sohio $~ate of ALaska Fi [es ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 1, 1984 Reference: ARCO Cased Hole Finals TDT 5" Sch CH CNL Run 5 TDT Run 2 CN/MSN/GR Run 2 CET Log Run 1 TDT ~ Run 3 TDT Run 1 ~~~--~-/~--.S. ~-18 , 4-28-~ Run 1 I O~-~- - --.S. ! 2i~84 PLS Run 1 / D.S. 7-26 -~/4-27-84 PLS Run 1 ~ D.S. 9-19~- 5-11-84 Collar/Perf Log Run 1 ~ D.S. 11-5 3-29-84 _S_p_inner/Basket Flw Mtr.. Run 2 ~ ,~ ~ ~-~~~. 12-16 4-~_~~4 T~~ Run 2 ~~ D.S. 12~17~5-20-84 Spinner Run 1 ~\~, ~,'~_ D.S. 12-18w/~/4-22-84 TDT Run 2 --~ ~ f'~~D.S. 12-21~/ 5-2-84 ACBL/VDL/Signature/GR Run 1 ~ D.S. 13-16,~/ 4-12-84 Spinner Run 1 ~ D.S. 14-2/`/ 5-3-84 CN/MSN/GR Run 3 ~ D.S. 14~~~./I 5-3-84~-------C~L~~ Run 1 ~ ~~. 14_-34 ~~84 TDT ~ Run 1 D. S .~- 3 ~, ~/~--5 - ~ - ~-8~----C-~~--~----~ Run 1 D.S. 16-8ww', 5-10-84 CET Run 1 D.S. 16-9'/~/ 5-13-84 Collar/Perf Run 1 5" GO 5" Sch 5" DA 5" Sch 5" Sch 5" Sch 5" Sch 5" DA 5" DA 5" GO 5" Camco 5" Sch 5" Otis 5" Sch 5" DA 5" Camco 5" DA 5" GO 5" Sch 5" Sch 5" Sch 5" GO CET Run 1 5" Sch EPL Run 1 2" Sch Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. #221 ~hevron D&M Have A Nice Day! DISTRIBUTION Mobil E & P Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, inc. Post Offic~ox 360 Anchoracj .laska 99510 Telephone 907 277 5637 March 19, 1984 Reference- ARCO Cased Hole Finals D.S. 4-1 12-5-83 D.S. 4-10"~' 12-9-83 D.S. 4-11~ 12-5-83 D.S. 4-13~' 12-9-83 D.S. 5-2'~- 1-13-84 'D S 6-8~ 12-9-83 D.S. 6-11~ 12-21-83 D.S. 7-15/z 12-18-83 D.S. 9-7"~' 12-4-83 D.S. 9-16~' 2-20-84 D.S. 9-17~'~ 12-4-83 D.S. 14-5-/ 3-4-84 D.S. 16-1~' 3-9 -84 D.S. 16-11~~ 3-10-84 D.S. 16-16~'~3-10-84 MS/CNL/GR EPL MS/CNL/OR CET Log Collar Log CH CNL CH CNL Perforating Record MS/Cm./OR Collar and Perforating Log MS/CNL/OR Collar & Perforating Log Collar & Perforating Log Collar & Perforating Log Collar & Perforating Log Run 1 5" DA Run 1 5" Sch Run 3 5" DA Run 1 5" Sch Run 1 5" Camco Run 2 5" Sch Run 3 5" Sch Run 1 5" Sch Run 1 5" DA Run l&2 5" GO Run 1 5" DA Run 1 5" GO 5" GO Ru-n 1 5" GO Run 1 5" GO Please sign and return the attached copy as receipt of data. HAVE A NICE DAY Kelly McFarland ATO-1429F Trans. # 101 DISTRIBUTION Chevron D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R&D Carolyn Smith State of '~""~' ~ ' '" aska : ,';.~ Bill Sheffield, Governor ALASKA OIL AND OAS CONSERVATION COMMISSION November 21, 1983 3001 PORCUPINE DRIVE ANCHORAG E,ALASI~A 99501'-3192 TELEPHONE (907) 279,-1433 · , ADMINISTRATIVE APPROVAL NO. 165.6 Re: The application of ARCO Alaska, Inc., Eastern Area Operator, Prudhoe Bay Unit, to substitute Prudhoe Bay Unit Wells 6-8, 4-1, and 1-10 for current key Wells 1-8, 4-13, and 5-7 in the Gas-Oil-Contact (GOC) monitoring key well program. Mr. D. F. S cheve Operations Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Dear Mr. Scheve: The referenced application was received on November 9, 1983 and stated that wells 1-8, 4-13, and 5-7 would no longer be suitable for GOC monitoring. Wells 1-8 and 4-13 are scheduled for con- version to water injection and 5-7 has recently undergone mechan- ical changes rendering it unacceptable for GOC monitoring. Our studies indicate the selection of Wells 6-8, 4-1, and 1-10 as suitable for continued monitoring of gas-oil-contact move- ment. The well substitutions will not cause undue problems and appears to be a prudent action. The Alaska Oil and Gas Conservation Commission hereby authorizes the substitution of Prudhoe Bay Unit Wells 6-8, 4-1, and 1~10 for Prudhoe Bay Unit Wells 1-8, 4-13, and 5-7 in the Gas-Oil- Contact Monitoring program, pursuant to Rule 9(c) of Conservation Order No. 165. Yours very truly, Harry ~. Kugle~ Commi s s ioner BY ORDER OF THE COHMISSION lc ARCO Alaska, Inc~-~- Post Offic~ ~x 360 Anchoraae. Alaska 99510 August 8, 1983 Reference: Arco Cased Hole Finals D S 1-20 -/ 7-17-83 D S 2-lA~'~' 4-15-83 D S 2-20 4-9-83 D S 3-12 5-8-83 D S 4-13~/ 4-23-83 D S 6-4 .......... 5-9-83 D S. 6-20~ 7-1-83 D S. 7-7A~ 7-3-83 D S. 7-11 4-16-83 D S. 7-14 ....... 4-22-83 D.S. 11-2 'j 5-7-83 D.S. 13-34/ 6-10-83 D.S. 15-11~~ 5-6-83 'D.S. '18-10'~'''~' 5-20-83 CFS CNL/GR/MSN PLS/PBU-Spinner CNL/GR/MSN CNL/GR/MSN CNL/GR/MSN CFS CFS CNL/GR/MSN CNL/GR/MSN CNL/GR/MSN CFS CNL/GR/MSN CFS / ~/Please sign and return the attached copy as receipt of data. Run 1 5" GO Run 8 5" DA Run 1 5" DA Run 3 5" DA Run 6 5" Da Run 2 5" DA Run 1 5" .GO Run 1 5" GO Run 9 5" DA Run 9 5" DA Run 2 5" Da Run 1 5" GO Run 2 5" DA Run 1 5" GO Kelly McFarland ATO-1429F Trans. # 450- Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil DISTAIBUTION North Geology Phi!liDs Prudho~ State cf Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 11, 1983 Reference: Arco .Magnetic Tapes' and Listings ~ D.S~7~25--~' 4-24-83 OH tape w/List Run 1 ' ~-24-83 RFT Pre-Edit w/List Run 1 ~D.S. 2-6--C--~ 4-14-83 CH CNL w/List Run 4 ~D S. 5-7/ 4-14-83 CH CNL w/List Run ~D.S. 9-4c~ 4-17-83 CH CNL w/List Run D.S. 1-8// 4-18-83 CH CNL w/List Run · D S. 7-26 4-8-'83 OH w/List Run .~D.S. 6-3/ 4-13-83 CH CNL w/List Run D.S. 7-14.,~ 4-22-83 CN/MSN w/List D.S. 4-13~,- 4-23-83 CN/MSN w/List 10 7 6 1 1 Sch #68216 Sch #68216 Sch #68214 Sch #68215 Sch #68201 Sch #68200 Sch #68176 Sch #68213 DA #1689 DA #1690 '[/Please s'ign and · return the attached copy as receipt of data. Kelly McFarland AFA-403 · Trans. # 336 NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL STATE OF ALASKA DALLAS' CAROLINE SMITH ARCO Alaska, Inc. '~_~. Post Office E 360 Anchorage. Alaska 99510 Telephone 907 277 5637 · March 24, 1983 Reference: Arco Pressure Data D.S. 2-lA 2-21-83 2-21-83 D.S. 2-5 / 2-3-83 2-3-83 D.S. 4-13 2-25-83 2-25-83 D.S. 13-8- 3-3-83 3-3-83 ?.~D.S.' 16-1/ 2-26-83 ~ 2-26-83 Pressure Build-up Camco Pressure Build-up Survey Report Pressure Build-up Camco Pressure Build-up Survey Report Pressure Build-up Camco Pressure Build-up Survey Report Pressure Build-up Camco Pressure Build-up Survey Report Pressure Build-up Camco Pressure Build-up Survey Report Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 ~.~ Trans. ~ 229 DISTRIBUTION NORTH GEOLOGY R & D MOBIL DRILLING GETTY PHILLIPS D & M SOHIO STATE OF ALASKA MARATHON DALLAS CHEVRON CAROLINE SMITH ~iasF, a~ IRC, Post Office ~ox 360 Anchorage. ~"~ska 99510 Telephone ~,,. 277 5637 December 8, 1982 RE: ARCO Cased Hole Finals D.S. 3-10 10-29-82 CH CNL/GR Run 4 D.S. 4-8 11-12-82 Spinner -D.S. 4-13 10-30-82 CH CNL/GR Run 5 D.S. 13-3 10-22-82 CH CNL/GR Run 2 'D.S. 14-7. 10-27-82 CH CNL/GR Run 2 D.S. 13-4 10-23-82 CH CNL/GR · Run 2 11 5" 5" 5" 5" 5" D/A SCH D/A D/A D/A D/A Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA-403 Trans. #645 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON 'EXXON MOBIL GETTY D&M STATE OF ARCO Alaska, Inc. Post Office ~'~x 360 Anchorage, Jska 99510 Telephone 907 277 5637 November 8, 1982 RE: ARCO Magnetic Tapes with Listings D.S. 13-5 11-1-82 SCH D.S. 5-14 10-30-82 Cased Hole CNL SCH Tape #ACC 66015 /D.S. 4-1 10-30-82 Cased Hole CNL SCH · Tape #ACC 66013 ~ D.S. 9-15 10-31-82 Cased Hole CNL SCH Tape #ACC 66014 Cased Hole CNL Tape #ACC 66016 ~.~ D.S. 3-10 10-29-82 CNL (6 passes) D/A Tape #ECC 1507 CNL/Multispace (2 passes) 'Tape #ECC 1503 CNL T~rpe #ECC 1508 _ Open Hole Tape #ECC 1489 CNL & CNL Repeat Tape #ECC 1504 ~, D.S. 13-3 10-22-82 D/A ~'~ D.S. 4-13 10-31-82 D/A ~..- D.S. 1-21 10-15-82 D/A ----' D.S. 13-4 10-23-82 D/A Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA-403 Trans. #608 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M .~STATE OF ALASKA~ DALLAS Run 3 Run 6 Run 1 Run 3 Post Office Box 360 Anchorage. Al .a.~k.a 99510 Telephone 90' 7 5637 July 26, 1982 Reference: ARCO MAGNETIC TAPES & LISTS D,S,7-7 5/17/82 D,S,7-7 5/17/82 D,S,3-6 8/17/80 D.S.4-13 5/12/82 DS, .18-2 7/14/82 Tape # ECC 1308 Tape # ECC 1308 Tape # ECC 734 Tape # ECC 1304 Tape # ECC 1372 NOTE: No lists accompained D.S.7-7 tapes. Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 305 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON E,~iXON MOBIL GETTY D&H GEOLOGY STATE'OF 'ALASK~ '~ ; Anchorage, Alaska 99510 Telephone 90~"~'7 5637 June 11, 1982 Reference: ARCO CASED HOLE FINALS D.S.7-7 5/17/82 p.s.2-22 5/18/82 D.S.15-5 5/8/82 D.S.7-7 5/17/82 D.S.4Cl3 5/12/82 D.S.7-7 5/19/82 D.S.5-4 5/22/82 D.S.14-20 5/26/82 P.S.12-8B 5/29/82 D.S.16-4 5/31/82 DS.'.14-11 5/28/82 C.AoT. W/Attached Reports/Casing Inspection/Field Interp. Run 1 5" ACBL/CDL/GR Run 1 5" Gamma Ray/Collar Log Run 1' 5" Magnelog Run 1 5" CNL/GR Run 3 5" Gamma Ray Run 1 5" CNL/GR Run 1 5" Collar & Perf Log Run 1 5" Collar & Perf Log Run 1 5" Collar & Perf Log Run 1 5" Collar & Perf Log Run 1 5" sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 226 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO' GEOLOGY MARATHON STATE. OF~AI. ASKA CHEVRON ARCO Alaska. Inc. is a subsidiary of AtlantlcRichfieldCompany ARCO Oil and Gas .... mpany North Alaska _,~strict Post Off;ce Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 16, 1981 Reference: ARCO CASED HOLE FINALS "~D' S. 15-11 10/23/81 CNL/GR Run 1 2"/5" .S.4-13 10/'18/81 CNL/GR Run 2 5" ~D.S.2-1A 10/18/81 CNL/GR Run 4 5" , ~.S.2-1A 10/19/81 CNL/OR Run 5 5" ~.S.6-6 10/25/81 Gamma'R~y Run 1 5" Mary F. Kellis North Engineering Please sign and return the attached 'copy as receipt of data. . Transmittal ~748 . DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company ,s a Oi~is~o..n of AtlanticR~chiieidCo¢~pany ARCO Oil and Ga~l~pany North Alaska trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Enginee'r November 16, 1981 Reference: ARCO CASED HOLE FINALS D.S.15-11 10/23/81 CNL/GR Run 1 2"/5" D.S.4-13 10/18/81 CNL/GR Run 2 5" D.S.2-1A 10/18/81 CNL/GR Run 4 5" D.$.2-1A 10/19/81 CNL/GR Run 5 5" D.S.6-6 10/25/81 Gamma Ray Run 1 5" Please sign and return the attached 'copy as receipt of data. Mary F. Kellis North Engineering Transmittal #748 , DISTRIBUTION ~ORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ~XON 'MOBIL GETTY ~HILLIPS ~EVRON IWaska 0il & Gas Cons. Commission. Aqch0rage ARCO 0il and Gas Company ,s a Divis,g,n ol AllanticRichfieldCompany ARCO Oil and Gar~pany North Alaska L,'istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 16, 1981 Reference: ARCO CASED HOLE FINALS D.S.15-11 10/23/81 CNL/GR Run 1 2"/5" D.S.4-13 10/18/81 CNL/GR Run 2 5" D.S.2-1A 10/18/81 CNL/GR Run 4 5" , D.S.2-1A 10/19/81 CNL/GR Run 5 5" D.S.6-6 10/25/81 Gamma'Ray Run 1 5" Please sign and return the attached 'copy as receipt of data. Mary F. Kellis North Engineering Transmittal #748 ~ DISTRIBUTION ~ ,/ ~ORTH GEOLOGY ~'XXON R & D MOBIL DRILLING G EITY STATE OF ALASKA EVRON Abska Oil & Gas Cons, Commissio. Anchorage ARCO Oil and Gas Company is a Divi~,ign ol AtlanticRichfieldCompany ARCO Oil and Gas'~"mpany North Alask,.. wistrict Post Office ~Box ,360 Anchorage, Alaska 99510 TelephOne 907 277 5537 Jerry A. Rochon District Operations En§ineer November 10, I981 Reference: ARCO MAGNETIC TAPES & LISTS D.S.4-13~--10/18/81 Tape #ECC 1144 D.S.14-15~-~170/6/81 Tape #ECC 1132 D.S.7-14~ .... 10/2/81 Tape #ECC 1128 D.S.7-11~'~'10/3/8i Tape #ECC 1133 D.S.4-1~?'/~ 10/17/81 Tape #ECC 1141 D S;13-7~// 10/7/81 Tape #gcc 1135 D S.11-1~/ 9/14/81 Tape #ECC 1116 D S.12-1J~J-'9/19/81 Tape #ECC 1121 DlS.12-13~j9/i3/81 Tape #Ecc 1115 D'S 14-16-~/9/4/81 Tape #ECC 1104 D.S.11-2~/ 10/6/81 Tape #ECC 1131 9900-10678 CN 10000-11570 CN/GR/CCL 10000-10977 CN 9500-10277 CN 10880-11450 CN 9670-11360 CN 10500-11781 GR/CCL 10600-11409 CN ' 8900-10500 CN 8700-10104 CN 9100-10150 CN Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #728 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MARATHON CHEVRON APCO (:'ii ,~qd Gas Company is a Divi$,~,n ot All,)nticRichheldCompany ARCO Oil and Gas C--~.mpany North Alask~ ,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer August 24, 1981 Reference: ARCO Magnetic Tapes & Listing D.S.4-13 8/21/81 D.S.17~10 8/21/81 Tape #CN/Multi-Spaced 9900-10700 Tape #CN/Multi-Spaced 8890-10330 Dresser Dresser ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #543 DISTRIBUIION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON CHEVRON ARCO Oil and Gas Company is a Division of AtlanticRichtieldCompany ARCO Oil.an~';'Gas C~mpany North Alask strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer August 24, 1981 Reference: ARCO CASED HOLE FINALS D.S.2-3 8/8/81 CNL Run 2 5" D.S.4-t3 7/29/81 CNL/GR/Multi-Spaced Run 2 5" D.S.13-2 7/31/81 CNL/GR/Multi-Spaced Run 1 5" D.S.14-11 7/29/81 ACBL/VDL/GR Run 1 5" D.S.17-9 7/29/81 CNL/GR/Multi-Spaced Run 1 2"/5" ase sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #542 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company ,s a D~ws,on of AllanhcRichl*eldCompany EXXON MOBIL GETTY PHILLIPS ALASKA OIL AND GAS CONSERVATION COll4MISSION f / ; .lAY S. ttA~IMO~YD, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501 TELEPHONE(907) 279-1433 June 22, 1981 A D M I N I S T R A '2 I V E A P P R O V A L NO. 165.2 Re: The application of ARCO Alaska, Inc., operator of the Eastern Operating Ar~ea~u__dhoe Bay Unit, to replace key well D.S. 4-7 with~D.S. 4-13~in the gas-oil contact moni- torzng program set out in Rule 9 of Conservation Order No. 165. .' Mr. J. A. Rochon District Operations Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Dear Mr. Rochon: The referenced application was received on June 19, 1981 and stated that the D.S. 4-7 well will no longer be suitable as a key well because of mechanical difficulties in the well bore. The application also stated that the well D.S. 4-13 would reflect the movement of the gas-oil contact in-the area of the field previously monitored by the D.S. 4-7 well. The Alaska Oil and Gas Conservation Commission hereby autho- rizes the replacement of the D.S. 4-7 well by the D.S. 4-13 well as the key well in the gas-oil contact monitoring program pursuant to Rule 9 of Conservation Ord.er No. 165. Yours very truly, Commissioner BY THE ORDER OF THE COMMISSION ARCO Alaska, Inc. Post Ofliccc¢=ox 360 Anchorag, ~aska 99510 Telephone 907 277 5637 June 22, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 16-6 DS 5-1 DS 16-13 DS '12-9 DS 17-7 DS 12-10 ~A'I DS t3-12 B-2 DS 14-18 B-3 DS 14-19 C-8 Dear Sir' Enclosed please find' , /' 1.) The subsequent sundries for DS'~'4-13 & DS 5-1. ./ 2.) The mOnthly reports for DS 12~10, DS 14~19, DS 16""13, DS 17-7, ~A-1 & B-3,./ ,l? 3.) The completion reports for DS 1229, DS 13'L'12, DS 14-18, DS 16-6 4 )~ThCe~l'G~rOscopic Surveys"for DS '12 DS I 8, DS 16-6 & C /~. P.A. VanDusen District Drilling Engineer PAV/KJG'sr Enclosure ARCO AI,'~sk,'l, inc. is m SLli.~Si(li;lry Of AIf;~nlicRIcl]fml,',ICon~P;w"¥ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C~JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ]~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 78-31 3. Address 8. APl Number P.O. Box 360, Anchoraqe, AK 99510 5o-029-20305 OTHER [] 4. Location of Well 33'N, 441'E of SW cr Sec 26, TllN, R15E, UM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-13 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 64'RKB I ADL 28325 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [~ Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Commenced operations @ 1300 hrs, 5/8/81. NU lub & tstd to 3500 psi - ok. Ran tbg puncher assy to 10,782' PBTD. Ran CCL. Perfd tbg fr/9846-9849'. Lost tool in hole while POOH. Pumped 1083 bbls of 9.6 ppg NaCl down tbg @ 1000 psi w/llO0 psi on choke to kill well. RIH w/fishing tools & retrieved lost tool. ND tree. NU BOPE & tstd to 5000 psi - ok. RIH w/spearing assy. Speared 5½" tbg POOH, laying down same. RIH & pulled K-anchor. Made run w/junk basket & circ hole clean. RIH w/RTTS & tstd upper/lower FO's to 2250 psi - ok. RIH to 6254' & tstd 13-3/8" csg to 2520 psi - ok. RIH to 9829' & tstd 9-5/8" csg to 2525 psi - ok. POOH w/RTTS. RIH w/new K-anchor & set @ 9875'. Tstd 9-5/8" to 975 psi - ok. POOH w/K-anchor. Ran 5½" completion assy w/tail @ 9702' & pkr @ 9633'. ND BOPE. NU tree & tstd to 5000 psi - ok. Tstd 9-5/8" x 5½" ann to 2000 pSiwelOk. RIH & pulled dummy valve @ 2255' Opened sliding sleeve & displ 1 to diesel w/ C-120 inhibitor. Closed sliding sleeve. NU lub & tstd to 3000 psi - ok. Ran GR/CCL to 10,782' PBTD. RIH & set SSSV @ 1927'. ND lub. Instld tree cap & tstd to 5000 psi ok. Secured well & released rig @ 0530 hrs, 5/18/81. 14. I hereby certify that th,e foregoing is true and correct to the best of my knowledge. Signed ',~~, ~/~_~ Title Dist. Drillinq Engineer The space below for Commission use - Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.f'-~' Post Office ~. _ .~ 360 Anchorage, Ataska 99510 Telephone 907 277 5637 April 30, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 4-13 DS 4-15 DS 12-6 DS 9-18 DS 12-9 DS 16-4 DS 16-5 DS 16-12 West Sak 18 Confidential West Sak 20 Confidential T-3C Confidential Dear Sir- Enclosed please find: 1. The Sundry Notices of intent for DS 4-13 & DS 4-15. 2. The subsequent Sundry Notice for DS 12-6. 3. The monthly reports of Drilling Operations for DS 9-18, DS 12-9, DS 16-4, DS 16-5, DS 16-12, West Sak 18, West Sak 20 and T-3C. Please note that West Sak 18, West Sak 20 and T-3C are considered CONFIDENTIAL. Sincerely, P. A. VanDusen District Drilling Engineer PAV/KJG'sp Attachments ARC() Alaska, h-it. is a t;ubsidiar,/ of AtCan~icRichh(¢idL;on~p;~rW STATE OF ALASKA '~ ALASKA ~JIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [~ OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 78-31 3. Address 8. APl Number P.O. Box 360, Anchorage, AK 99510 5oj329-20305 4. Location of Well Surface' 33'N, 441'E of SW cr Sec 26, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 64' 12. 6. Lease Designation and Serial No. ADL 28325 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 4-13 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ~[] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to repair production tubing leak(s) and casing leak(s) in this well. The 5½" production tubing will be pulled from the well and the 9-5/8" casing leak(s) will be repaired as necessary. The well will then be recompleted with new 5½" plastic coated tubing with gas lift mandrels. A 13-5/8" 5000 psi WP RSRRA BOP stack will be used on well work performed by the work- over rig. The BOP equipment will be pressure tested each week and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the perm.a- frost interval. Necessary provisions for subsurface safety equipment will be run in the completion string. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on wireline work as necessary. The downhole safety valve will be installed and tested upon conclusion of the job. Estimated start- 5/13/81 MAY - 1 1981 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,'3~, _~.~~ T itle~/~ The space below for Commission use Date Conditions of Approval, if any' Approved by Form 10-403 Rev. 7-1-80 ~..! By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas Company North Alask ~istrict Post Office x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District. Operations Engineer April 7, 1981 Reference: ARCO Cased Hole Finals D.S. 15-21(N-4) D.S.12-6 D.S.1-3 3/12/81 3/11/81 3/23/81 3/14/81 Collar Log/Gyro Correlation Run 1 5 Collar Log/Gyro Correlation Run 3 5 CBL/VDL Run 2 .5 Collar Log/Gyro Correlation Run ~ 5 Please sign and return the attached copy as receipt of data. Mary ~Keiiis North Engineering Transmittal #172 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG$ MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON Alaska Oil & Gas Cons. Anchorage ARCO Oil and Gas Company is a Division ol AtlanticRichfieldCompany ARCO Oil and Gas (~--,pany North Alaska .strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer June 8, 1981 Reference: ARCO'Cased Hole Minals .... ~?. ~ '-~'~ ~ 5 / 17 / 81 Gamma Ray Run 1 D.S.14-18 5/9/81 Diff Temp Log Run 1 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal f~334 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Division ol AtlanticRichfieldCompany Jtme 21, 1979 Reference' Enclosed are aressure buildups fox' the following wells' t D.S. / D.S. #4-12 D.S. #13-1 D S. #15-3 D.S. #9-1 D.S. #9-15 z D.S. #7-7 / D.S. #14-5 D.S. #7-10 D.S. 7-6 · D.S. #7-8 D.S. #6-6 5/22-23/79 Dresser 5/31-6/1/79 Dresser 4-25/5-6/79 Dresser 5-21-79 Dresser 5-20-79 Static Dresser 5-13-79 Go Wireline 5-16-79 Go Wireline 5-27-79 Static Dresser . 5-31-79 Static Dresser 5-26-79 Static Dresser 5-28-79 Static Dresser 5-24-79 Static Dresser 5-23-79 Static Dresser 4/29-5/1-79 Static Dresser 4-24-79 Go Wireline Please sign and return the attached copy as 'receipt of data.. . Very t~ly yours, R. A Hanlin North Operations Engineering Transmittal #190 D1SJ RI })U 1 ION ARCO Oil and Gas..~..Company F'ost Office ,_:,ox 3GO :(;-:chorage, P.!aska 99510 Teiopi~o:',,e 937 277 563'7 June 12, 1979 Mr. Hoyle Hamilton State of Alaska A1 aska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject'(~Permit No. 78-18 Permit No 78 31 DS 6-1 Permit No. 75-49 DS 6-2 Permit No. 77-78 DS 6-3 Permit No. 75-73 DS 6-4 Permit No. 75-62 DS 6-5 Permit No. 78-20 DS 6-6 Permit No. 76-20 DS 6-7 Permit No. 78-21 DS 6-8 Permit No. 78-22 Dear Si r' Enclosed please find a Completion Report reporting production information for the above-mentioned wells. Very truly yours,_ District Drilling Engineer PAV' cs Attachments ARCO Oil ;,nd G~.s Company is a Di¥;sion of AtlanticRic,hfieldC.-:_),~,;.,an/ F'(~rm P- 7 SUBMIT IN DIJ .... /CATE* STATE OF ALASKA ': (Sceothcrm* M ructions on OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* WELL WELL b. TYPE OF COMPLE~ON: ~w ~o,.~w°~"~ ~' ~ ~,~"~ ~'"'~~. oth~ Perforated WELL EN NAME OF OPERATOR ^tlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 LOCATION OF WELI~-(Report location clearly and in accordance with any State requirements)* At surface 33'N f 441'E of SW cc Sec. 26, TllN, RI5E, UM At top prod. interval reported below 1391'S & 1871'E of NW cc Sec. 34, TllN, R15E, UM At total depth 1322'S & 1352'E of NW cr Sec. 34, TllN, R15E, UM 5. APl N~CAL CODE 50-029-20.905 6. LEASE DESIGNATION A2qD SERIJkL NO. hDk 28325 7. IF INDL~N, A-LLOTTEE OR TRIBE NANIE 8. UNIT,FAitJVi OR LEASE NAME Prudhoe Bay Unit 9. WE3-~L NO. DS 4-13 (22-34-11-15) 10. FIELD A2qD POOL, OR WILDCAT Prudhoe Bay Field n. g~ Y.','~.~.y(b~k~o~ O~CWIVE) Sec. 34, TllN, R15E, UM 12. PER1VIIT NO. 78-31 13. DATE SPUDDED 3/26/78 18. TOff'AL DEI:~rH, 1VLD & TVD[19. PLUG, BACK ' MD & TVD~0. IF 1Vt-ULT]~PLE CO1VtPL., ! 21. 10,845'MD 9059'TVD' ! 10,782'MD 9014'TVDI' a°w~ff~le I ROTARY ~. PRODUCING IN~VAL(S), OF ~tS COMP~TIO~--~P, BOSOM, N~E (~ AND ~)* Top Sadlerochit lO,095'MD 8523'TVD Base Sadlerochit 10,762'MD 8999'TVD 24. TY~PE ELECTRIC AND OTH~ LOGS RUN .... D,IL/SP, BHCS/CAL/,GR,'FDC/CNL/GR~ CNL/CCL/GR 2~5. CASING RECORD (Report all strings set in well) INTERVALS DRILLED BY CABI,E TOOLS 23. WAS DIRECTIONAL SURVEY MADE Yes 20" 94# Welded! H-40'] l'll' ] 30", [320 sx Arcticset II cmt 9-5/8" 47# Butt [ N-80/~ 10,1826' 12-1./4 .900 sx Class ~ cmt / RS-gq , , , t=' ( ' , i AMOUNT PULLED DEP~{ SET (MD) ~ PACKER SET (MD) Ii ~8. ~ORATIONS OPFgN TO PRODUCTION ~interval size and number) ' l 0,630-I 0,666' , ' l 0,678-10,685' '10,694-10,703' ;-10,714-10,724' w/4 shots/ft. 10,003",[ 9880' 29. ACID, Si!OT, Fi%/LCI~, RE~ CEa~,IE:NT~, ,,., , ,SQUEL~ZE', ETC. DI~-~TIi iN'rEI~VAL (MD) AMOUN£ /'~D K1ND'(gF i~A'I'E?,2AL USED N/A ! /:)ATE FIRST 'Pi~oDUCTION 12/5/78 DATE OF T]~ST, |HOURS T~S~U~D . ' lclto:<E SIZE IPROD'N FOR OIL--BBL. GAS--MCF. ~i .... P~OD ]2/7~78 ]] 8' 20° w, ~ m Icxs~m P~ssu~ iCAL~~ O~BL. GA~ra~. ~SS. I [2~-aoua a~ .I 925 I -- ' I ' ~ [ 4160 I 2044 gl. mSPOSI~ON O~ ~aS (8Old, u~ed lot tuel, venteg, etc.)' Rei njected 32. LIST OF ATTACHMENTS . - , · PRODUCTION ~: PI~ODUCTION METIfOD (Flowfl~g, gas li£L pumping--size and type of pump) Flowing '~' ..... IW~LL ~TATUS (ProdLlc[ng or [ Producing WATER~-~BBL. J GAS-OIL l%,~TIO 022 I o I WA~BBL. [OIL GRAVITY-~I (CO~. I 0I JTEST WITNESSED BY 33.'i herebyC;~ t~t t~e 7eg~and ~ttached information is complete and correct as determined from all-available records SIGNED~~'~--- ~; TITLE District Drilling Engineer DATE *(See Instructions and Spaces for Additional Data on Reverse Side) 6/12/79 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items :20, and :22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item ?2 show the p~cJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAU. Y OF' PO~MATION T~S'I'.'-J INt'LUI)I N(; INTERVAL TEs'TED, PItES~SUIIE DATA. ~ '.RECOVERIES OF ()IL. GAS, 35. G ]~OLOG IC M ARK~:~ WATt'I! AND MUD NAM~ No ne ~,~-^s. onm~ ~uz v~'. nn,rm ,, , Top Sadl eroch~t 10,095' 8523' Base Sadleroch~t~ 10,762' 8999~ ii '"l'li ~' ~lr ...... I I I I I lll f~l0 .. i i i i i i ~ CT i i' [i i i i' i i i ii i i i i · ii m i .............. None , .... ,,,, ......... , ..... Norlh Alaska District Post Office F'~ 360 Anchora§e, ska 99510 Telephone 507 277 5837 March 16, 1979 Reference' Enclosed are the following cased hole logs: · '-DS .4.-lSU' CCL lZ/ S/TS ~;~75'~"~;T 2'' '~'" C N L 10 / 26 / 78 DS 14-S" CCL 12/ 1/78 DS 6-6v CCL 11/25/78 DS 6-6,~ CNL 12/ 7/78 DS 6-7~ CCL/GR 12/ 2/78 'Please sign and return the Sincerely, copy as receipt V.G. Reimers Nor th .Engineering TRANSMITTAL #101 North Geology Drilling Eng. Manager R&D Geolog DISTRIBUTION F~xxon Sohio Mobil Marathon Phillips Cl~evron Getty ,~-!or Ih :-",,,'n e ~i c a n N o~,h Alaska PoM Ollice Ancl~orage~Alaska DgSlO Telephone 907 277 5637 February 16, 1979 Reference'' Enclosed are the following Pressure Surveys' DS 1-18 Static-Survey 12/26/78 DS 4-12 Static Survey 12/1/7.8 -~._~S. 4~13!- Static Survey 12/3/78 DS 6-3 StaticSurvey 11/23/78 DS 6-4 Static Survey 11/23/78 DS 6-5 Static Survey 12/6/78 DS 6-7 Static Survey 12/10/78 DS 6-8 Static Survey 12/11/78 DS 7-2 Static Survey 12/16/78 DS 7-4 static Survey 12/19/78 DS 7-5 Static Survey 12/21/78 DS 9-20 Transient Survey ]2/4/78 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TtL/kN~'IITTAL # 73 DISTRIBUTION North Geology Drilling Eng. Manager R&D Geology State of Alaska D &M 'Exxon Sohio KobZZ Marathon PhLZZips Chevron Oe~ty Hoi'ih A~i'~ :C:.%kProducing Divisi,:;,r~ North Al ~ ~.~ .riot Post Oilic~ox 3~0 Anct~ora~je, Alaska 99510 T~lephone 907 277 5637 January 18, 1979 Reference: Enclosed are the following: DS 9-17 DS 5-1 1 DS 5-7 ¢"' DS 3-4 ¢' DS 3-6¢' DS 2-1-- DS 2-1 DS 5-11 DS 2-2 DS 2-12 DS 2-2 DS 2-4~''' . DS 4-13 Perforate and Cleanup Record ~S '4-12 / Perforating and Cleanup Record BHP Buildup and Flow Profile Analysis I! I! !! !! !! 6/26/78 6/18/78 6/18/78 9/16/78 9/19/78 5/20/78 8/28/78 11/27/78 9/08/78 6/19/78 4/08/78 4/07/78 12/12/78 12/12/78 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL #028 DISTRIBUTION North Geology Drilling Eng. Manager Mobil Chevron R& D Geology State of Alaska Marathon Getty D & M Exxon Sohio Phillips ' Atlaa~i¢,~lichfieidCompany Nc'.r~.h Americ-an Producing Division Norlh A~ask¢istdct Post Office. .360 Telephone 907 277 5637 December 26, 1978 Re~erence' Enclosed are the following Directional Surveys: DS 4-12 Gyroscopic Survey 12/6/78 DS 7-6 Gyroscopic Survey 12/6/78 DS 7-1 Gyroscopic Survey 12/6/78 DS 13-1' Magnetic Multishot 12/6/78 DS ~ Gyroscopic Survey 12/6/78 Please sign and return the copy as receipt of data. V.G. Reimers North Engineering North Geology Drilling Eng. Manager CeoJ ogy State og Alaska D &N: -. DISTRIBUTION Sohio MOb i 1 Hare thon Phil].~ ps C he_v ~on Cctty Atlantic~icn~ei~o m ~aay · December 12, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 6-1, Permit No. 75-49 DS 6-2, Permit No. 77-78 DS 6-3, Permit No. 75-73 DS 4-12, Permit No. 78-18 ~Permit No. 78-31 Dear Sir' Enclosed please fi nd a Completion Report along wi th Perforating Histories for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'jh Enclosures F'or n', SUBMIT IN Dlz ,JATE* STATE OF ALASKA ',se .... ti, er st ructions on reverse side; OIL AND GAS CONSERVATION COMMITTEE i i WELk cOMPLETION OR RECOMPLETION REPORT AND LOG* X~'. TYPE OF WELL: OH. ~ ~AS' ~ ~RY ~ Othe, WmLL ~LL b. TYPE OF COMPLE~ON: OVE~ EN .. WELL ' 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 33'N & 441'E of SW cr Sec. 26, TllN, R15E, UM At top prod. interval reported below 1391'S & 1871'E of NW cr Sec. 34, TllN, R15E, UM At total depth 1322'S & 1352'E of NW cr Sec. 34, TllN, R15E, UM 5. AP1 NU'M. ER/CAL CODE 50-029-20305 6. LEASE DESIGNATION AND SERIAL NO. ADL 28325 7. IF INDIgeN, A.LLO'Zq'EE OR TRIBE NAiViE 8. UNIT,FA/t/VI OR LF-~SE NAME Prudhoe Bay Unit 9. WELL NO. DS 4-13 10~ FIEIr~ AlXlD,~POOL,,.Ol{ V4II~DCAT ~ruanoe bay r]e~ Prudhoe 0il Pool 11. SEC., T., R., M., (BOSOM O~E~IVE) Sec. 34, T11N, R15E, UM 12. PER3/IIT NO. 13.. DA. TE SPUDDED [14. DAT~i T.D. I~F_~CttED [15. D,a-TE CO'IViP SUSP ~1t ABAND. ] 16. ELEVATIONS {DF, RKB~ 3/26/78 J 4/14/78 I 4/19/78(Perf'd 12/4/~8) 64'RKB ] 10,845'MD, 9059'TV0 10,782'MD, 9014'TqD Single I A~l ~. P~ODUCING !N~VAL(S), OF ~I$ COMP~TIO~P, BOSOM, N~E (~ AND Top Sadlerochit 10,095'MD 8523'TVD Base Sadlerochit 10,762'MD 8999'TVD 24. T~E E~CTEIC AND OTH~ LOGs RUN 78-3~ PCI~, GR, ETC)*]17. ELEV. CASINGHEAD ! INTERVAI,SDRILLEDBY i CABI,E TO O l.,,H 23. WAS DIRECTIONAL , SUltVEY MADE Yes t DIL/SP, BHCS/~CA, L/GR, FDC/CNL/GR, CNL/CCL/GR 25. CASIHG REcoRD (Report all strings set in well) CA, SI~'qG SIZE \VEIGPIT, LB/FT,~ Glq~DE ! DF-P'IX-I SET (1VLI2)) 20" 94~ Vie l aeq H-40 ! 1'1']~' ' 13-3/8" 72# Butt·!N-SO [ 2692' 9-5/8" 47# Butt ] N-80&[ 10,826,' · IRS-95 | , LINER I~EC Ot~D SIZ~ 28. PERFORATIONS OPF/N TO PRODUCTION ~interval, size and number) 10,630' - 10,666' 10,678' - 10,685' · 10,694' - 10,703' ~ 10,714' - 10,724' w/4 shots/ft. PRODUCTION HOLE SIZE [ C'EAILNTING RECOILD i AMOUNT PULLED 30" 1370 sx Arcticset 11 cmt II 17-1/2 [6400 sx Arcticset II ,cmt "[ t 12-1/4 900 ax Class 6 cm , 27. TUB~G RESOP~ 'i, 9 80, 29. ACID. SHOT, FiIACI URE, C~IENT SQUEEZE, ETC. DEk~TIt iNTIgRVA-L (MD) AMOUNF AND KIND OF MA'I'Ei'-LIAL USIKD ~/^ DATE FIRST PI%ODUCTION a/A DATE OF TEST, II-[OURS TESTED ']CI-IOXE SiZE [PROD'N FOR FLOW, TUBING ICA~LNG PRESSURE [CALCULATED OIL--BBL. 31. DmPOSIT~ON Or ~AS (8Ol'd, u, ed .for Iuel, vented, etc.) PRODUCTION MEIIiOD (Flowh~g, gas lif~, pumping--size and type of pump) [V(I~LL STATUS (Producing or I OIL--BBL. I I LEST OF ATTACHMENTS Perforating History 33.'I hereb7 certify that the fpr~d information iS complete and correct as determined from all-available ie~rd,~ SIGNED ~,~, TITLE District Dril 1 in~ineer o..m.: *(See Instructions and Spaces [or AdditiOnal Data on Reverse Side) 12/-13/78 INSTRUCTIONS General: This form is designed for submitting a complete and correct well cor~pletiOn: report and :l°g on all types of lanJs and leases in A~laska. Item: 16: Indicate which elevation is used as reference (where nOt otherwise shown) for depth measure- merits given in cther spaces on this form and in any attochmer~ts. ':e'ltems 20, an,:{ :22:: If this well is completed for separatc prcduction from more than one interval zone -....(multiple completion), so state ~n item 20, and in item 22 show thc p~cJuci~,El interval, or intervals, ¢ top(s), bottom(s) and name (s) (if any) for only the interv~l reported in item 30. Submit a separate report i,.(Paoe) on this form, adequately identified, for each additional interval to be seperately produce~, show- ~i-ng the additional data pertinent to such interval. Ite, m26: "Sacks Cement": Attached supplemental records for this well shouI-J show the details of any mul- tiple stage cementing and the location of the cementing tool. Item :28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ,, 34. SUMMARY OF FORMATION TESTS IN('LUI)IN(; IN'I'EI-~.VAL TESTlt, D, PI~ES~Si.;~LE DATA ~ /~ZbVERIES OF ()ILl GAS, WATfclI! AND MUD . , . ,, , , DS 4-13 Perforating History API 50-029-20305, ADL 28325, Permit No. 78-31 12/2/78 - Pulled dummy valve. Ran temperature survey. Perforated intervals 10 630' - 10,666', 10,678' - 10,685', 10,694' - 10,703', 10,714' - 10,724' wi~h 4 shots per foOt. All perf'd depths referenced to BHCS log dated 4/12/78. Ran Amerada pressure bombs. Ran and set flapper valve. Tested ok. Released well to Production Department 12/4/78. RECEIVED North Alaska District [:noinee_ ,~ z-'~na TRANSMI TTAL J. A. Rochon/D. R. ~ackson Date' . . . lfell Name' Transmitted herewith are..the following for the subject well' Run No. , Scale Xerox Sepia BL Line BHC SOnic/Caliper Log /' '~ BHC Sonic/Caliper - Gamma Ray Log .' BHC Soni¢/Gmr~ma Ray Log Caliper/eCL Cement Bond Log/VDL Compensated Fmmtation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Inter-val Core Description (Conv.) - Core No. Directional SurYey - Gyro Si!~gle Shot ~'~ltishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log ' · Formation Density Log/Ganm~a Ray Gamma Pmy/CCL Laterolog Location Plat Microlaterolog '~;2crolog ~'~dlog- Intez~al Sample Log (A.R. Co.) - IntmA~al Synergetic Log. TFD-DIL R¥D-Porosity Log Receipt Acknow].edged For' Date' P].ease return receipt Atl--fi~--ic R'chfield Co,nj)any NOrth Alaska Engineering Manager ~/~ d',-~4 P. O. Box 360 Anc]mrage, Alaska 99510 ,. ~.i ~ nticRic h field Company Norlh American Producing Division North Alaska District Pos.~ Office.' < 360 Anchorage, ,,.,,aska 9-95'10 ~\'~Telephone 907 277 5837 xJ~' 26, 1978 Reference' Enclosed are copies of the following cased hole logs' Differential Temperature Log NGI #3 NGI#10 ' D.S. #3-8 D.S. #4-9 Fluid Density -D.S. #3-8 D.S'. #4-9 11 Collar Log D.S. #1-11 D.'S. ~fl-15 D.S. ~fl-16 D.S. #4-15~ Hydro Log S" D.S. ~3-8 Please sign az~d return copy of transmittal as receipt of data. R.A. Logue~' North Operations Engineering Transmittal #371 GAS North Alaska ])istrict ]h]gineerJng 'T RAN SM I TTA L To' Frown' Transmitted herewith are the following for the subject we].l' Run No. .. -. Scale Xerox Sepia BL Line BIIC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log B~IC Sonic/Gamm~ Ray Log Caliper/CCL Cement Bond Log/VDL ___./]___ Con~,ensated. n . ~ Forn,ation Density Log (,omi_ ensat.ed Neutron-Formation' Density . Compensated Neutron Log Core Analysis - Interval Core No. (]ore Description (SWC) - Interval Core Description (Co. nv.) - Core No. D_irectional .Survey -' Gyro- Single Shot },'~ltishot Drill_ Stem Test - Test No. __.~___ Paal Induction Laterolog ~___tq_~-,/ Formation Density l,og · Formation ~ensity Log/Gamma Ray £;mma Ray/CCI, Laterolog Location Plat Microlaterolog Microlog [dudlog- Interval Santp].e Log. (A.R. C6,) '- i31ter~l Synergetic Log ~\ D~ D.[ L TVD-Porosity Log }receipt Ackno;,,'ledged For' Date' case return receipt to' A~i~itJ.(; Richfic. ld Co. any N6rAdn Alaska Engineering P. O. Box 360 Anchorage, Alaska 99510 T R A N 5 ~.I ~ T'J'A ]. r.. lfcll N.~mte · . AcS d or Yractm-e" ' . ] rcatmen'L Log ..... g!-lP Buildup [~ Flow Pro£ile Survey ];orehole Gcomet~~ Lo~ Carbon Oxygen Log . Casing Collar Log Cement Bond Log .~ Compensated Neutron Log- CaSed I-lolc .. Core Analysis - Interval COre Core I~5cx.tptlon (SxlC) - ~nterval .... --'Core D~scription (Cony.) - CoTe No. Directional. Sun~)-- Gyro . - Single Shot - ~'Mltishot '.]h]g~]]eering Productioa Log ]quid Analysis Grandma' Ray - l,ocation ...... Nonthly lfcll Te~t Data Nud Log .... Perforating Record State Reservoir Pressure Report Surveillance Reports _~_ Temperature Log . Tranaien t Pr essurc ' Survcys ...... TVD I,o~5 - ~et Induction I,atcrolog - Compensated Fo~mtion - Compensated Neutron- Density Log. - Borc]}o].c Com~]~.nsa1.cd- · - Sonic Log - Porosity l,og Scale' · }~ccc].t)c Tc)' }.Is. P.. A. ].oguc At] ant:i.c P,i.c]~[:i eld C:o;npany P. O. Box 360 Anclo'ragc:, Alaska 9951[) ' ' ~CrOX. Sep).a 'BL Lific . oo . Well Name' i'ranz~l~it, tTed herewLth are the following for the subject we].l' 1~n No. Scale · Acid or Fracture Treatment Log - BI IP Buildup & Flow Profile Survey ..........Borehole Geometry. Log Carbon Oxygen Log Casing Collar Log ........... Cement Bond Log ............ Compensated' Neutron Log - Cased Itole (:ore Analysis - Interval Core No. ....... 7 Core Description (~.xlC).- Interval ............. '- Core Description (Cony.) - Core No. -[-f-_~fff_ Directional Survey- Gyro - Single Sho~ -Engineering Production' Log Fluid Analysis . Fluid Density Gamma Ray I,ocation Plat Monthly Well TeSt Data " Mud Log -' Perforating Record State Reservoir Pressure Report Survei 1 lance Report s Temperature Log Transient Pressure Surveys ...... '--' TVI) Logs - bael Induction Laterolog - Compensated Formation Density Log - Compensated Neutron-Fomation Density l,og - Borehole Compensated Sonic Log - Porosity I,og ',cce:ip-t Acknowledged By' .,,.?.~...~L}` /~..ff~.;; '~.k,,-';". .... · "l. easc Retta-n Receipt To' Ms. R. A. L°gue At].anti. c Rich-field Company 'P. O. Box 360 Anchorage, Alaska· 99510 Date' Xerox Sepd. a 'BL Line AtlanticP~ichfieldCompany ~ North Americ~.~.~ Producing Division North Alask slrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 25, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 4-13 Dear Sir: Enclosed please find a Completion Report along with the Drilling History and Multishot Directional Survey for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure · ~ SUBMIT IN DI_,'?~..:AI'E' STATE OF ALASKA ~s. .... th,,~-m, slructlons on l'eVpl'~t, side; OIL AND GAS CONSERVATION COMMITTEE WELL MPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE 07 WELL: OiL l-VI uAs WELL WELL ~ DRY Other b. TYPE OF COMPLETION: WEI,I, OVER EN BACK P, ESV R. Other NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESSOF OPERATOR P.O. 'Box 360; Anchorage, Alaska 99510 4. r. OC~TzON or WrLb (Report location clearly and in accordance with amy State requiremet~ts)* at su~?N & 441'E of SW cr Sec. 26, TllN, R15E, UM at top prod. interval reported below 1391'S & 1871'E of NW cc Sec. 2~t total depth 34, TllN, R15E, UM 1322'S & 1352'E of NW cr Sec. 34, T11N, R15E, UM 13. D.kTE SPUDDED [i4. DATE T.D. REdkCHED Il5. DATE COMP SUSP Ol~ ABA,ND. IlO. ~EVAT'I.QNS iDF, RKB, 3/26/78 J 4/14/78 ~ c~j 4/19/78 J :,rB4'~ RKB ~'o~.~ ~, ~ & w~p. v~u~, ~: ~m & w~. ~ ~u~ ~o~., ] ~l,~ 10,845'MD, 9059'TVDI 10,782'MD, 9014'T~D ~OW~ngle , ,o~..,,,,~l,t ~. P~ODUCING IN~RVAL(S), OF ~.lS CO~P~TIO~--TO,P,BOSOM, NA~IE (MD AND ~)' Top Sadlerochit 10,095'MD, 8523'TVD Base Sadlerochit 10,762'MD, 8999'TVD 5, API NUi'~L!glUCAL CODE, 50-029-20305 6. LEASE DI~.SIGNATION A2ND SERIAL NO. ADL 28325 7. iF INDIA.N, ALLOTTEE Oft 'I'i{IBE NA&IE 8. UNIT,FA1UVI ON. L~ISE NAME Prkldhoe Bay Unit 9. WF~L NO. DS, 4-13 Sec. 34, T11N, R15E, UM 12. PE~iVIIT NO, 78-31 i~T, GR, *.~TC)*tlT. ELEV. CASINGttEAD ! INTERVAI.S I)R[I.I.ED BY CABI,E TOOI,$ 23, WAS D!.HECTIONAL Yes 1 24.TYPE ELECTRIC AND OTItIER LOGS RUN DIL/SP, BHCS/CAL/GR, FDC/CNL/GR, CNL/CCL/GR C~SI24G SIZE ,,! J \VEIGHT, LB, FT, 20" J94# Welded I3'3/8" 72# Butt 9-5/8" J47# Butt i, ~ 26. .LIN~ 1Rig C Of-kD S!Z~ i TOP (MD) EOTTO}/I (MD) [SACKS CLEMENT* ~8. PEi~FOR.ATiON~ OP~_LN TO PRODUCTION' (interval, size and number) N/A ]ASING REcoRD (Report all strings set irt wtll) { Gi~zkDEI i DEPTH SET (MD) i i N-80] 2692' ' N-80~I 10,826' "RS-95 [ ........ HOLE SIZI~I [ CI~MLNTING I%ECOILD 30" [320sx Arcticset II cmt 17-1/2"16400sx Arcticset II cmt 12-1/4" 190.0 sx Class G cmt . ,i TUBING HE'ZOItl) ,/c~.q OU NT PULLED 30. PH. ODUCTION DATE FIEST PILODUCTION [ P~ODUCT1ON ]MEI[iOD (Fiowii~g, t2:a$ llf~, pamping--size and type of pump, N/A DAT]~ OF TI~T, FLOW, TUBING GAS---2~ICF. 31. DISPOSITION OF SCi'iJLEN (~ID) SIZE DILPTII S}YI' (~,D} ~ PACi~IqI~ SET 5-1/2" 10.003' 9880' 29~ 'ACID, S~:OT, ~';~At:'t GHE. C~:,[KN'I' SQUJ_i/~i~Z~, Ih'PC D~Plli, IJ~'I'~V.~N/A (MDI _ ~ A2, I.~UNI' AND I',.iNI) Die MA'/E/[iAL USED I V, l%A., 1¢'1ATUS ( I'roducing or lq-OURS g_ESTIED 'JCilOXE SIZE JPP. OD'N PO~ OI~BDL,. 6ASISqG 'P~EsSURE/CALC~T~ OI~BBL. ~*s (,gold, u~ed yor ]uel, v~nte~j etc.) Dril Iing History, Mul tishot Survey i'~;~,.~,(~r~ ,q,q."I hereby certify ~n g and attached information is complete and correct as determined from all-a\.a'tlahle record~ SIGNED._ ~ TITLEDistrict Drlg._~gSnee__?_ ,~,l,,.: .AgrS]_25,_~1978 *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form 'is designed for submitting a complete and correct well completion report end log on all types of lan:Js and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~c. Jucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate 'report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoul:J show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. ': (See instruction for items 20 and 22 above). ' "~4. SUMMAItY OF "~'O~MATION T~'I'S INCLUI~IN(; INTEFLVAI., TF~'TED, PHE~URE DAT~ ~'~OVERI~ OF OIL, GAS. 35. G~GIC MARK~ ~AT~ AND MUD NA~ DRILLING HISTORY D.S. 4-13 API 50-029-20305, ADL 28325, Permit No. 78-31 Spudded well @ 1600 hrs 3/26/78. Drld 17-1/2" hole to 2710'. RU & ran 13-3/8" csg w/shoe @ 2692'. Cmtd w/6400 sx Arcticset II cmt w/0.6% D-13R. Drld shoe, cmt & 10' new form. Tstd to 12.1 ppg. Drld 12-1/4" hole to 10,810'. Dropped multishot. Ran DIL/SP, BHCS/CAL/GR, FDC/CNL/GR logs. Drld to 10,845'. RU & ran 9-5/8" csg w/shoe @ 10,826', FC @ 10,782', btm FO @ 2496', top FO @ 2369' Cmtd w/900 sx Class G cmt w/0.75% D65 & 0.2% D13R mixed to 15.8 ppg. Tstd FO's. Pumped 200 bbls wtr followed by 20 bbls CW7 then 300 sx 16 ppg Arcticset I cmt thru lower FO. Did Arctic Pack job thru upper FO. Displ mud w/wtr then wtr w/10.,5, ppg CaCI~. Ran CNL/CCL/GR logs. Ran gauge ring/junk bskt. RU & ran 5-1/2 compl ashy w/shear sub @ 10,003', pkr @ 9880', PBR @ 9869', landing nipple @ 2243'. Dropped ball & set pkr. Pulled dummy valve. Displ CaC12 w/diesel. Ran CCL/dummy gun. Reran & tstd dummy valve. RU & tstd xmas tree. RU for long term tbg tst. Released'rig @ 0600 hrs 4/19/78. ~~'t Eastman ~_ -, ~ ~-I Whipstock l)~ A PEIROLANE C,01,fPANY REPORT of SUB'SURFACE DIREC TIONA L ATLANTIC RICHFIELD COMPANY COMPANY ~4-13 WELL NAME P R[ID'r4C)'F: RAY LOCATION JOB NUMBER A478 SO299 TYPE OF SURVEY MULTI-SHOT DATE 4-12-78 SURVEY BY KEVIN DURLING OFFICE ALASKA DOG LEG ~ S U,',~ E S SEVEklTY SECTi,,," ~ ANGLE DEG/IOOFT OISTANCE ' ;- ~ r' n ,,'~ o- az ,'- o c ,:" :~4 .... 4.45 c iZ 1~.~1!2 ........ ~ ........ .{! ..... U..!E_:~.~:':s :'":,' ' ..... ' ~ , ................... ... ' .-. ' C'E._t~..:'}q ...... ~i: ~,:L. ............. .~!~_.._~_~._~ ........ 3.27' IA.,D4 S i2 °71..~ 2 r} 7717.".;-' ZF~',3,~.,:~ q13.:::,(>:' 4i 2,": ~' 9.al E.' 42,28 S !2 /.. . , .~ ,.., L.; ~ .. ~ ~ .., , ~,. ~.., ~ ~. .... ' - ::_A_T::'Jc! ....:.: ....~....i~_,'., :...z_.:: ........ : ~ · '2 ': A,'+ e ::% S ,:.. 7: ' 4 9.4 6 S :',,. "..." 41 z.. '.,~' 3 {} 4 :::', c. r~.., 2976 ·: 3 :":6 ~ - ",, {. :, 4 } · d: ': c : · 4: F:" q 5.7 O S l ! 6 . z ,, " ~" · ..................... Jt.~. 35 5 =,:__:::: ........ : ..... :,~ .... A.~_.:_::_.._._:..: ...... _: ,.<:2~._~ ..... ~ ...... : ~62 · ,._.=:: ........... :- n · 94 >, b 75 ,,. ,,,, ..... - ......::7 '~!~-,1,?7 '-/2.:.'>,,)W 9:.el " 1F.'17 ~.. :~.C2 c 24 ..................................................... 3320 P, l~' ?.?17.~i.~ ......... }25~.34 ".~4.i'".:,',' 92.79 S . :~C.:.?! ' 414.78 S 41 ........................................ ................................. :---: .............................................................. { l .......................... ~__. -_ .............. .:: _ ::.,-: .... --_.:::::... 9-::.,.,':',. ............. <_~.:3 ::_ 9:'..7~ ,, i g.&l sou ~S ~.": :774.,::: :'~::.~'~ ~. ~6~.:":',. 6~: " 32,~:~ ~v 15 36~ 3.?: :.:7<,c: ~ <" r. .,' '~7 " ,., lz, .:.2 ,'. i$ .49 E, 6,~ ....-- ~ .... , , · ~.. ~? ~') ~.~ · , · ~' ~ .~ , , .................................. ..................... - .........: ....................... L: , . . 4~..,4,,~, .?( 15 4':; ',"' ~, '-,2'3':,.2'7 '=?'2.:_':'.. ~,.~,'.] ; ~' ~,"'":::.}, ':.". :~ 22 5 a6 = ................... ~ ................ ~. ~ . ~,z,~,~ ':': ", a':c '~.~_,,:. ' ?i<,,.::L: __ S6~ "" ~" ,. ' .... -..=: .... ~__~ ............................... :: ...... : ~ ........... .< ~?v ..i .... 22- .1.2 .'. =::<:,~:9 S 07 _==:_.: ~ . : '37 59 .59 E 0.196 0,32 59 59 E 0.000 1,07 59 59 E 0,154 1,46 59 5'9 E 0,153 16 54 E 2,32b 2,98 31 46 E 0,2?2 3,67 33 ll E 1,616 6.~5 52 36 E 1,337 11.56 12 ll W 2.151 i7,32 29 14 W 2.161 25.96 29 59 ~ 0.57~ 37.,.t 19 44 W 1.625 51, 16 16 ~v 1.452 67.~'7 47 44 W 1,4~6 5C,5'f 38 28 W ,2,154 i07.~0 42 22 ;,' 1.~25 131.17 19 4~ w i,535 ib7,30 10 lo ',.,' 1,913 l~d~.ll :5 40 ',,? 1,140 217.1:: 44 3 ~'~ i. 14. C 53 q-6 ;.'; 3.594, '23,5L: A P !:'~ I L T !::. b' 7~ DOG LEG % ~, ,;: ......... ~"i:; ........ E~: ....... -(i';:';; ~: : :-~:~- F- -' ......... ¥':'i'~:':, ......... x-x-: ........ :-:-7 ...... 7:i- .................... }~ ........... ,,, .... ~- ,~ ., ~ .-;~ ,EPTH ,:,. ",. <~ L :::' D?.PTH 5E';A OIi::L.C DISTANCE ANGLE DEG/IOOFT DISTANCE ~ ........ ~:...,: · O H $ 4.~:_32_r,,._t ]!.[L ........ _ri .......... 9...q,:,};.!(: 4474.10 5d :'! , ;: ',':V/ !t7.56. 5 4R".Zb '" 462.41 £ 66 23 51 W ?.925 465 ,t~ml2 q7 0 4(-c7.61 zSZ3.f~l SgO.,.>C; o51.73 : 919.~v" O"z6,gS S 54 7 55 W 1.648 570.43 ' z~ ,:) :) d,33' 15 a 7 ('. ! · ',;~. 5 a ~: 9 ;~, · ~''', ,, ,':.,, c % I..50~',' 2 ,b >" · ,,,n a S 55 TM., · ~; 0 ' .... 6 '~,, 2. ? 4 ,S ,5, _~55 47 W 1 · 48 ~ ~ 23 · 52 · ', ~ .'% ,~ / .... ., .., ,, .... ~ ,.'/ q.,'2,09 q() r) ~ "0~ q, )4], ~ ..... ,. · .. .... ~ &P~:;.05 ',,'¢ ' , ......... ,~u .... 5 4, z.~.~ c~a.C~',' '~::'9 5'~ ~' 749.c. 6, S 61 21 1 ;" 0,691 735.00 ~,~ a,~ ~; z c~._~ ao~:~-~:~ 55~'. "'""," 3c4.75 ~: 7C¢,.TM ?~C")',3~, " 60 46 26 W "~.269 791.75 ......... ..... · .~. ,5 ~, · ~, ~' ',': 4 9 :~ · '~ :5c 5 " ~ , 0,586 965 · 65 '.L.(.:.. P6d.45, 5 95t.~.(::! " !lZo,b2 $ b9 2Z ~9 ~ 0.356 : ' ..... , ,.' :2z+1.71 5 ;:'9 6 40 w 0.765 1705.57 ~ · .5 .: :: .......... ~_ t::_.' ~_5_~ .... :c_._!!..(2.~..:::..: ....... t., ..... .,. ~ .,~( ,z_tT' 6 U 5 ~ ., 6 9 W 0 · 578 i: 31 · 17 . . .~ 57 5 58 52 37 W 0.74.7 14.qb.' ................................................................. O, ' '7.73 .51 1Z3<:.lz~ ,,,.., lSa3.c:q 5 bb 54 iO ',,~ 0,741 1511~.27 i ;", ;<c(,.7,'~ S 1296.22 , 16:;9.4~ a f.~ 5~ i ,, 1.&,,2 1~b2.36 .... - -, , .:,- ,-'," ~ .', c !5o'.'-'~- .. ,, ,..., u.Ou:O i773.5u . ~ v .:. ~.-. '-i '-7 ; · ...... ';,:::~.',~, ~ ~;:~t;. ,': ,, !::v,..'.~.5 S 5v 20 i ~; 1.064 ~:. 7 v ~ ', '~ ..... 7 --' F", = h. ~ 5 :"', 7 ~, z.. Z f, & o ................ - .... ' .... . ...... ..... .,,:~,t, 2. ~.:,,, c. v 5 :-; .... ~_Ai'. ............................ --:.- .................. .. _ ...... : .......... .~ i:p~f:.~ u b 59 '>5 24 " 0,269 190~.02 5 f 57 =i =, 15 F: 5 f · % '~ 20 · 5 R: ~, 2 · .._.., .._ _ ~_: :. -: t "_:/_ tL .... ~L'L'z_t_ :{ "i ..... 'z .... :'._'~;'i_~. t _7_ S~:. 9 30 27 ,~~0.000 1967 · 9 ~v.~-.:.:--)-'~ ..... :-;:---:--7-5v : ...... : --:'w--r-~ ...... C;~ " · ~ 2 %~j5. ,., :g 36 4} ,~' C, ~3 2,53Z.57 ~:~:. ~: ' -ICf. L, ~";-';: yr?;-;: .... :,.: ;7 ...... :iL{'~ .... <-~ :-. ~ , 0,532 2356.91 . -, ' ,, ., ' ..... ,. :.. v. ,. .... ~..~: ., 9 53 ic: ,', i26~',. 92 : ~-~-i'r--;::7 ;iT-F ......... i'j"FLirYi ,' ................. i:-'~::i ....... ~ ........ -. , .................. I ::lC L;IST,C,i~CE AtiGLE DEG/iOOFT DISTA,'.~CE ~,....._'_~:_'.._,:..~L: ...... :,_, :..2.=.i:L_.,,..tL ...... 5,.:.q.,.}..,_4:.5'. ..... ~oi.OOW' 1163,52 S lg7:,1!!,4~ :,.,: :::'.::~9('~,14 5 15,9 45 20 W C,7~7~ ~.~.3_ 1 .... ?423 47 15 ~Sq~','?:~. (:.~2a.73 F,r~4, ,,,: ......... ]..l<:..:> .... ? ....,_-_k:::.!..,.:->.' ~ ............... ~:...::~.:_-..~(.:?-. ....... ~ --~ -,0 ., 1,760 2296 75! 7 a~. ~: r,r :,-.:.p:~ ~'5;':r: ~',<'~ SiSg.'"',: 2i2 '::' c~ 2101 ~ ] 2426.07 S 60 1 19 W 3.057 2366.22 _'__.__.~...L .... --'..?L ..... t,.,'_'. ......... -~.?._'.'.: :rf.~_ v '.. '. ...... '2..... -': ..':: · .'.'::. :_~ .......... ". ......... , : ........ ' .... ' ..... 7 ~-_ >A;) _-'_t.Z!!__i',_'.,'__!i_.,_Z.5'. ....... t,.{.: %:i....__7_~.~ ............ ,57.6.? s :...,. ; 23 ;. v s s 2: t: _:. 4 s .- : q s ?. :: 6 s 5 o 2 0 4 3 ,,,, 4. ~ 23 2 ~ :: 1.21 7_:_':5_::_:.__-'+__.,.?_ ...... :,:! ....... 6_7_.~.:.q5 {.:_v~_:..,_.::_5 ..... ST.':.,.-):.:.:..': .......... _1.~_6t. 7.._,_ k:<.: ........ ~5._. :: 22:4._._ !_._7::55,,.12 s ~:,o 42 48 W 0.9:39 2~+:)3.82· ........ '__' ...... }:._~ .................................... : .............. ' , 79~3 4= 15 6:~n~ 14 Lo?~, 14 575 .-' / ,, .- · . ~ ..... c ................... :: ........... - ............................ - .... '. . "-' ' -_:_r:L_:: ..... _~. :_: ......... :. ~. ": LI ." _:::'_ L:. ..... ~ ~ ': ~::" : '2' '-) ' ~ .................. ........................................................... r' ~. ~, f:, 4= ' 7,'+ 4 9 :~ 7 F. 7~9 44. g~5 76!5,7~ 745] ,Yd. SL' ., ........ ., ,, · .c., Z,C 3 .................................................... q~lS 4a. vf,/,%., ;,7 '/:n: 7 ................... ' ,:o :.:,": 4~ :, ~7 1 r:,. "'7 ';' f~ {'_J'J.z. 7_7 .. C:lf' 5 4'~ :r-, 7Vt c_ : r: -z71~ c-:: c"- '--.5 '- .:-_ :'~_ _fL':: .... ' L '-.'.--t , _ 4 ......... ':.L.:.::: ~ E' -: "s 5 :;:'~"' ~2 3 ?4?:) l~. 7>:'~'."'": --_: '=: .................................. -, ,. ~, ~, . . O.,l',j..:: ~+ ,, -.]~,,.afi :,. :,.:~5' 9" ............. ~ ...... ~ ........................... .... : _.'. t /'; r.~,'. :, 23' .C'~' ~48 42 - ?'-,z..3.lc ':::'~ .19 , 21 40 W 1.07~ 2623.06 40 28 w 0.605 2665.94 59 46 W 0.601 2754.77 19 46 W 0,599 2821,24 ~ '.~ '7 I _ ,% ~' c ': -7 c' Z. ;'." · '~ ~; ' ~ ' ' '" ' ........... +. -:'._.L~. ~ ': >: .... ~: ..... ~:_:_:_..:..t::.2 .... .' ............ -- .-"'' ~2 5 o~ 21 ",, c PbO,.~ '~"~ '¢ ~ ' · '.-., 1392.9= ~' ,." ': :' :: ,1c,. . " ;..]~:5...,5'~ S 6~+ 4 ."' !417,9:5 S 3059,5~ '.- '372.14 ~''. ......... !9..(:_'2._,..!_5. :~ ..... ::. b,:__: :.:. ::___ ' 5.:'= :?..~" ~.E_._~__.qS' 2 ,.. ~47q 7~ :f, 5!F7,9:. . :.493,i:4 S 65 ,5" I~:5,P3 ::. 5"; ~:],/-c' -" . ............... : ....... ' .... ~:..: ..... -._., __ .:,7_:.:a.'-~O ~ 66 11 · ,, i ": .... q: '7 ...... .'' __ -,_'~...:.: ...... :.. .,._:_ :,7~.1C ~ <; 51 ................................................... 0.764 25~7.0~ · l":~z-;5.;:.'. "". 3477. :~5 - :-~:;'> o42 $ ':7 · '' - .................... --7 ........... '-- .'2 .......... -~T_ ....... "' o _i:~,'~"..~-;; .: 5,-+q :.'-- - . ,.:7~,5,L'5 a ,=;'7 ._ ' .... ~ :L__ _: ' ' . ............... ," ' l'~-'...:~oj, 4 :, 3{,:.-:..~-:'.. .. :;?,9','.4~ $ 6~ . · 6~i~, ',~'-...:..._ :::._ _. ~'=,.,, ...... ':-.,- =,: .,.., . ~5 c~.. .................................. 0 42 '~ 0.764 2~52.78 45 '¥; 0,601 30iS.23 17 W 0.'752 3C~4.09 21 ^' O,GOC.. 3i49,17 26 W 0..!543 32i3.99 4i W 0.3.47 327 g · ""~ 5 W 0.739 3342, 30 ',l (;.74,7 34C5.4b 3~; w C.538 346d,31 6 W 0.593 3:330,52 20 'r, 1.C90 ~=92.41 9 ;,.' 0.7lb Il 32 ~': 1.:J70 3';:11.73 32 ,~4 ','/ C.7©5 5773.16 54 3 v,, 0.53q- 3E29.0~ 15 53 '¢, 0.719 58 27 W I.~'00 5945.66 1 5'-.5 ?:, 0.'[77 a$C~.~;C, ., DOG LEG E S SEVERITY SECTION ANGLE DEG/iOOFT DIS. TAN,.,c'"": M S BOW t z.-2 ° ~ c: , .,.OC', c r'o 4! ,:,d'Sf;.62 S 69 P6 15 W 0,55z+ 40~1. '~.._ ......................... :: ......................... ~, ~ .............................................................. : .............................................. .' ".. 14~;2.97 ,S 4G(.)C:.6t', ',',' 4239.52 S 70 40 29 W 1.075 4236.67 · ,..:,,,. 1.38'0.34 S 4.13!.40 ,.,' ~,357.!!i0 b 7i 27 0 W C.269 435-6,03 · '".,.. , · . ,.~ 7~_ 48 59 W 0.538 4~+16.34 ',, ,',~57~.;~3 S 72 46 31 ~',~ 0.000 4574.58 '"'TTr;"-" ' "Ln '-L,;,'-,:Uq. 7 4~;7z+.5S ;-::Z''T 'T £ 72: 46 '-'~ ;_L ..... ; .......... ii-_'.:.<' .............. L.u .................................. ~- . ..... ' -~ ..... ' [)--4, APRIL i8, 197~ 764 764° 700 g' . ....... C ...................................... ],264 1264. 12:3( ,. " 16..74 S _ ............................................... ,. ..... , _ ....................................... ' ................ ~.h .... .'l ~.: · 94 S 1,60 o.6a S 1,99 12.04 S 2,7 ~:~ ~74 S 3,17 16.37 ..~; 3,54 E 4.12 S 4,31 4,45 4.57 - ~ ~. ~z ..................................... ....................................... ................... 2 ] % ~ :-.:! '-'; .:.,. ? I 7...'. '; ': 3, L :! 2 r., 4 · '~ ' ............... [ ...................................... 51_. '.' - . 2 :,'.6C S ',.' ~ 2 i. &.t 2 :": .~,~ ............................................................. 4°75 5.50 5.6'~ E · 6.56 h ................... ~ ~'~:;"-1 ......... ' ..... ~7i 1 !3.41 3 7,7i .......... ; . ............... ;: ............ ..,~ .- .. , .4! o '; co9 0.~3 :: 9 · 8 2 ,. 36. ...... 53.19 '.'. z '- :-4 :' - :. 4 · ? '::: (' "" _ ? ~ ~, 4 ,::':.: z.. 2 6. "" /: .................... 2' '9 ',': t' 2 :';" x~ ............................. ...... .~. . ,._. ,- ............. 3 '-5:? ~ ................... ': -.-:.. ~ "' :' :' ......... ~ .. ~ .. ............................................. APRIL 16~ 19'78 . T I CA,,L :" C T I 0," T(..,T;: L. C{:,C:{L) I f.iATE 5 3 '? 77 '~ 764, .370"([5 .............. i-~ 3 4199 ~ 164. ~.10'j 7f 5 7 ..................................................................... 4 ~'~'L 4484. 44C0 72 i ........................................................................ ~ 653 4. 5 .A 4 · 4 5 C):0 47 ?,2 46:54. 4G30 !}1.36 S 91,54 W 64,33 S 114,47 F9,57 S 171,51 I,C!.13..c' 205.35 i11.41S 242,13 i':)2.~5 S 2~ 65 i:S" .31 S 54 ,..'~ ,, '~ 1, e.. 7,2 g S Il:' 2~. Z4;::, 3l S ~84 6g W 445.38 W 505.23 W 564.57 47;07 4764, ,470© .............. ::i'F-;5 '6 1'7:. SS '::3':.93 S ?ii .3! 4S7,87 S 697.66 767.20 ~l:l 818.11 ~,'~ ~77 .......... i'~ 4!I b67i {:-."; & 4. {l ~ ;3 il, ,ii . 7 l-'?" ..... 1.3~ S 1563.63 .:.~I ~--]A~, ~l.,.,O.. r.'.~-~, 4~, c77.2~... S I~50.73~ ~'~ ................................. ................................. F963 f?~/4. {;23'~ SSt c= ia~:4.51 S 1739.73 W , .;_ ~. :,-0'~, ~.~ 4z. 117~.82 ~q 20~4.50 .. '.. ,.. ,. ., ............................................... ............................................................. 7'~:]~% :;.~:.:,4. 67"q:2 c~ 2 30 126:1.31 S 2291.96 W .~i~.~ ~ 2484,84 '~'~ TOTAL C©OP, D I/~ATES :~2.3.1 71f:4.. 7100 1 ,.5,?73 7,: ..,.,. .< .... ~ r' 1 z*,., '? 36~+. 73 .,?' .,,, ~ 655 '? 4 ~ 4 · 74 () 0 1 ~}796 7564.. 750~.,., t 4 ".; S 5 7 :S F: 4. 76 ',30 1 907~ 7764. 77Qr~ ' i 9212 7~.16~, 7f2;_ i ............................................................ 9347 7964. 7 .... :? 6 12 .'~ ............... .................... '.:.: 015 '? ' ,, ,g , , ,..~ ,j _.:5 7_.: ............... ,:: c ~+ ~ ....... !"' ' ..;, . :,7! 3 Co 6,-z ................................................................................... 42 I..5-2~1,71 ............... ...~. ................ ,...~ 82 · = ,_5-:,7 ...... ~"5--"'v:,V 2681.73 W 2780,00 W 2~79.13 W 2976.56 W 2;~.."' ' ....................................... 3'L: ............................ i%'-,~1,,.,3'> .... :. 3072.65 w 3]" ..::? !42:5.0g ,S 316,~.67 W : .;' c.., -~.~_ · 14 '~ F, ,..'h 1.... S '~ 262 · 80., :i::-q ":;:. ]4~" 22 .S .~., 3353,,15 W 3441.03 :3527.73 3616.06 ~,'~ 3705.51 3795.9'4 408,_, :,u .. 41~,1.76,_ W _ .'_ ...... . .... }"./i----]-~] .~) '- SCALE i'"= I000' 400 - , - ATLANTIC RICHFIELD CO. .......... RADIUS OF CURVATURE MAGNETIC MULTI-SHOT I~00 2000 ALL DEPTHS SHOWN ARE TVD $60C 4000 5EO0 5600 TVD : 9059', TMO 10~845 HORIZONTAL 'VIEW - '~ _' - -~ ..... .... SCALE !"= i000' ........... ATLANTIC RICHFIELD CO. .................................................................................................... W ELL-' NO': -'4-'13 -.- ; .......... ; .......... : ..... RADIUS OF CURVATURE ......................... MAGNETIC MULTI-SHOT ............... . ...... . .-- ........ ........ .~ .! .... ...................... . .......... : ......... :.,.._.~.__.._...,~ ................................ .............................................. . .......................................................................... .... . ................. · ................... ALL DEPTHS SHOWN ARE TVD COMPLETION REPORT ' DEC~~?8 ATLANTIC. RICHFIELD COMPANY D~4-13~; GYROSCOPIC SURVEY KB--EL-E-V 64 FT, RADIUS OF CURVATURE METHOD OF COMPUTATION DECLIh!ATION 31 DEGREES EAST CONPUTED FOR SDC BY F.M, LINDSEY AND ASSOCIATES 11-DO-GYM3-086 RECORD OF SURVEY ALL. CALCULATIONS PERFORbiED BY I B M ELECTRONIC COMPUTER TRUE MEA$. 'DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D bi S DOG LEG SEVERITY DEG/iOOFT SECTIC DISTANk.~. 0 '0 0 0.00 100 0 0 100.00 200 0 0 200,00 300 0 0 300.00 400 0 0 400.00 500 O O. 500.00 600 0 0 600,00 700 0 0 700,00 800 0 ~5 799,99 900 0 30 899.99 1000 0 0 999,98 -64,00 N O.OOE 36,0'0 N O.OOE 136,00 N O.OOE 236,00 N O.OOE 336,00 N O.OOE 436,00 N O.OOE 536.00 ' N O.OOE 636.00 N O,OOE 735,99 NiO.OOE 835,99 N30.OOE 935.98 N O.OOE 1100 0 0 1099.98 1035,98 N O.OOE 1200 0 0 1199.98 1135.98 N O.OOE 1300 0 0 1299.98 1235,98 N O.OOE 1400 0 0 1399,98 1335,98 N O.OOE ~500 0 0 1499,98 1435%98 N O,OOE 1600 0 30 1599,98 1535.98 S20.OOE 1700 0 0 1699,98 1635.98 N O,OOE 1800 0 0 1799.98 1735,98 N O.OOE 1900 0 0 1899,98 1835,98 ' N O,OOE 2000 0 30 1999,98 1935.98 N30,OOW 2100 0 0 2099.98 2035,98 N O,OOE 2200 1 0 2199,97 2135,97 N20.OOW 2300 1 45 2299.95 2235.95 S 2.00W 2400 2 0 2399,~9 2335.89 S30,OOW 1,67 N 0.42 E 2,08 N 2.08 N 0.5~ E - 2,08 N 0,53 E 2,08 N 0.53 E 2,08 N 0,53 E 2.08 N 0.53 E 2,14 N 0.8~ E 2,19 N 1,14 E 2,19 N 1,1~ E 2,19 iq 1.15 E 2.61 H 1.03 E 3,02 N 0,92 E 3,88 N .0.77 E 3,61 N 0,91 W 0,50 N 1,80 W 0.00 S 0 0 0 W 0.00 5 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 5 0 0 0 W 0.00 5 0 0 0 W 0,00 S 0 0 0 W 0,00 5 0 0'0 W 0.65 N 5 0 0 E 1.72 N 1~ 22 17 E 2.15 N 1~ 29 50 E 2.15 N 14 29 50 E 2,15 N 14 29 50 E 2.15 N 14 29 50 E 2,15 N 14 29 50 E 2.15 N 1~ 29 50 E 2.30 N 21 29 16 E 2.~7 N 27 34 22 E 2.~7 N 27 34 22 E 2.~7 N 27 34 22 E 2,80 N 21 36 31 E 3,16 N 16 56 49 E 3,95 N 11 14 36 E 3,72 N 14 12 25 W 1,87 N 74 29 28 W 0,000 0,000 0.000 0.000 0.000 0.000. 0.000 0.000 O,7fiO 0,250 0,500 0,000 0,000 0,000 0,000 0,000 0,500 0.500 0.000 0.000 0,500 0,500 1,OOO 0.764 0.252 0.00 0,00 0,00 0,00 ..... 0,00 0.00 0,00 0,00 -0,25 -0,91 -1.15 -1.15 -1,15 -1,1 -1,15 -1,15 -1,45 -1.76 -1.76 -1,76 -1.78 -1.80 -1,92 -0.23 1.56 ARCO DS 4-13 GYROSCOPIC SURVEY R~CORD OF SURVEY ALL CALCULATIONS PERFORMED BY. I B H ELECTRONIC CONPUTER DEC 06, 1978 TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. -2500 2 15 2499,82 2435,82 S35,00E 2600 1 15 2599,77 2535.77 S14,00E 2700 1 30 2699~75 2635.75 $35,00E 2800 1 15 2799.72 2735,72 S45,00E 2900 2 15 2899,67 2835,67 $50.00E 3000 3 30 2999,54 2935.54 N60.OOW 3100 6 0 3099.19 3035,19 N69,00W 3200 8 0 3198.44 3134,44 NTI.OOW 3300 8 45 3297,37 3233,37 N 5,00W 3400 9 30 3396.11 3332,11 S82,00W 3500 10 45 3494,55 3430,55 S60,OOW 3600 13 0 3592,40 3528,40 565,00W 3700 14 30 3689,53 3625,53 562.00W 3800 16 30 3785,89 3721,89 S65.00W 3900 18 15 3881,32 3817.32 S67,00W 4000 19 30 3975,94 3911,94 S71,OOW 4100 19 30 4070,21 4006,21 S73.00W 4200 22 0 4163,71 4099,71 578,00W 4300 25 30 4255,23 4191,23 $75.00W 4400 28 45 ~344,22 4280.22 S71.OOW 4500 31 15 4430.82 4366,82 S70.OOW 4600 35 0 4514,55 4450,55 S67,00W 4700 ~6 0 4595.96 4531,96 S62.00W 4800 37 15 4676,21 4612,21 S60,OOW 4900 38 0 4755.42 4691.42 S55,00W 5000 39 0 4833,68 4769,68 554.00W 5100 39 0 4911,39 4847.39 S54,00W 5200 41 15 4987,85 4923,85 555.00W 5300 40 15 5063,61 4999.61 S57.00W TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M 3.00 $ 1,65 W 5,77 S 0,39 W 7,94 S 0.59 E 9,77 S 2.13 E 11,84 S 4,38 E 14,59 S 2,45 E 3,43 S 28 49 39 W 5,78 S 3 55 25 W 7.96 S 4 16 32 E 10,00 $ 12 18 47 E 12,62 $ 20 19 19 E 14,80 S 9 32 20 E 12.12 S 24 25 25 W 17.83 S 67 20 55 W 25.25 N 80 55 39 W 38,24 N 70 26 7 W 11~)3~ S 5.01 W 6~7~ S 16.46 W 3¶!~8 N 24.94 W 12 ,~ 0 .iN ...... 36,03 W ¢ ~' ~...~..~.~o,~.t 7 o. 8 4 s 8 8 4 2 9 w 12, 92.98 S 81 58 23 W 147,97 S 75 29 58 W 180.14 S 74 20 6 W 213,50 S 73 58 12 W 248.90 S 74 11 15 W 289.1~ S 74 30 34 W 334,70 S 74 18 14 W 384,60 S 73 48 35 W 439,03 $ 73 9 0 W 496,49 S 72 8 33 W 555,14 S 70 57 9 W 614,66 S 69 37 44 W 674.95 S 68 14 59 W 736,11 S 67 2 38 W 799,13 S 66 2 25 W 863,48 S 65 17 7 W 37,05 S 143,25 W 48.64 S 173.45 W 58,95 S 205,20 W 67,82 S 239,48 W 77,22 S 278.63 W 90,54 S 322,22 W 107,23 S 369,35 W 127,25 S 420,18 W 152.25 S 472,57 W 181,17 S 524,75 W 213,96 S 576,22 W 250,11 S 626,90 W 287e10 S 677,81W 324,52 S 730.27 W 361.02 $ 784.39 W DOG LEG SEVERITY SECTION DEG/iOOFT DISTANCE 0,269 2,49 1,000 2,12 0.250 1.86 0,250 0.95 1.000 -0.55 1.401 2.12 2,502 8.14 2,000 17,77 1.702 22.53 2.642 30,39 1,466 47.86 2,264 68,13 1,512 91.63 2.015 1!8,04 1,761 147.72 1.327 180.02 0.668 213,39 2.597 248.75 3.544 288.90 2.514 384,45 3,878 438,97 1.996 496.49 1,449 555,01 2.038 614.04 1,076 673,34 0.000 733,13 2.292 794.52 1,303 857,20 ARCO DS 4-13 GYROSCOPIC SURVEY RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC CONPUTER DEC 06, 1978 TRUE HEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M S 5400 40 0 5140.07 5076.07 $56.00W 5500 41 45 5215.68 5151.68 $54.00W 5600 42 0 5290,14 5226,14 S54,00W 5700 42 45 53'64,01 5300,01 $56.00W 5800 43 0 5437,30 5373,30 557,00W 5900 43 30 5510,14 5446,14 $58,00W 6000 44 45 558!,92 5517,92 $58,00W · 6100 44 fO 5653,39 5589,39 558,00W 6200 44 30 5725,02 5661,02 S56,00W 6300 43 45 5796.81 5732,81 S61,OOW 6400 45 0 5868,28 5804.28 $60.OOW 6500 44 15 5939,45 5875,45 $60,00W 6600 44 15 6011,08 5947,08 S61,OOW 6700 44 30 6082.56 6018,56 559,00W 6800 45 30 6153,27 6089,27 $62.00W 6900 45 30 6223.36 6159.36 $62,00W 7000 45 0 6293,76 6229,76 S61,OOW 396,59 $ 838,13 W 434,12 S 891.73 W 473.35 S 945,73 W 512,01 S 1000,93 W 549.56 S 1057,67 W 586,38 S 1115,46 W 623 7 S 1174,50 W 660 3 S 1233,81W 698 3 S 1292,33 W 734 1351,67 W 927,22 S 64 40 37 W 991.79 S 64 2 29 W 1057,58 S 63 24 39 W 1124,29 S 62 54 31W 1191,93 S 62 32 37 W 1260,19 S 62 16 11W 1329.63 S 62 2 47 W 1399,40 S 61 50 39 W 1468,94 S 61 36 52 W 1538.44 S 61 28 25 W 759, .4~i;2,-,iS~],.~irt,~,.~,, 160~,36 S 61 25 52 W 804, 4~(~3~.~i7~.~-..~.~,~...~.~.~... 1678.59 S 61 22 17 W 873,5 59~.,'~.~.~2.~;~)1818,27 S 61 17 7 W 908.40 S 1656,20 W 1888,97 S 61 15 21 W 941,89 S 1719,18 W 1960.29 S 61 16 98 W 975,77 S 1781.59 W 2031.30 S 61 17 25 W 7100 46 0 6363.85 6299,85 S60.OOW 1010,89 S 1843,67 7200 46 30 6433,00 6369,00 560.00W 1047,01 S 1906,22 7300 47 0 6501.52 6437,52 $58,00W 1084,52 S 1968,65 7400 48 0 6569,08 6505,08 S57,00W 1i24,14 S 2030,83 7500 46 30 6636,96 6572.96 S67,00W 1158,57 S 2095,59 7600 42 15 6708,42 6644,42 S74.00W 1181,89 S 2161,46 7700 42 15 6782,44 6718,44 S72.00W 1201,55 S 2225,75 7800 43 15 6855.87 6791.87 S72,00W 1222,52 $ 2290,31 7900 45 15 6927,50 6863,50 S73'.00W 1243,50 S 2356,85 8000 45 30 6997,75 6933,75 572.00W 1264,91S 2424,73 8100 45 0 7068,15 7004,15 S75,00W 1285,07 S 2492,82 8200 45 0 7138,86 7074.86 S77,00W 1302,19 S 2551.42 2102.62 S 61 15 49 W 2174,84 S 61 13 18 W 2247,62 S 61 8 59 W 2321,20 S 61 2 2 W 2394,53 S 61 3 48 W 2463.49 S 61 19 47 W 2529,~7 S 61 38 16 W 2596.17 S 61 54 26 W 2664.78 S 62 10 59 W 2734,83 S 62 27 1 W 2804.56 S 62 43 42 W 2873.42 S 63 ~ 7 W DOG LEG SEVERITY DEG/IOOFT 0,483 1,~62 0.250 1,188 0,528 0,689 1,250 0.750 1.102 2,506 1.346 0.750 0,698 1,014 1,825 0,000 0.707 1,126 0,500 1.181 1,142 5,471 5,299 1.345 1,000 2,063 0.567 1,581 1,414 SECTION DISTANCE 919.24 981.7. 1045,16 1109,54 1175.04 1241.31 1308,80 1376.60 1443,94 1511,56 1580,04 1648.69 1717,02 1785,37 1854.61 1924,81 1994,59 2064.4~ 2135,02 2205,94 2277.25 2349,43 2419,28 2486,50 2554,38 2624,16 2695,33 2766,32 2836,87 ARCO DS 4-13 GYROSCOPIC SURVEY RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER DEC 06, 1978 TRUE MEA$, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES CLOSURES DISTANCE ANGLE D hl S DOG LEG SEVERITY DEG/100FT 8300 45 0 7209,57 7145,57 S79,00W 1316,88 $ 26~0,58 W 8400 45 15 7280,12 7216,12 578,00W 1331,01 S 2700.03 W 8500 45 45 7350,22 7286,22 S79,00W 1345,23 S 2769,92 W 8600 44 45 7420,62 7356,62 $79,00W 1358,78 $ 2839,63 W 8700 44 45 7491,63 7427,63 $81,00W 1371,00 S 2908,96 W 8800 44 30 7562,81 7498,81 SSO,OOW 1382,60 S 2978,24 W 8900 44 0 7634,44 7570,44 SSi,OOW 1394 1 $ 3047.06 W 2941,80 S 63 24 26 W 1,414 3010,27 S 63 45 30 W 0,563 3079,30 S 64 5 46 W 0,716 3147,98 $ 64 25 42 W 1,000 3215,85 S 64 45 54 W ' 1,408 3283,52 S 65 5 51 W 0,551 3350,84 S 65 24 52 W 0,695 9000 43 15 7706,82 7642,82 584,00W 1403 2 S 3115,46 W .3416,84 5 65 45 15 W 9100 43 0 7779,81 7715,81 585,00W 1409 7 S 3183,50 W 3481,65 5 66 6 57 W 9200 43 0 7852,94 7788,94 $85,00W 1415 3251,44 W 3546,24 5 66 28 21W 9300 42 0 7926,67 7862,67 S87,00W 1420 ~3~i~i~i~~1tC 3609,98 S 66 49 ~1W Z ' 9400 42 0 8000,99 7936,99 $86.00W 1424, ~,~,~i~..,,~t~ ....~673,06 S 67 10 56 W 9500 40 45 8076,02 8012,02 586.00W 1429, ~1'"~5~+~;~ 3735,69 5 67 30 33 W 9600 40 45 8151,78 8087,78 58B,OOW 1432,4: ~51.~:~1N:.~%.~3797,28 $ 67 50 16 W 9700'41 0 8227,39 8163,39 589,00W 1434,15 5 3582,16 W 9800 41 30 8302,58 8238,58 S86,00W 1437,03 S 3648,02 W 9900 41 45 8377,33 8313,33 S88,00W 1440,50 S 3714,35 W 10000 41 0 8452,37 8388,37 $89,00W 1442,23 S 9780.43 W 10100 42 30 8526,97 8462,97 NBg,00W 1442,23 5 3847,01 W 10200 43 0 8600,40 8536,40 NB7eOOW 1439,86 S 3914,84 W 10300 46 15 8671,57 8607~57 N86.00W 1435,58 S 398~.95 W 10400 45 0 8741,50 8677,50 ~86,00W 1430,59 S 4056,25 W 10500 45 30 8811,90 8747,90 N85,00W 1425,02 S 4127,05 W 10600 4~ 15 8882,77 8818,77 N85.00W 1418,87 S 4197,34 W 10700 44 0 8954,55 8890,55 N84,OOW 1412,20 5 4266,64 W 10780 43 30 9012,34 8948,34 N84,00W 1406,41 S 4321,65 W 10845 43 30 9059,49 8995,49 N84,00W 1401,74 5 4366,15 W D858.58 S 68 10 50 W 3920,86 5 68 29 58 W 3983,90 5 68 48 9 W 4046,19 5 69 7 5 W 4108,47 S 69 26 56 W 4171,24 S 69 48 23 W 4235,65 S 70 11 18 W 4301,14 S 70 34 22 W 4366,15 S 70 57 2 W 4430,67 5 71 19 21 W 4494,27 S 71 41 10 W 4544,75 S 71 58 Z3 W 4585,65 S 72 12 3 W 1'596 0,528 0,000 1,342 0,669 1,250 1,305 0,498 1,409 0,921 0,865 1,756 1,056 3,292 1,250 0,713 1,250 0,543 0,625 0,000 SECTION DISTANCE 2907,21 2977,6 3048,54 3119,06 ~188,81 ~258,32 3327,37 3395,24 3462,03 3528~53 3594,14 3658,98 3723,17 3786,28 38~9,09 3912,68 3976,89 4040,34 4103,7~ 4167,60 4233,03 4299,40 4365,11 44~0,15 4544,71 4585,65 BOTTOM HOLE CLOSURE 4585,65 FEET AT S 72 12 3 W ARCO DS 4-13 CODE NAME GYROSCOPIC SURVEY INTERPOLATED TRUE VERTICAL DEPTHS~ COORDINATES AND CLOSURES FOR GIVEN DEPTHS · TRUE MEASURED VERTICAL TOTAL COORDINATES C L 0 $ U R E DEPTH DEPTH DISTANCE ANGLE D M S DEC 06, 1978 SUB SEA TOP SAD 10095 8523.28 BASE SAD 10762 8999.29 TD 10845 9059.49 1442,'29 S 3843,63 1407.71 S 4309,32 1401.74 S. 4366.15 4105.33 S 69 25 54 W 8459.28 4533.42 S 71 54 34 W 8935.29 4585.65 S 72 12 3 W 8995,49 ARCO DS 4-13 GYROSCOPIC SURVEY MEASURED. DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF 5U8 SEA DEPTH, DEC 06 ~ 1978 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 164 164. 100 0 0 0.00 264 264. 200 0 0 0.00 364 364. 300 0 0 0.00 464 464. 400 0 0 0.00 564 564, 500 0 0 0.00 664 664. 600 0 0 0.00 754 764. 700 0 0 0.26 N 864 864. 800 0 0 1.36 N 964 964. 900 0 0 2,02 N 1064 1064, 1000 0 ~ 0 2,08 N 1164 1164. 1100 0 ~ 0 2.08 N 1264 1264. 1200 0 0 2.08 N 1364 1364. 1300 0 2.08 N 1464 1464. 1400 0 ~i]'~ ~¢iti~[~)~tt~il~ 2.08 N 1664 1664. 1600 0 2.03 N 1764 1764. 1700 o ~<6~~ C©~©~2.19 N 1864 1864, 1800 0 0 2.19 N 1964 1964, 1900 0 0 2.37 N 2064 2064. 2000 0 0 2,96 N 2164 2164, 2100 0 0 3,38 N 2264 2264, 2200 0 0 4,28 N 2364 2364, 2300 0 0 1,61N 2464 2464. 2400 0 0 1,74 5 2564 2564. 2500 0 0 4,90 2664 2664, 2600 0 0 7,15 2764 2764, 2700 0 0 9.18 S 2864 2864. 2800 0 0 10.98 S 2964 2964. 2900 0 0 14.36 S 3065 3064. 3000 0 0 12.38 3165 3164. 3100 1 1 8.41S 3266 3264, 3200 2 1 0.82 3367 3364, 3300 3 1 12.00 N 3469 3464, 3400 4 1 9,62 N 3571 3564, 3500 6 2 0,40 N 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0,01 E 0.26 ~ 0.55 E 0.53 E 0,53 E 0,53 E 0,53 E 0,53 E 0.66 E 1,15 E 1,14 E 1.14 E 1,17 E 0,90 E 0.96 E 0,37 W 1,30 W 2.16 W 0,63 W 0,12 E 1,57 E 3.40 E 4.17 E 1.86 W 12.07 W 23,45 W 30.85 W 47.45 W 65.05 W ARCO DS 4-13 GYR~3SCOPIC SURVEY HEASURED. DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, DEC 06~ 1978 TRUE MEASURED VERTICAL SUB ND-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 3674 3777 3882 3987 4093 4200 4310 4423 4539 4660 4785 4911 5039 5168 5300 5431 5565 5700 5836 5975 6115 6254 6394 6534 6674 6815 6958 7100 7245 7392 7539 7675 7811 7952 8094 3664, 3600 9 3764, 3700 13 3864, 3800 17 3964, 3900 23 4064. 4000 29 4164. 4100 36 4264~ 4200 45 4364. 4300 58 4464, 4400 75 4564, 4500 96 4664, 4600 120 4764. 4700 146 4864, 4800 175 4964, 4900 204 5064, 5000 236 5164, 5100 267 5264, 5200 300 5364, 5300 335 5464, 5400 372 5564. 5500 410 5664... 5600 450 5764, 5700 490 5864, 5800 529 5964, 5900 570 6064, 6000 609 6164. 5100 651 6264, 6200 694 5364, 6300 736 6464, 6400 781 6564, 6500 828 6664. 6600 875 6764, 6700 911 6864. 6800 947 6964. 6900 987 7064, 7000 1030 3 9,97 4 22,14 4 34,81 6 47,20 6 58,26 7 67.82 9 78,32 13 94.14 17 114.50 ! 21 141,64 24 176,56 26 217,82 ~. 264,53 407.89 35 512.00 37 562.89 38 613,97 40 665,79 40 718.67 39 767.02 41 816,06 39 804.28 42 913,42 43 961,38 42 1010.89 45 1063,59 47 1120.91 47 1168,79 36 1196,42 36 122~.85 40 1254.45 43 1283.97 86.29 W' 110,16 W 138,05 W 169,38 W 202.96 W 239,48 W 282,70 W 332,59 W 388.69 W 451,72 W 516,72 W 581.72 W 646,75 W 713,16 W 784.39 W 854,68 W 926.71 W 1000.92 W 1078.34 W 1159.62 W 12~2.49 W 1324,08 W 1408,86 W 1493,95 W 1579.01 W 1665,65 W 1755.40 W 1843.67 W 1934,42 W 2025,85 W 2121,31 W 2209,74 W 2297.49 W 2392.09 W 2488.72 W ARCO DS GYROSCOPIC SURVEY MEASURED. DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, DEC 08, 1978 TRUE MEASURED VERTICAL SUB MD-TVD 'VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORD [NATES 8235 7164. 7100 1071 8977 7264, 7200 1113 8519 7364. 7300 1155 8661 746#, 7400 1197 8801 7564, 7500 1237 8941 7~64, 7600 1277 9078 7764, 7700 1314 9215 7864, 7800 1351 9350 7964, 7900 1386 9484 80&4, 8000 1420 9616 81~, 8100 1452 9748 8264, 8200 1484 9882 8~64, 8300 1518 0015 846~, 8400 1551 0150 8564, 8500 1586 0289 8664. 8600 1625 0432 8764, 8700 1667 0574 8864. 880.0 1710 0713 896~. 8900 1749 41 1307.60 42 1327,65 42 1347.82 42 1366,52 40 1382,72 37 1408.33 37 1416.48 32 1432,79 32 1435.10 1440,05 " ..........1436,12 43 1~20, ~7 39 14tl,25 2585.57 W 2684.05 W 2783.26 W 2881.87 W 2978.93 W 3075.15 W 3168,55 W 3261.68 W 3352,23 W 3441.17 W 3527,18 W 3613,71 W 3702.38 W 3790,29 W 3880.86 W 3977,05 W 4078.75 W 4179,01 W 4275,61 W ARCO DS 4-1,$ GYROSCOPIC SURVEY NTERPOLATED VALUES FOR EVEN 1000 FEET OF MEA,SURED DEPTH, TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999. 935.' 2000 1999. 1935, 3000 2999. 2935. 4000 3975, 3911, 5000 4833. 4769. 6000 5581, 5517, 7000 6293. 6229, 8000 6997, 6933, 9000 7706. 7642, !0000 8452, 8388. - 2.08 N 0,53 E 2,61 N 1,25 E 14,59 S 2,45 E 48,64 S ._173.45 W 250,11 S / 626.90 W 623,27 S 1174.50 W 975.77 S 1781.59 W 1264.91 S 2424.73 W 1403.12 S 3i15.46 W 1442.23 S 3780,43 W DEC 06, 1978 ; · ............. ............ ~ .......... ........... .................... ....... ~ . ~~~ .. ~-- ....................... ............ !; ...................................... ~ T"~, ........... ~ ............. ~i - '~ ...... T''~'-~''~''~-~. ~ ' . t ..... ~ ........ . , ~ .... ~~l ' ~ ........... ~ ......... ~. .................. : ...... ~ ................................ ",NOI~Si~D]~A7 ~-~ _~ - ~' ' . AtlanticRic~ hfieldCompany North Ameri~.r~ Producing Division North Alask; ~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 7, 1978 Mr. Hoyle Ho Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 4-13 Permit No. 78-31 Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure Form No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield COmpany 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Alaska 99510 4. LOCATION OF WELL 33'N & 441'E of SW cr Sec. 26, TllN, R15E, UM 5. AP! NUMERICAL CODE 50-029-20305 6. LEASE DESIGNATION AND SERIAL NO. ADL 28325 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 4-13 10~ FIEL~ AND P~OL, ORo.~IL~C~T ~ruclnoe ~a}{ ~&8t~ Frudnoe 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 34, 1'11~, R15[, UM 12. PERMIT NO. 78-31 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for the Month of March, 1978 Spudded well @ 1600 hrs 3/26/78. Drld 17-1/2" hole to 2710'. RU & ran 13-3/8" csg w/shoe @ 2692'. Cmtd w/6400 sx Arcticset II cmt. Installed & tstd pkoff. Drld shoe & 10' new form. Tstd to 12.1 ppg. Drld 12-1/4" to 3655' as of March 31, 1978. 14. l hereby ¢~~or~.g is~ Di stri ct Drill ing Enginee~ATE SIGNED · ~ ~ ~' ~ TITLE ' 4/6/78 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. DEt:'~ OF ~I~~ P~~C~ Di~c~% ?f Oil and Gas Cc~servation O. K. Girth, J~%.~ --~-'~! April 3, 1978 Di~~ Hoyle H. H~l~n . ~~1~ ~~r BOPE Tests - ArGo's DS 4-13 ~sda~- I departed my hc~e at 8:30 AM for a 9:00 AM ~-~-' 10:00 AM departure via Wien flight $9 for Deadhorse. a n~l real--on dela_~d our departure until 11:00 AM and I arri%~d in Deadhorse at 12:30 PM. I proceeded to Drill Site %4 where nipp!~ng up was in progress. Aroo drilling foreman was George Bean and ~c~an rig $34 toolpusher was Jim Weath~_rl_¥. I received a call frcm our Anc~e offioe later in the afternoc~ advising no drill/rig pexmit had be~-n issued for %,m_ll 4-13. Exact spud time of the well was devel~ ~ later called to Hoyle Hamilton in Anchorage. Wednesday, March 2.9, 1978 - Tests began at 4:00 AM with shoe on 13 3/8" at--~.---~ssuri~ ~ accusing, wi~h two stage Koc~ey pu~p and diesel. Annular pre~enter tested to 3000 psig. ~ile att~g to t~st the top pipe rams the flange c~ the check valve in the kill 1/ne leaked. This was repaired and upper and lcwer pipe rahs, both wing valves on the choke 1/ne, and both wing valves and check valve in the k~ll line tested to 5000 psig. Thirteen valves and t~anty-s~ flanges in the choke manifold tested to 5000 psig. The manual adjustable choke was free moving and the Swaco super- ~ actuated both ~lly open and fully closed. Both dart and ball type floor valves %re_re in plaoe. ~ nippling up test adaptor on lower kelly valve I toured the locatim which was w~ll organized, reser~ pit well built, rig in good repair, but ~ well sign had not been received. A~ator p~sure was 3000 psig. N2 backup bottles tested 2500, 2300, 2100, and 2600 psig. Kelly cock and lc~r kelly valve then tested to 5000 psig and tests ~ cc~cl~ at 8:15 AM. A field inspection report was prepared with a copy given to ~3e Be~n, a copy mailed to Bob Hines and the origir~ ! attached to this report. I then proceeded to Drill Site. %5 for upcoming BOPE tests, the sub~3t of a separate report. ~___~sday,~__~arch 30, 1978 - On ~uty at DS 5-17. ~-----~-~-:~5 ~ ~a ~ien flight $20 arriving in .Anchorage at 11:05 and at my. hcm~ at 11:45 PM. In s~: I witnessed successful BOPE tests on Arco's DS 4-13. Attachment Drlg. Permit No. Opera Satisfactory Type Inspection Yes No Item (~N'~Location,General () (~- ( (~( (~( () ( () ( ( ( ( ( ( ( () ( () lo Well Sign 2. General Housekeepin.Q ~,. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W __,___,___, . 10. Gr. Bbls., , , ( ) Final Abandonment ll. P&A Marker Ala J Oil and Gas Conservation Commi~ e Field Inspection Report ~'- ~-q~.~ We 11/~ S e c~_T_/._~..~.F__R_/_J~__~--, _t~_~! Represented b ..... . Y__~~A.~ Name & Number ~,~' S~ s~ctovy Type inspection Yes Na ~em [~OPE Tests ?~u r~u~d-( )w~' ~mud 16 17 Master Hyd. Control Sys.-..~_~_.o_F..~sig 18 ~'!2 btls~,i.~m~.~/_~,~..psig 19 Remote Controls 20 Drilling spool- .~ "outlets 21 Kill Line-(~Check valve 22 Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs/.~flgs=~ 24 Chokes-(~emote( )Pos.(~$~j. 25 Test Pluo-(~ellhd( )csq( )none 26 Annular Preventer,~sim 27 B1 ind Rams.,~~sim 28 ( ( ) 12. Water well-( )capped( )plugged (~-)~ ( ) 29 ( ( ) 13. Clean-up (~ ( ) 30 ( ( ) 14.. Pad leveled (~x.- ( ) 31 Total inspection observation time ...,~f hrs/~tl=~ Total number Remarks P i pe Rams _=*:~ ps i q Kelly & Kei~S~-ock~o~..~..,,psig Lower Kelly valve Safety Floor valve~-2-~ (-~7Dart eaks and/or equip, failures .... cc: _~~ ~_~.~Notify in days or when ready Ins pec ted byj[]. ~~,~_~__xDa te_~.~.]_~...~_'../,_:_ ~ Howard A. Slack, Vice President & Resident Manager Atlantic Richfield Company P.O. Box 360 Anchorage, Alaska 99510 April 3, 1978 Dear Mr. Slack: The Department of Natural Resources, Division of Oil and Gas Conservation, has reported that there has been a violation of 11 AAC'22.005 which requires that an opera- tor of an oil and gas well secure a drilling permit prior to drilling or deepening of any well. Atlantic Richfield Company spudded and started drilling on Well DS4, Number in the Prudhoe Bay field without a permit. The operator k commenced drilling approximately three days before a permit was issued by the Oil and Gas Conservation Committee. Alt though we are convinced that the infraction was not inten- tional, this is the second time that ARCO has violated 11 AAC 22.005 and the Oil and Gas Conservation Committee has recommended that action be initiated to collect a fine from ARCO pursuant to AS 31.05.150. That provision pro- vides that a person who willfully violates a provision of AS 31.05 is subject to a penalty of not more than $1,000.00 for each act of violation and for each day that the viola- tion continues. The Oil and Gas Conservation Committee has recom- mended that efforts be made to collect the penalty from you equivalent to about 25% of the maximum penalty.to which ARCO could be subjected for willful violation. In this case, the well operations were carried on for approximately two days and 17 hours. A $1,000.00 per day penalty rate would equal approximately $2,710.00. A 25% penalty would amount to $678.00 which the Committee has rounded off to $700.00. The Oil and Gas Conservation Committee is willing to accept $700.00 from ARCO in this matter as full penalty payment if ARCO gives assurance that they will inaugura~-~ .~..i-.ii procedures to prevent similar occurrences from happenin~ again. Mr. Howard A. Slack -2- April 3, 1978 Although the Oil and Gas Conservation Committee is convinced that the infraction was not intentional, this is the second time that it has happened despite a MarCh 10, 1976 communication from you indicating that necessary steps were taken to revamp ARCO's procedure to assure that simi- lar occurrences would not happen again. If I may be of any assistance in this matter please do not hesitate to contact me. Should you decide to pay the penalty of $700.00, payment should be made through this office and any checks submitted should be made out to the State of Alaska. Once again, please do not hesitate to contact me if you have any questions about this matter. Very truly yours, ATTORneY GENERAL ./ / /' Jeffrey B. Lowenfels Assistan~ Attorney General ~ ~ .,' JBL:tb cc: O. K. Gilbreath, Jr., Director Alaska State Division of Oil and Gas 3001 Porcupine Anchorage, Alaska 99501 Fred Boness, Deputy Commissioner Department of Natural Resources Pouch M Juneau, Alaska 99811 FILES DEPAR524~qT GF ~ RESOtSRf~S Divisic~ of Oil and Gas Comservation 30, 1978 AROO Well DS4-13 Spudded Withc~ Pezmit Ben Le Norman called frc~ Prudhoe Bay at 9:15AM today. He reported that well DS 4-13 was spudded at 4:30 PM Sunday 03/26/78. The dril]_~ng permit was approved fo~ the w~ll at 9:30 AM Wednesday 03/29/78. Calculation of possible penalty for drilling without a peanut. 4:30 PM 03/26/78 to 9:30 AM 03/29/78 = 2 days 17 hours or 2.71 days. Max Penalty = 2.71 days X $1,000.00/day = $2,710.00. .25 X $2,710.00 = $678.00 or app~te!¥ $ 700.00. March 29, 1978 ~ Bay L~it DS 4-13 Atlantic Richfield ~y Pe~t No. 78-31 P. O. Box 360 Anchorage, Alaska 99510 Enclosed is the app~ application for ~rmit to drill the a~ove ref~ well at a location in Section 34, Tcmal~hip llN, Range.. 1SE, ~F{. ~11 samples, core chips and a m~l log are not re~_ ~ired. ~urvey is requLred. A directicnal Many ri-~rs ~ Aia~ca and their ~naoe sy.sq~s have been classified jar~~nt for ~ spa~ing or migration of an~ fish. q?eratic~s in ~se ~as are ~bjec~ to ~ 16.50.870 and t~he _regulations prc~gat~ tt~reur~r (Title 5, ~~ ~istrative Code). Prior to ~cing operations you ~y be oontacteO by rtz ~{abitat Coord'mator's office, Depar~--nt of Fish ~ ~. Pollution of ~ny ~ters of ~ State is prohibited by k~ 46, C~apter 03, ~icle 7 and ~ formations prcmulgated thereunder (Title 18, Atas~ Adrcdnistrative ~, C~apte~r 70) and ~ th~ Federal Water Pollution Control ~t, as ~. Prior to ~ing operatioru~ ~ may be. ccmtac~ ~ a representative of the De~t of Envir~tal Conse~a~on. tktrs~t to ~ 38.40, ~1 }Lire Under St_ate Le~ses, ~ Alaska De..~~t of Labor is ~ing notified of the issuance of this ~m~t to drill. To ~ ~ in ~dul~g fielO work, %~ w~_ld appreciate your notifying t2~is office wit~ 48 ~ after ~ ~11 is spudded. ~ %o~d also like to be notified so that a representative of the D~3;ision may be ?resent to ~,~tness t~sting of bl~t preventer .~equi~t before ~arface casing shoe is drilled.. F. M. Brc~a~ P. B. Unit ~ 4-13 2- March 29, 1978 In the e~nt of suspensic~ ~r aband0~z~nt please give this office adequate advanoe ~ficatic~ so that w~ my have a witness present. Encl~ ~ of Fish and Gains, Habitat Sectic~ w/o encl. Department of En~tal C~ervatic~ w/o encl. De~t of ~, Supezvisc~, Labor Law Ccmpliance Divisicn w/o ~ncl. AtlanticRiclT~ieldCompany -~ North Americ~ Producing Division North Aiask[ .~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 15, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 4-13 Dear Sir: Enclosed herewith is our Application for Permit to Drill DS 4-13, a $100.00 filing fee and the required survey plat. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure Form 10-401 REV. 1-1-71 SUBMIT IN TR ATE (Other instruct. , on reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMiTTiEE~... L ii..~ L,it : ~i; i~ ) la. TYPE OF WORK DRILL [~ b. TYPE OF WELL OIL FX] GAS []] WELL WELL OTHER 2. NAME OF OPE~TOR gtlant~c R~chfield Company PERMIT TO DRILL OR DEEPEN DEEPEN ~ 3. ADDRESS OF OPERATOR P.O. Box 360; ^nchorage, ^K 99510 4. LOCATION OF WELL At surface 33'N & 441'E of SW cr Sec. 26, TllN, R15E, UM At proposed prod. zone 1345'.S & 1400'E of. NW cr Sec.. 34,.TllN, R15E,.UM 13. DISTANCE IN bIILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 6 miles NE of Deadhorse, Alaska 14: BOND INFORMATION: API No. 50-029-20305 6. LEASE DESIGNATION AND SERIAL NO. ADL 28325 7. lF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME __Prudhoe Bay Unit 9. ~LL NO. DS 4-13 10. I~ELD ,,~D POOl.OR WI~DCA'I~ vruclnoe uav r 1 el d Prudhoe Oi~ Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, TllN, R15E, UM 12. ~F~ Statewidesuretya,~/otNo. Federal Insurance Co.. #8011-38-40 A.,o,,t $100,000 15. 2I. DISTANCE FRObl PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. ELEVATIONS (Show whether DF, RT, CR, etc.) Pad Level - 30' RKB - 64' 1345' 16. No. OF ACRES IN LEASE 2560 ~ 19. PROPOSED DEPTH * 10654' MD 2560' 23. PROPOSED CASING AND CEMENTING PROGRAM 17. NO,ACRES ASSIGNED TO Tills WELL 160 ' 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START April 1, 1978 SIZE OF ttOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEFI'It Quantity or' cement 32" 20" 94 lb. H-40 80' 250 sx PF II to surf 17,1/2" 13-3/8".. 72 lb. MN-80 2700'MD Circ to gurf-approx 5'500 sx 12-...1/4" . 9-5/8" 47 lb. 80&95 10654'MD 2600'+ c'mt column on 1st st9 .approx 1500'.sx) plus 300'+'col.~m.n _ on 2nd stg (approx 300 sx) Atlantic Richfield Company }reposes to directionally drill this well to 10,654'MD, 8930'TVD to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be used. It will be pressure tested each week and operationally tested each trip. A string of 5-1/2" 17// N-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A non-freezing liquid will be left in all uncemented annuli within the permafrost interval. Selected intervals' within the Sadlerochit interval will be perforated, and reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. Well will be flowed to production facilities during perforating and testing. The downhole safety valve will be installed upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on. present productive zone and proposed new productive zone. If proposal is to drill or deepen directionMly, give pertinent data on subsurface locations and measured and Uue vertical depths. Give blowout preventer p~o~am. SIGNED~'/~ ~'' ~ ~'''~m~ ~ ~'~24' I hereby g,~{~' that the Foregoing ~~.7~t~, DA~ Harch 15, 1978 _ TiTLEDistrict Drlg. Eng~ (This space for State office use) [SAMPLES AND CORE CHIPS REQUIRED [] YES g~ No DIRECq'IONAL SURVEY REQUIRED ~.YES [] NO CONDITIONS OF APPROVAL, IF ANY: MUD LO(; [] YES ~] NO OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE 50-029-20305 PERMIT NO. APPOVED BY 78-31 APPROVALDATE · TITLE Chairman *See Instruction On Reverse Side ~arch 29, 1978 DATE M_arch 29, 1978 SECTION 35 J ,g ! -0 i ~'~ · i . , L:t~E : , 47G4' t,, , :/ / ,' .,/ · ! ...... ~.~-~ .... ~ ~..~ ~ ~_, ~',~,~ I ~,~ ..,~ ..... ~ an~ ,.~ P~-tCT~C~ L~;'~D SURVEY!NS ~N THE ;:~ ,_u,~ ;ON SURVEY :~,..,~_"~"~ ~"~, ~,~_',~ m~ UNOER..,. MY DIRECT ~.R"~ CORRECT. JANUARY S, ~9'/7 .... ~-~ C -~' 'E S UR~ E YOR {;A"'~ OF SURV~'Y t ~,;x'-t , //0. 11 ,'i.:] 77 70 ~ ,.'..f<, ' Y_o. Lc',u~. ,'48~/~,'~I Z34" ' ,'v .... L ,VO. 12 ,'P..,,'F. To* /6' I.~ . 931" lz;2,~;. /~8~/~' l.::~. 5/Z" t'~%~/ t A~ x'F F:_ ~. ~_ / V O. /.:) " ,'~ 17 ./7~ ,,_4r ;v o ..... ?qSL L NO. tS ,.. i /_A;C 7,2' /~' /.~ .625' ! .,- ~,v6. /48°/~' 29. 049" WELt /,10 t5 ... LAT. 70 ' /~' '/..5' .470" ~.~/G. /48 °/~ .38..327 t ,,/,-, ~ NO. t6' LA/7 70~ It3 '/4 . i ~o#~. ~48 "' I(= '27.602" x. $. R C., z'o,vE//o. ,4 '/ ~ 957 /50.26 ,~ 713 Zl3.57 7' 5' 952 o~3. 57 / 7z3 Z4t. G8 951 9/7. t~ 713 Z70. OI / .3' 9~1 800.~9 X 713 298.55 . 951 ~,8~. 98 7t5 ..326 7' W 951 56,7. IZ X 713 354.91 AS - 3UiLT E, , .,R~LL SITE Bio. 4 '"'"LLS,~F_ I I THRU t6 LOCATED IN P~OTNACT~D SECTIONS 26~ 35, 'TdN~RISE, U M, ...,,,,. LOUNSBURY/AND AooOC.'A~ 723 W, 6th AVE., ANCHORAGE~ALASKA ! ! CHXD. BY G. O. j F!£LD BK. l. Is the permit fee attached ..... Yes !io Remarks ...... /~z~;,( 2. Is ;.,'ell to be Ic-atei in a defined pool 3. Is a registered s":'vey plat attached 4 Ls ',.:el 1 ~c',-~-= ' ~= .. , _~_'_a src$er distance f'r'om prope~ wy line 5 is ;.,'ell ls,;,-:ted ".-~;--r distarce from other wells Is suffic:ent unleclicated acreage available in this pool 7 Is ,..,'ell to be de' iated . 8 Is ope~ator ti~e cniv a, ,~u~=d party 9 Can permit be a?~:-oved before ten-day v;ait . lO Does operator have a bond in force ' " . - 11 Is a conservation o'rder needed ....... i~ ,~ ministrative approval needed 13. Is conductor string provided ............ 14. Is enouqh cement used to circulate on conductor and surface . ,,. 15. Will cement tie in surface and intermediate or production strings 16. Will cement cove? ail known productive horizons .' . 17, Will surface cas:ng protect fresh water zones 18. Will.all casing give adequate safety in collapse, tension & burst 19, Does BOPE have sufficient pressure rating - Test to ~OoO 20, Has DMEI'i approved Plan of .Operation ....... Additional Recu'irements' ps io Approval Recommended- Geoloq}(.: Enaineering: Revised 11/17/76 Well Histo.ry 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" i ' .. organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO ALASKA, INC. Well D.S. 4-13 Field PRUDHOE BAY County, State N. SLOPE, ALASKA Date 10-31-82 *** Casing Collar Locat°r Corrected As Per Log*** Curve Name (Abbrev.) Standard Curve Name Logs Used Scale , ,, LSN1 Long Spaced Neutron Pass 1 CN/MS 0 - 1250 SSN1 Short " " " 1 " 0 - 1000 ,, CN1 Compensated Neutron " 1 " 60 - 0 GR1 Gamma Ray " 1 " 0-100, 100-200 CCL1 Casing Collar~Locator" 1 " 0 - 1 LSN2 Long Spaced Neutron " 2 " 0 - 1250 , , SSN2 Short " " " 2 " 0 - 1000 CN2 Compensated Neutron " 2 " 60 - 0 GR2 Gamma Ray " 2 " 0-100, 100-200 CCL2 Casing Collar Locator" 2 " 0 - 1 ,,, , ~ ~ PASS 1 PASS 2 N~~ NEUTR~B NEUTRON ~oo~o. ~s o. ~vs. -~n. ~. o. ~.~o z.oo ~.~-~o 10030. 121.2 ..... 0 0080 100~0 10100. 10110 1.0120. 27 29.16 .10150. 22.0 25.5 712, 556. 585. 708. 26,85 27.9¢, o_an .... n_an_ lOlt+ 27.9 7_Q.6 . 578. 53q-. 672. 30-5~ 3!,55 0 = 8~~- . 10150. 23.7 2~.6 756. 599, 607, 7~7, ~6.93 10160. 2q.1 28.1 847. 678, 679, 867, 2~.99 25.0~ 0-8.0 10170. 19.7 20.8 82~. 666, 6~6. 825. 2~.99 26.17 0-8o . O_Sn 10~80, 22.8 23.6 753. 58~. 6~5. 787. 26.q9 10190. ~,.~0 ~5.8 591, 459, 504. 618. 29.09 29.06 ri.an ........... ...?-~ ~{.~....?~ .................. 1, 02.00 .~~ ...~,~,.,.,,.~. 607... ~EZ,7, q~6. 58fi. 33.59 PAGE 2 ARCO ALASKA INC, PASS__I_ PASS 2 NEUTRON NFUTRON NFUTRON ......... 1. 0250~ .......... 21.1 2~.3 866. 69O, ~52, 02~ .... 22.0 0320, 19. ~ 21.0 76 ~.0350 10360 ~0370, 20 53.30 ............... !~ 0 :~.90.,~.~__1._,_~.0. ...... ~,~. .... 7_%. ~..~...7 ..... ............... ~.~, ~,~.~ ........ ~ ~ ~,~ I 0~10. 19.~ ~9 576. ~9~ ~0. 570. 35.~5 32.51 ~.0~20. ~ ~.6 ~8. 50Z~ ~68. 58z. ~s...85 ~5.5~ o.an _O_.~O .... ~:~::;?:;~::~;:::~::~s'~;;:';::L:':;:s;::s:::s':'}:::~:: ~:}'~ ~;. ===============================~j~,~]~.~.~.[,::t: ~i:. :::-;:~ ~:';:":::::~:~:s:: '::;';..; :;;:'~;s ;~c:'x':::.c:.::~,:~_~. ~.:. *? ..:~:s:;;.;;*;:::..~;:::.~i ;:' ".; ;::: :::$s~ :~:.:~.~....;::~:s":'~s;: .::-~¢:~;::: .;:.~:;. ::;:t::~ -: [~ ;L~~~;.~~,~.~....~_~.j.;_,.~[...__,:~_O..~_.. ~ ~.~:.~ .~~_~o..~.n_..._.~.~_. . :::~;~.~.:~: :.~ ~ 25,1!.; ........... :, .:o_-_8.n. .... .~.__ ...;... o.._- :8 o.: . ~;~ 2'.~;~ ~ ~~:.:_:. L2.~!.~_:~.._: .......... o..,..sn ................ ~~_, ._. _.~O.~. ..... ..~. ~ ~506, .......5~.9, ........ ~.E,~7 ~5 ........a.,8~ ........ a-..-~o ........ PAGE 3 PASS i PASS 2 NEUTRON NEUT~~ NEUTRON _ 1050~ 50.8 q9.9 68U~. 561. q'61. 625, 39.55 5.5 . ~_..1__ ..... 0_,_8~-. ......... ~~- 10590 10600, 19 10610 10620. 57 27.99 26,97 N-RrL___&-Rn _ ;[0630. ~0.~ ,39.6 815. Fg50, 7q-3. 871. 19.82 22.80 ]06~0. 5 ~,~.~~ ............... 667, 5~9, 525. 10650. 25.7 25.9 682, 5~5, 523. 651, ~1.36 51,55 10670. ~0,7 ql.8 528. ~20. ~25. ~26. 5q ..25.. 53.75 10680. ~. 2 ~.~p. 5 597 .... ~71, ........ ~87. 578, 50.57. 52.9! 10690, 0.1 0 1 -260, -215, ~2, qO. ~8,06 ,8.00 LIB.KARY TAPE CURVE SPECIFICATIONS Company ARCO ALASKA, INC. Well D.S. 4-13 Field PRUDHOE BAY County, State N. SLOPE, ALASKA Date 4-23-83 Curve Eame (Abbrev.) (THIS TAPE CONTAINS 1 FILE) Standard Curve Name Logs Used CN/MSN Scale 0 - 400 80 - 580 60 - 0 0-100, 100-200 LSN1 SSN1 CN1 GR1 CCL1 LSN2 SSN2 Long Spaced Neutron Pass 1 Short " " " 1 Compensated Neutron " 1 " Gamma Ray " 1 " Casing Collar Locator Long Spaced Neutron " 1 Pass 2 Short " '" " 2 -10 - -5 0 - 400 80 - 58O CN2 Compensated Neutron " 2 " 60 - 0 GR2 Gamma Ray " 2 " 0-100, 100-200 CCL2 Casing Collar Locator " 2 " -10 - -5 CN1 LSi'ql SShll OR]. CCL1 CN2 LSN2 SgN2 GR2 CC1_2 FROiq 10030.00 TO 10702,00 62. SAh'i, PLES PER RECORD PAGE 1 ARCO ALASKA INC. DEPTH GR1 LSN1 SSN1 CNI CeLl GR2 L,SN2 SSN2 CN2 100~50. 122.6 101.1 210.1 .~7.3 It.f) 0.0 0.0 0.0 10032. 122.6 101.1 210.1 37.3 0.~ 0.0 0.0 0.0 '7'""='~7='~ ] ~ Y77''''~:' :"T''~ ':~ ~' F'~: '7 ~"? :;~ ~: ;AF: '~ ?':~;'J :~,'~": =2 ~ ~7~7~ $~ r'77T' ]?~j77 F7 W]~ ~? ~'~?$k~ T~:.L~$2 ':~ T '~TF r'i?: T'-TC '.' ~?~ ~'"'? "~]]' % x:~'''=-:: !' 7-='''''~'''=' '7 '~" ~'i""T'"7-'T '": Y'U 1~0~. 122.6 101.1 210.1 ~7.~ 0.0 1~1.q 101,0 206.5 ~0036. ~22.6 ~0~,~ 210.~ 37,3 0.~ lq~.~ ~0~.0 208.5 1003~. 122.6 101.1 210.1 37.5 O.O 141.4 101.0 205.5 100~0, i33,1 96,2 209,8 ~1.1 0,0 1~1.~ 101.0 ~08.5 100~2. 135.2 97.9 ~10.~ 39.9 O.C 123.2 105.0 212.0 100~4. 125.~ lO0.b 211.3 ~8.1 0.0 122.~ 98.5 .0 P12.9 100~6. 122.9 2.6 L~ 2I-1.~ 40. 10050. 121.3 208.9 10052~ 113.0 .~.~] qO, 10054. 118.8 0.0 ~1.0 210.~ ~9. 97~.<..,-_.,_~...~._~ ........ 9..~...,.,,5 2o 7.2 ~e. 10056, 130.2 97.8 206.6 ~9,3 0.0 132.2 96,q 206,8 38, 10058, 127,9 99,7 207,7 57,~ 0,0 132.9 100,7 205.2 35. 10060. 152.1 102.6 206.9 ~5.0 0.0 130.6 95.9 205.2 39. ....... ~2 ................. ; .......... ~.....~. L......-i.<..:;.....&~nL. ~...:...1......:..: .....; ...... -~22 ..... i..:f.:a.:d:.~.. ~., :........ct.t.....<.~.._._. L L.: .~f.c _1 .:.t.. -..,:.~:~... Z2 ...2.: .......... :~ ... ~ .:~.....; .......... 1........: ....... .* ........ '. :..~-: ..................................................... ~ !0062. !26,3 99,6 205,2 36,6 0.0 11!.2 98,5 20B,q 1006~+. 109,8 102.~ 20~,0 3~,1 0.~ 139,3 100,9 2].1.7 10066, I~5.6 99.8 211,2 ~5q.7 0.0 102.8 92.8 20~.8 ~2. 10065. 106.0 96.5 205.1 39.1 fi.f} 75.9 lOq.7 218.3 37. 10070. 75.8 107.5 216.3 35.5 -I0.0 100.6 101.~ 211.0 ~7. 10072, 97,5 101,~ 209,5 36,8 0.0 ~9.1 100,8 202.~ 3~, ' ... ~.. _ ..._!.. L.L .... :~:_.: ................ ~. .......... ..._ .~.._ _....:i-. ]6 ~..:.LiSL~. _ ..~...:..-. f ...................................... :.c.,..:..:L~:......:, .................................. ::~.::: .:.-::.:::..:.:.:.~..,. ....................................... ;.u......,.c...: ........................................ : ) i0077., 85,3 97,6 201,8 b6,7 0.0 66,2 IOq.6 20q.9 53. ' .............. 10076. 62.6 100.7 207.2 ~g.5 O.O 62.5 92.6 199.3 40. ':r'"':7 :"-'-':-- '~77~:~:7¥~ ;~':7->7~';';~7'?~?:~!~jf?T'~?T~?Tw%~?'~7~i~'~'?~;:;;:¥~¥' ~ 7~=~ :;¥~y :F¥7'-'¥'"'""; -- i ~'? "~¥-" ~""'-' 7=--''':: .............. 10078. 66.8 9~.5 199.6 5.9.5 0.0 82.5 96.1 195.9 0.0 0.0 0.0 0,0 36,7 36,7 36.7 36.7 36.7 36.7 36.7 34.2 35.0 36.1 40.6 ~1.6 40.9 ~7.7 6 1 7 7 5 1 6 6 6 6 5 1 0 0 6 5 1 9 6 9 0 6 0 1 6 CCL2 ..... 0.0 0.0 -10.0 O. 0 0,0 0,0 0.0 0.0 0.0 ........... 0.0 0,0 0.0 0,0 0.0 0,0 ..................... 0.0 0o0 0.0 0,0 0.0 0.0 ........ 0.0 0,0 0.0 0.0 ............... 0.0 0.0 ........... 0.0 0.0 0.0 O,t9 .......... 0.0 0.0 ....... 0.0 0.0 ......... 0.0 0o0 ..... 0.0 O, 0 ...... 0.0 -10.0 ............. 0.0 0.0 0.0 0.0 0.0 O. [) 0.0 0,0 PAGE 2 ARCO ALASKA INC. 10080, 80.6 95,5 195.8 ,56,2 0.0 85.1 95.6 196.6 58.1 10082, 81,9 95,8 198.5 ~8,5 O.N 87,8 90.2 192,5 39,5 lO08N. 8~.7 90.~ 190.9 58.6 O,,n. 8~,2 90,5 19q,O. ~9,7 10086. 86,2 92.6 195.8 ~7,7 O.o 7~.2 95.5 202.~ ~0090. 75.0 ~9.0 200.2 $5.2 -lO.o 66.7 105.6 216.2 $~.! ~0092. 86.6 ~05.0 2~5.5 ~6.~ 0.0 ~90.0 ~25.0 229.6 29~5 1009~. 271.6 129.6 231.9 28,2 0.0 259.0 1~1.9 2:48.0 28,6 .9 10096. 111.5 7 10098. 22.5 ,& 2~1o2 10100, 22.9 2~,2 10102. 20.2 10104. 20 5 .9 ~.0 248.8 10106, 19.1 15,.0 255.0 2q.8 0.0 19.8 l~O.1 2q2.9 10108, 17.9 135,4 243.9 28.5 O.O 23.3 145.4 255.4 10110, 19,9 157,2 258.7 50,9 O.N 29.7 159.5 244.9 27.4 1~112, 27.0 1~2,& 2~5,5 2~,G 0,~ ~1,2 150,~ 250,1 25,0 :??-?~'7"~ZC~'%;~'~ ~l~"~ ~.'!:.'~':"~iT~ ;'~;~;~:7~2"~?~7:'~;;'~i:;;;~?;~~'' ~--~' ?~?'"~?" 7'i-'"~"T: ........ ; ............ ; '";7 '~:; ........... ~ ................. , ..... 26.5 27.0 27.2 26.5 25.2 25.6 25.~ 25.5 27.3 27.6 26.8 26.9 28.0 29.1 10114, 29.0 150.0 2U, 7.9 2~.8 0.0 20.1 1~+7.9 2q9.7 25.7 IO!IG. 20.0 1~.~ 250.~ 25.7 {).N 2~.2 149.6 24(3.2 25.1 !O!l~:, 22.0 151.1 250.2 2~+.8 O.(j 2~3.1 156.2 2qZ.q 24.0 10120, 24,~ 1~7.7 255.9 2¢,,q 0,0 26.1 150.1 250.6 25.2 10122. 22.2 1~5.0 ~51.2 2&.8 0,0 25.6 lq8.q 25~.0 26.5 1012~, 25,9 I~6,1 255,~ 26.6 0.0 25.0 157.6 265.5 25.6 :::::::::::::::::::::::::::::::::::: 10126, 23.5 155,5 265.5 2g.1 0.0 21.4 156.S 2&2,7 25.5 "--"'[~-- ............ - :: ~':~: ' ~'1:~ ~ ~: ~'~;~"?:"~;7~;"[~ ~7~7'7'~:"~?:j"j"": ~5';~:~ 7' :~T:-~;:~ F"?'-'~UT';?T;~;~.~:;-7:;::': TTj:jT%:?~':"'::'? 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DEPTH GR1 LSN1 SSN1 CN1 CCL1 GR2 LSN2 SSN2 CN2 10130, 19.~ 156.q 26~,5 25.7 O.rl 21.0 160,8 2~4,1 2~,5 10152. 18,4 161.2 265.6 24.6 0.0 22.6 lq6.3 257.0 26,8 101~. 21.6 1~5.~ 255.5 27.~ 0.0 ~7.1 158.5 2~0..5 2~.6 10136. 3~.9 160.3 25B.B 25.6 O.f~ 28.7 182.3 27~.5 21.7 10i38. 28.N 175.5 Z77.~ 22.9 0.~ 25.1 ~75.7 ~.~2.Z ~::'::'":~:"?-~7' :'~':~?: '%;'~' ~:7~'~ ~g~':~?;~'7';' '~:g~"'"5?::'~:~-~:~:?:'-;'~'~'g'~'"~ ......... i'g-'i',"Z ~'~-~, ~ 25 9 ........ ~ ................................ :...:... :..::; ,: _.....:.c.....::. ,: ,_ _. :,.,< .c,,.., ...~..... :.:.:: .:~ ..... :..: .::~:....~z.c~.~ ..:~., ,:... ~..~....L ,..:..:&f.:..:.:~.%~;. ~ .~ ::%~, ~.. ,: :~},........ s.:z ~: :...-....::~,~:.,:.- ::...~. ................. ..:...:~...:.:....~.....-.,.~d..~....-,'..,: ................................ &...,....a.:-..-...,..~ ............................................................................ 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'?-F W'T'-T;;F='"~TF ;':[~;g7'~T~ -'?-T"%~7;TT~' ?'TZj'~ 'FF.'~u;:~ '~:T~Y':U"'"'=TT~j"~ZAS~-'SF'?=Y'TT'-S'~Z" :~T'~ .......... == T"';TT:'S"---]" ---": ' ~' S; ......... ~ ........... - · 1g~34, 52,0 155.0 256,0 27.2 0.~] ',9.7 128.8 2,1.5 50.6 ..... : ........... i:....._..sL.,..,...:::...~.._ ~,:.:~:,.....~:;..:.:.:.::..~..:...:.~.~ .............. s.i. :...SL,_..: _c L .:. ,c~:: ...~......,,: .:...., .: .: ,._ .., .:,.....L..LL._.:;,:... :: .L.:2:,....&~:&...Z2,~.~ S....: .,i SSS....... :..::_...~. :.......:..~ .............. .L..L.S_. ..................... .................................... : ..................................................... 10~0, ~7,8 127.5 235.9 29,9 O,O ~'7.0 iI~J.3 222.7 ~0,8 lq5~2, 41,~ ll~,~ 22~,9 3;{,G-iO,D 57,~ 116,2 ~20,~ ~1,~ .~ ............... ; ................. LS..S......~..S.L L.....Si&.J-.&6z.-...:-...:..-.-.:.-..i~.-....~::.SL...,,.: .d_.c&C~..4.._4~....__SS.._..LLS._.L ~.~kLa.._/~;& = -~.L,.L.:S:.: _.: :...:..--J.~.:....:S.:.:......:..L ...:.,,S...........L..........: ............ 6 ............ 2 ............. ; ............................ ~..:: ........................... 1054~, 55.7 111,6 222,3 34.0 O.O 57,3 134.~ 24~.0 26.7 ,3 252,0 105~+6, 57,6 ~,~ 55, 6 10~50, 51,7 ~08,7 ~O,M 0 ~28,,0 2~,6 io5~. ~.5 .~o'~I.5 es.e . ~.9 25.o i055~ ' 2~.o 29.s 9 2~7.~ 29.6 10556. 52.~ i~9.5 250.7 2~.~ 0.0 62.0 1~0.0 2~6.2 1055~. 61.6 125.5 2~7.1 ~1.0 0.~ 57.8 129.6 10560, 55 5 129 2 938 .-5 29,7 0,o ~-~8 6 ]_19 5 2Pq.,7 10562. 5~,2 122,6 224.6 29.5 O.O 70.6 128.2 224.9 CCL2 -1 0.0 0.0 0.0 0,0 O. 0 O. 0 0.0 0,0 0.0 0.0 0.0 O. 0 0.0 0.0 0.0 28.7 0.0 26..~ o .o 26.1 2~.0 O. 0.0 0.0 0.0 0.0 0.0 0,0 0,0 0.0 0.0 ,50.0 0.0 30.8 0.0 28.9 0.0 27.5 0.0 27.2 0.0 .1 0,0 .U 0.0 26.8 0.0 26.~5 0,0 10, 70 ,5.~ 158.~ 25~3 '7 24 3 0 0 27 6 159 7 2¢,2 5 2~ b 0.0 10672, 31,5 15G.~-~ 261.9 24.,7 0.A 52,~ 151.1 '252.~+ 25.2 0.0 · o'. l'S ............ 1,, o." o. ',, 105'7q, 28,5 i51,~ 255,2 25.~ 0,~ 55.0 1~6,5 255.1 26.b 10576, '32.7 i~7,9 25U.5~.'~5.8 J.O .~U,r'.. I'~6.4 2;~6,~ 27,2 u.u :'"'::T'T'-"':'~::'T"i~ 2F:~ ~$T~:/~ '~?~T~ ?"" '6':-:':":":"~'~'~';:Y'"'i~'~"',"'g'-'~~. o e~ ~ o o ......................... : ................... .:.........~.:......,..::..._......:... .................................................... ~.:..~.......:.a ..................... ................................................................................................................................ '......J ............................................ ]..... ............................... S..2S .......... ; ~ ~ ' ~ 1057.'.~, 27,7 151.q 258.5 2(g.1 0.~ 25.7 158.:5 220.7 25.1 0,0 ._. ,,0:?._~ ............... 2P._.~..~ 15 .~, 5 2 F, ~. ~ 26.0 0.0 PAGE 12 ARCO ALASKA IF.lC. DEPTH GRI LSH1 SSN1 CN1 CCL1 GR2 LSN2 SSN2 CN2 10580. 27.1 1q6.7 257.5 27.3 0.0 ?7.7 154.6 2_56.5 24.9 .0 28,1 152,5 2.50,7 24.6 10582, 27,1 154.0 257,5 25.3 O.H 27.6 152,'~ 252,~ 2~.8 105Bq, 2b,6 15],,7 255,1 25.2 O.O 51,* 156,2 256 b 2, .5 2~ lflS~G~ ~U,~ ],55,~ 256,2 2q.7 [~.0 29.6 162.2 2fi~.5 2~ 10588, 27,8 159,6 259.5 2~.1 O,fl 2~.0 172.8 275,~ 2~ 10590, 25,9 170,8 269.6 22.9 O.f~ 26.9 18'Z.5 2R1.6 21 ~TT¥`!~r~;`TT`;~:~T..`:````~T!~?;~!?!~7~J!`:`:~?~`~TT?~?T~:;~:~?~ T~%t~;~'":~;-T:'T';~T"'?~'T'- 7"~-T?-y~;-"'7'~'" .9 25~.2 2~ CCL2 -10.0 0.0 0.0 .5 0..0 .2 0.0 .... .4 0.0 .9 0.0 .0 0.0 .6 0.0 .0 0,0 .5 0,0 ,0 ,2 0.0 .9 0,0 ................ .7 0.0 10596, 52,1 10598, ~'F.2 10600, 2~,1 1 10604 20 6 ~ 10606, 19,8 165.~+ 270,8 2~,4 O,n 18.~ 177...'% 10608, 1~,~ 185.0 286.1 22.5 O.fl 19.'~ 181.5 :52.0 ....2..5, u. o.o ,1 26,1 0.5 2~,5 59,8 24,7 59,2 24,9 25, 25. 2 7,8 24. 272.5 23. 2/~3.3 25. 287.9 2~. 293.0 2~, ~6.~ 24. 0.0 0.0 0,0 ............ 0,0 0.0 0o0 0.0 0.0 0.0 0.0 ., :~.-,,~,Oi .;~ ,,,:.,~,..-~ ~:, .~:~.,-:.:. ,:::. :.~' :':' :..-r~ :21.1 . . I ~ 0 .7 2 q. 10610. IG,9 18.3.9 289.5 22,8 O.fl 22.7 18~.9 29~.6 2~.9 106i2, 21,9 laS,0 294,6 2L5,~ ~,D :56,9 196.2 248,0 2I,~ .. 8 291.~ i9.5 lrtO].~, 35,1 i~3,2 ~89,5 2U,9 O,o 51,2 175.2 281.0 25.5 lo~i, ig. 1~2.5 18~.9 25~2.5 2~.0 O.n bi.5 153.9 2~7.t4 2B..~ ............ u.=,.,,,..L.,,i,.61.2 275.7 25 loGz~. ,~.~ i~.2 ~5a.i 27.0 o.o ~l.~ i~,s.o 27~.9 ab .9 .5 10620. 60,7 168,0 272.5 24.0 O,fi 58.1 171.0 P77.0 2q,O 10622, 5t~,8 17~,8 275,1 22.8 fi.R 6~,9 [5~5.5 255.6 25,1 T' ~ i"~:;TT""T 7'"T?~iTT~:'~%~F~F?.''=''T?': 7;'3uSj'-T''"''' '-%"F2;~;SFT"~7'~TT;':5:?~7~Sj?'}SiF"~7=5;{'ETTyT'{F. T7-'~':''':'''~' '7 ............. 7 'T~'-% .................... :"-'""kT'": ......................... ; ~. ~O:G2~,:. _::u,8 o5,9 .~65,1 2A1,5 23,0 I0621~, 61,9 15~,6 260,0 25.8 0,0 64,~ 170,9 27~.0 25,q 10626. 65.0 162.4 265.~ 24.3 0.il 62.7 197.~ 29~.5 21.0 10628, 6d],7 196,9 292,6 20,6 O,f~ 58,5 218.~+ :515.6 19,.5 ......................................... 'T77' ~?~F?~?'~T;;T;T'~;~%:;;~-TV"-~W-r:"""?Q~'r'"?I~'~';;~;:?''''"~ ........... : ................ ' ............... ?;~':; .................. ; ........... 7 '" ,:':'u: .... -:0,8 ~1,2 197 q 299 9 21.~ F'"": ........... ':7"'"':'"':'"7T'"'~;"."':'-~:'~,;;:":':~5"~"' ....... - t',-~C : ~ · · 0.0 0,0 0.0 0.0 0.0 0.0 0.0 O. 0 -10.0 0.0 0,0 0.0 0.0 . . 0,0 0.0 0.0 0.0 PAGE ARCO ALASKA ,[NC. - i~%i T- .... , ::"i::::: .... ,- ~ C - · -:-~, - SSN2 C N 2 % CCL2 10630. 59.5 220.q 316.~ 19.5 O.O qq..9 19q.q 296.7 1065~, 32.7 197.9 295,1 20.7 O.O 28.1 165.5 2F, 7.0 ':':"'"r:":7: ::?::"?''' 7'~S7~V ~:~)~;: j;~F?7" 7Z"V"~;'Tt~;T ~T'::%"'~;:: 'TT~;'=: 7:77T2;~2~: ~'}~Z;T~'~:~tt}':::':?'~;~':?T?-~ '2"7~'Z:'"~'~ :7'7'~T: --?"- :5 '--:'7:-':' ?- "'~'"' '7': ~-:7'~ ..... : .................. ~ ................. 10658, 26,1 !80.5 291,1 23,8 O,fi 38,9 12U.7 221.3 10658, 35.9 13~,0 237.6 28,1 O.O ~.7 130.7 229.1 lO6qO, ~.3,6 i50,9 22q-,~ 26,6 O,fl ~6.0 199,7 2~6,3 106~2, ~8,7 i~1.6 2~5,1 2&,7 O.~ ~1.8 lq2,8 2~5,5 21.6 21.2 22.5 21.8 2~.3 28.5 29.~ 28.~ 27.5 26.~ 2q.9 25.8 26,0 lO6~q. 38,6 139,3 245.3 27,5 O.O ~2.9 152.8 257.6 25.6 "y~"g';"~ ....... ~'~i~',' g ...... a'~'7 lO6~G, ~9.6 25,0 2~,6 10~5, 57,2 25,6 .9 26,0 10650, 3~,5 0,8 27,2 ,6 26,0 10652, 26,5 ,.9. 27,~ 27,0 1065~, 26 5 6 ,8 28,0 .8 2~U.6 28.2 10656. 26.5 i58.9 2~0.~ 26.7 0.~ 27.9 12'.0 228.5 29.6 0.0 0.0 .......... 0.0 O.O 0.0 0,0 .......... 0.0 0.0 0.0 0,0 0o0 0.0 ................... 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 .............. 0.0 0.0 0.0 0.0 10658. 26,2 121,0 230.~ 31.~ O,n 2q.5 117.3 2~3.1 33.9 0.0 :;:':T!:??!!::~i: ~;~:'~:~:: ~ '~-?ii?:" :"7':;~6'i;'~6:':'":-:::~'~'-;~-i"~'~';'g""-~'g"5,z ~2 ~ ......... :.....:.....,......:L:: ....i.:& ....:.::.....:..~-,::2.::],~d, ,:::.:..:1~..:. ~;:~Xd..Z.~.:d:.L;:::...~..;.::L::-,L~.~:..:::: ::..:......:..:.:L..::cL..:~.L:..::.:;::...C L 21~L&,,..~,-.:. &.&L......::...:...:.........:.:.-.d-..~-L- i:-,Z~. L.& L- -:.: -:: ::....:.~.:-:..:.,.,- -L ............... .~..-:: .......................................... ~ 10660, 25.~ 115,3 23q,5 35.6 0.0 23.8 139.2 252.0 28.7 10662, 2~.7 142,4 256.5 28.5 0.~ 27,'7 ~2~,2 225.2 27,4 1066,, 25.5 130.9 226.0 26.6 0.0 30.5 151.6 2,5q.1 27,9 loggg. 28.~ !30.7 25~.5 28.1 O.O 33.0 !26.9 ~p~ 9.7 28.7 0.0 10670. :59.1 125.U 219.q 28.0 0.~ 5~.5 107.2 209.1 32.8 0.0 T-:': .?~-:~':7 ."?%-~.T"~¥7':'~F;~ ........ 7"':':: ...................................... ~ ........... ~ ~ ,~ 13.5 210.2 29.9 0.0 10672. ~2,6 111.0 211.3 51.5 U.O 71.q 117.q 218.7 Y:;:.~ : ~6"~-'::'~:,~:'~"~:?:'7":'""~-fi'"~--'"7:'"'"g'~":-~'-' ~-~'Y';'"~"" '~ ~ o. ~ 1007~, ~8,5 13~.,6 236,5 27,~ 0,0 70,5 128,.5 2.52,6 3U.2 0.0 25.9 0.0 26,7 O.G 28.7 0.0 29.q 0.0 27.5 0.0 28.6 0.0 27.9 0.0 0.0 -10.0 ....... 0.0 0.0 PAGE I]EPT~! GR1 LSN1 SSN1 CN~ CCLI DR2 LSN2 SSN2 CN2 9 7 8 29.J, 29.5 10680. ~9.~3 129.~ 2L51.3 28.1 0,~1 73.7 128.~ 228.9 28.0 10682, 47.8 129.7 229.2 27.6 O.O 73.3 129~,.~ ~..2~.9 27,9 10~86, ~8,7 122,8 229,7 L~O,5 O.~ 72.2 130.~3 2:%0.0 27.~ 10688, q7,9 127.2 228.2 21~.5 O.O 76.0 150.8 229.6 27.3 ............ ::%`~:~T~`?7`{``7``"~m`~```r%:``~`~`~T7~2T`~r~````::~`~`~?7~`~72?`:~`~`?~:~``~T~T%~`%1~'''':::~:''~' "~77~=''' ~7:"'-:':'-"' '"'~"":'~"F'-'~'"7'-'77--F' :'-'::'-'~ .......... ~- '"Z .......... : ................. : ........... ~ 10690. ~7,5 I~0,2 229.1 27.q 0.0 7'7.7 131.0 2A2.8 27. 10692. 50.~ ~27.~ 250.5 28.7 0.~ 78.0 125.3 227.~ 28. IoGg~. 50.3 128.1 252.2 28.8 0.8 78.0 Z2~.3 229.9 26.0 2;50. ~ 10G96 ,0 29.~ ,0 29.4 10698. 50 0 0.0 10'700. 50.5 0.0 0.0 0.0 0', O 0,0 10702. 50.5 ~i ':0'0 0..0 0.0 CCL2 0.0 .... 0.0 0.0 O.U 0,0 ............. 0.0 [].D 0.0 0,0 f}. 0 0.0 0o0 0.0 .............. O. 0 ............ ..... LIBRARY IAPE CURVE SPECIFICATIONS Company, ARCO ALASKA, INC. Well D.S. 4-13 Fi e 1 d PRUDHOE BAY , County, State N. SLOPE, ALASKA Date 10-18-81 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale GR Gamma Ray CN-Mult ispaced 0-100 100-200 .., . CCL . Casing Collar Lo. ca..,tor ., " 0-10 LSN , , ,L.o, ng, ,Spaced " 0-1250 i'S~N~* Short Spaced " O-l_~n~,vo I CN i Compensated Nuetron " 60-0 ARCO ALASKA ....... D.,.,.S,., ...... ~- 13 ........... ....:.......:.,._:::: '"'~ :S:: i~.::: .......................... B,E,,B,!..f:,,,:~ ......................................... G.A,.~,,~,,A.,...BA~ .................................. .S?!.,O..,,R_...i,,,.,,,,,SP.._AC,E ..... .L,,,O.NG SPACE COMP , NEI IT C£L ...... .~.. 0. ,....0... .....0,.,....!..,.. ..,. ~ ..................................................... .1...~.,~......,~..8 ........................................... .~ 29.... 2 ~ ........................... 5 02, ,,.,,:,::,,.. :,:~.:.~.. :;:~:,..,,::,:.,,,,,:,:.:::.,.::':: :,::,,,, DD~!::L...%::~.~:i;'~.:::..~..:!:,.;.L::i,:::::_.,.::...5:0~:":8.,7..... ................ ~.,0.,.,0,,.,0,,,, 5., 0.,. ................. 115,11 q. Sll.. :~: 1- .,~14, ~ ..................................................................................................................... i0007 j 0 J.J 1. OR q, 51.19 .506.59 10009,0 lO~,GJ. ~37.7G 511.93 10011 , 0 q9 . O0 ~Sa . 57 502 . O1 1001~, 0 96, ~0 ~7~. 16 515.7~ 10015.0 98.51 ~.~n. ~ 50~. 30 ~ 0.80 .......... 10017.0 ~0 ~1~. Ol ~7.5~ 0 0 .............................................................................................. ............................ Z 0o19.0 1~ 0. O-so zoo2l. O z 0.80 0 ........... 10025.0 0.80 10025 0 1 ~l.~& 0.~ O.BO 100~7,0 118.1& ~07.25 ~95.1. q 3~ 55 o.Bn 10029.0 109,1~ q3~.~9 508.11 .......... ~7.,55 O. lO0~B. O 120,24~ ~9~.~ 5~7.78 100~5,0 12q.15 ~51 .19 51A.79 37.~3 ...... .0..., R d ......................... 100~7,0 121 ,a~ ~5~.2~ 5~2.&9 100~9.0 12~,17 ~5~.2~ 508. J. 1 lOOffl. 0 120.P~ 520.~42 57 100~, 0 lJ 5.a4 4A~. 18 53~. 05 .....'""' ~``~``~.6?~.`~:`~``.~:~.`.-~:~```:~6:~:~`:`~`~`~=::~``~.~:".T`S`:~.~.:'' ':¥::::"-::'¥:::":"S::"::~:"{"~ 100q7,0 110 . 7P ~. 2~ 527.95 ~7.G2 0 . : :,, ::":i..:~'~:~:~:;.,.~:":'. ================================= :'.:'... :::::::::::::::::::::::::::::::::::::::::::::: '-::::, ~:~..~'::':~i::~S T'::':":::'"'.'"::'-'/:':: :'~' ~':~ :'"~;-~- ~':'o~ o, lOOqg, 0 11~, 01 ~Sq. 1~ 51 7. P7 PAGE ARCO ALASKA INC D.S. ~-1~ OEPTH GAMMA RAY SHORT SPACE LONG SPACE COMP.NEIIT CCL 10051,0 1.13.,.6,5 ~57.29 5P1.08 ,58.21 0.80 10053,0 118.16 ~Sm. 07 52~. 90 3~. 9~ O. 8N 10057,0 122.07 ~51 .19 50~.5~ ~n.65 " 0.88 10059.0 125,&1 ~51 . 80 510. ~0 ~00~. 0 ~.~7 f;~.~ :~? ~:~"~:?.~ ,~:,~:'~:~'?~ 10063,0 11 3, O~ 10065,0 115.97 ~1 lP.~2 0 .SO ............ 10067.0 8 ~0~.5~ ~f19. O~ ~ O.fiN O~ 81 ......... 10069,0 0.SN ~8~ O.BN 1007~.0 .0.8~ .~'~ 10077.0 71. a~ 10079,0 76.7a ~.05 ~9~.~8 ~9,19 O.~n 10081,0 79,7~ ~A,78 ~86,75 ~,05 0.8N 10085~0 80,08 "7~'~:i"~ ~'~'~'~'i~'~'~.T~7:~.~'~'~i~' '~?~:~'~'? ~'~'~'.~:~ Z'{~'~"~ ................................ ~'~".-'g'+ ............ o.~n ...... 10087,0 a~,~7 ~q,56 q97.q5 ql, 0.~ ............. 0,81 ~.'~":~.'~'~' ~~'~'~'~.~'~' ~ ~.~.: ~"'.'~'~'~'~'~'!'~'~;':'~:~.'.'~' ~'~'~':~' ~:~'~:~' ............ ~'~. ;. ................................ -X-~..-~ ~ ......... ~-~ ~.-~ ......... ............................... loo~z,o z~z.~ ~n.t~ s~,~ .... ~.~. !_.~ .... o..nn 10093,.0 2~9.88 501 .~ 608.06 ~1 .SN o.sn ........................... ~'i'~2 .... 0: ~'n ........................ I0095 ~ 0 RO.PO 51~.9~ ~0.~6 ~7.57 n.Rn ~-~'~'~'- ~-~'.~'~:;-~-~'.~-~i'~-~'-~.;.~'~;.T~"- 7.-~-.~-~-.~,'~.-~'~; :~17"i;77~.'~- :~{ ~: zoo~7.o ~5.~ ~..~ ~.~7 ~7.~ o.~n ........ i-~-~'~'~'~"';'-b' ................................ ?'-~'g'-;"~-{--" ....... :'~'" ....... :g~{~-;: :'-'¥'¥-'-'":77--:,'-"~-~?g'7' ~,.~ o.~n ~0099.0 25.7~ 5~n . ................. :'"': ............... : ................ "' .............. '" " ........ '" ARCO ALASKA INC OEPTH GAMMA RAY SHORT SPACF LONG SPACE COI~P.NEIIT CCL ......... !QIO..I.., 0 ................ 2~,05 ................5~.6q .660,70 10103,0 )2.71 5~v.02 686.6q Pg.,. 0...~ 0.80 92 i0107,0 23,93 53~.G4 651.5N 10109,0 2~,90 5~z.50 6A5.28 29.10 0 ~01~, 0 28.fi9 51_9,55 6WO. ~0 27 10115.0 25.9~ 51. q. 55 659.17 10115,0 P2.RA 52~. 10 670 .~2 ~6.81 0 10117,0 2 53~ 03 673.67 10125 0 Pti.79 0.80 PA.O8 0 10127.0 ~2.09 567.16 699.61 ' :!' ......... 10129,0 ~2,71 5A~,89 7~7.2~ 2fi,~2 0 10151,0 2~.Pg 5~.~4 693.51 25.90 0.80 10135,0 31.8~ 5~P,.13 679. O1 10155,0 29.91 5~7.16 73~. 70 10157,0 26.61 5~n.59 778,96 21.15 0,.60 10139,0 25.63 599.79 727. R~ Pti. 101~1,0 27.3~ 55p, 51 689.69 P~. 55 0.8n 1.OlqS, 0 26,gl 5A~.6~ 755.~0 2~.17 0 80 101q5,0 25,~ ~0z.78 7~5.9~ ~ ........................................................................... 101~7,0 25. ~ ~1 .~8 7~9.80 101~9.0 25e 02 AI.~ .93 793 .q5 ,, ................ .. ................. :.: ,,. ............ : ............... PAGE ARCO ALASKA INC ...... Q,,,....S,..., ~+- 13 SHORT SPACE LONG SPACE COMP,NEIIT CCL 0.8t"l 0.80 ............................ 0.80 0 0.. 81~ ............ 0.80 1.0iD7.O .... 2_..5...,,,39 674.58 888.82. 19,7~. 0.80 ~ ~ ;.-~a ...... o,~'~ ................ ,"' '.' ~'"'S'~ ...... ............... .~., ~..~.,.~..9,,.,O ......................................... ~ ~....,,.,~,! ........... A~. 5o 8~. ~G .... ~_]~, 3i o. an ........................ 10161.0 27.22 GAP. 37 878.90 PO. 43 0 , BH '~:~S2~'S~ .......................... ~"'~";'~ ............. 0',~', .... 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PAGE 5 ARCO ALASKA INC OEPTH GAMMA RAY SHORT SPACF._ LONG SPACE COMP,NEIIT CCL 0 LIBRARY TAPE CURVE SPECIFICATIONS Company .ARCO ALASKA, INC. Well D.S. 4-13 Field PRUDHOE BAY County, State N. SLOPE, ALASKA Date Curve Name (Abbrev.). Standard Curve Name Logs Used ~-'Scale GR1 Gamma Ray'-Pass 1 CN-Multispaced , , 'o-zoo, z°o,2o'°' GR2 " ,, ,, .2 ,, ..1 ,, GR3 " "' '~" '3 "' · ' "' ' '-., ' ' ',"' ' CCL1 Casing Collar Locator Pass 1 ,, 0 - 1 .. CCL2 " " " " 2 " " ,,, CCL3 I " " " " 3 " " SSN1 Short 'Space 'Neutron Pass 1' "' 0 - 1000 , SSN2 " " " " '2' " " , . SSN3 " " " " 3 " " LSN1 Long Space Neutron Pass 1 " 0 - 1250 LSN2 " " " " 2 " " , , LSN3 " " " " 3 " " CN1 Compensated Neutron Pass '1 " 60 - 0 CN2 " " " 2 " CN3 " " " 3 " " , , , ARCO ALASKA, INC, D.S. q-13 API FT. API API API PASS1 PASSp PASS3 PASS1 PASS2 PASS3 O,,o .o~, loOqO. 92, O, O, -381. O. O. -318. -62. 65. qg.8 -f1.3 -0.3 ~i~i~'.!~ ;i'ii~;~~ .i?!i??:;.ii~; ~'~;':ig2? ' ~.~, ~, ~, ~ ,o, ~ ,o, ~ loo~o. ~a. o. o. ~=. o. o. ~, ~. ~, ~,~-~,~ ,o ~ 10080. 55. O. O. 559. O. O. llSq. 63. 63. 9.6 -0.5 ,0 ..5. ........... ~`~`~```~:~`:~:~:`~```~``J~::````~&:`J~````:`~vi`~``~`~:~```::~:~:`~``~:~:~`~:``~```~```~``````~```~ ..................................... .....u... ............ :x.:. :~.J.: ................................ :.~:....._ ,.,....<....:::.J.....:~...._..J:.:...u.......: .................. : ............ :.:......:..: ................................................ :.: ............. 10100, 16. O. 17. 659. O. -127. 1538 ........... 63., ~7, 7.~ -0.~ ~..8 '~,;;.:u-.'~/..;~-~2~'~. :_ ;6~3~:: . 5~0:,.: :5~0, I562 g~l. 682. 7,6 2~...7 26.9 lolqo. 15. 15. 15. 686. 573. 586. 1579. 76q. 780. 6.3 2.~,5 .... 2 ~ ,..5~ ........................... i~'~'~0-~0-%~', ............. :-:~',,-~-'2'~,~; .................... ~:~,-:S~,:; ............................. ~"~?-:--',:--~-"'g-,~-9'-~ .................... 5,,-07-~-,~2 ..................... 5i"~-'"~- issg': ~'?'~' ..... "~:'~'~:~'~'~'~i~O~'~'~Y';~'~:"~"=~'~'"i'~~'~;~''~''-:~'~'--~'~' -'~'~"-~"~'~'~' ~'"~'~f~7~::~"~', ~:~;1'0~7 5' ~l~. 7 ~e.~ ..... '~L:~'":~g~:~':~:~'~L'~'~=~L~'i~:'~~':~L:::~'~::~'::''-:'~ ~f~:~l:~ ~'~'~'~'li':I' 5, 5, ]. 17, q 17.5 '---":'-~'~' ................ i'~O':~:'-~::~6?:'~:~""'"--~':::'--:'-i"~?:" ............. ':'::y~":;' .......................... "~'--~--?::'-"'::'-?-"~':-'i'"; ................... ~-:-~--~'T-'-'~ ............ ~-~-?-'1 ........ i-~-~5. ~l~, ~,. s, ~an. ~~o. ~ ........ .......................... I'6'3'g"6"';' ............................. i5'; .............................. ~'~'"'~ ............................... i"3-;' ................... 'g'?'21' ................... B'gS"i ................ 5"?'5'"1' ....... i~'~'5", A23, 7~5. G. ~ 2 n. ~ 22.9 ................ ....... [ ............. ~,:,,:,,.,,':,t~,&..2h. L2z L 6 :,_,..,~,~::,:,.,.:,c,u,.,,,:Z~].:,,, L2.1...&.,u,.:u,.::::,,._.:.,uc..L,,~f:,u..,..,u. JL.~lL ZZ ...;, ,..;..,. ,.,.:_,,. ,.:,:::..~ ............. 2c~ .............. L] .......... [. :,,t.:,:: c .,,.:......_:.,u ....... L., ,.~,Z..L., ,2,~, ....:.:..... _..., .::,. t .... ~ ~ 10580. 15, 17, 11, 6~5, q99. 696. 912. 642. 607. 7,9 27,6 ,.. lo~.oo. ~.~ 12, 1~, ~2, ~l.,. ~9.6.., .......... 1.~.2.~., ............. ~gT, 59~, 7.9 .... 2.~, 7 ~';T:~?~;~'..~ ;?~~'~.'~'~ ;C7~'~' ;%' ~;.:~'.:~:~'~<:?;.;~.- ~o~. ~. ~o~.~. o ~.. ~ ~. Y lOq20. 1~. 12, 13, 628. q9q~ 506, / ql 7,.. 596, 617, 8..2 29.0 29.6 ;?;:~~;~ ;~:~?~.T.:;~:.~ g';:~:~'.~'.~'~:6~.~';~.'~T.~'.~'g~g;T.."~' , 7i~. ~. 7.~2~.~ lOqSO. !q, 15, ].q, 708, 6q7~. 67~, 1579 .......... ~57. 885, 6.7 2.~.5 22..5 .... '~"-":?'Fi~6~6'~' "::~:":':":"::~-':;"~: ';:~:'~'~:~"F:~:~"gj:Y~'"'g'~:"~'-."~'""i~'~'6"~ '~i'. ~. ~ ~~-, z ~., ......... ....................................... ....................................... ~....=.... ............................................... ~ .................................... , ~ .... ~07, 8o5. 8,0 2~,8 ~ ' 10520, 1, 15, 15, 651, 7~3. 7q5, 125q,_ 998 1037. 10.7 21 .1 :'"'?:'7;' " ~'~':~' .......... ~'~"~: ~,.~: ~o. ~. ~ ~. ~ ~. ~ ARCO ALASKA, INC, i],S. ~-13 API FT. AP1 API~ AP1 PASS! PASS2 PASS3 PASS]. PASS~ PASS:3 % .~ ?f~ 10580, 31. 18. '16. 1~7. 598. 588, 185. 718, 7~3, 25,5.. .27.~ 10600. 26. 12. 15, 2~. 57S'. 579, 289. 765, 77.1, 2~.,7 10660. 3~, 18, 18, 57. ~01'. ~10. 12. q. 53. ~3~, ~.2.....6 zoa~o. ~. 25. 2~. zz2. ~5. ~72. ~. ~o~. ~o. ~2.~ ~.7 .~.~._~ ...... a:,~.,~<,z~,:,,:..~¢~¢,~,~.,~:¢.~.~....~,~.,,....,.,:..<~......~C,~-...-..;. ..................... ;.........~....::.....:...:...:.:..:......:~:.:.:....:::.:::..::.:-.::.: ..~..-f..::::::~..:~:-:..:.-.::::::~:....¢.::..:....:~,~..~.~..;,.~... ,...~: ............ : ............................................ :.........C.:: .....z .................................................. 10700. O. 26. 28. -381. 370. 369. -318. 529. ~71. q~.8 ....................... LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Alaska, Inc. Well DS 4-13 API 50-029-20305 Field Prudhoe Bay County, State North Slope, Alaska Date 8/21/81 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale CN Compensated Neutron CN/Multispaced 60-0 LS Long Spaced CN/Multispaced 0-1000 SS Short ~.paced CN/Multispa..ced 0-1000 ! GR Gamma Ray CN/Multispaced 0-i00 100-200 tCCL Casing Collar Locator CN/Multispaced 0-10 ,,, .......... ..... ................. . :: > ~- PA6E 14 ARCO ALASKA INC. .......................................... ~ ............................... : ............... ........ ~ ................................. L..... ........................................... : ......... . ........... ~ DATA EVERY 1 SAMPLES 99( 120.05 8.03 18.35 65 99 119. ,6 8.05 18.05 65 .58 99 119· 8,05 17.58 ................................. ~,~ .................. ~'"~'" ?'~'"'"'F'0-,T---- ......................... 119 ~ ~6 ': ' ~'"'~ ........... ' ......... :]8 ~ 05:''-'-''¥ T'F~ ..... T ........... ~ 7]..! 53: "? "~; '"~"'r"' ~. .... 657:·:'-'''~''' "" ....................... ~ 9o 5";'5'0 ................. i"~"9"";'"~'"~' .................... '~' ;'"0:'~ .................. '~:'?'::';-5' 9~ 769.~ 76 777.38 783.~2 3.32 .~9 ...................... "I ~ · 9'0 · '29 82'5.36 5'0 ......... i2'7' ;"q:'~ ..................... 8 ;'I2 .................. 17'"; I-3 .............. 8I'8 ..................................... 99'25";U0 ........ I29';5'9 ..................... 8;"I'I'" ......... I7';'::'0'51 ........ ~:8'2";"82 .............. 8:I-3'; PAGE 2~ ARCO ALASKA INC, .................. ............. "~i~' ....... :'"'~; .......... ~'"""'~"~ '~i";"" '''~ ................ : .......... ~i'P,'"'~'"'~""'"'~ ~F'"'""~"i~"FF'"'~'"T-' "i'~::: ............. ':'"¥'- ~ R ....... .......................... D.._~...~.~..~,. .......... ~.....,..A?_.~ ...... SLOPE DATA EVERY i SAMPLES GR COL CN S'S LS ...... ;'"'"' ............. "'"9'9~-5~-T5'0 .......... 'ii'~'9';"3'~':' .......... :'"":--"~"~'"i;I"~'?"'""-'"'-'I"~:;'-~"~'' ............. '~'?'9'~;'-'~'0 ................ .................... ~ ............. ~'9'~-~'---;'"'o--o-~-- ....... ~--2--?---;-"8'~' ...................... -~--?:'-']:' .................... :~'~-';'-"~'-~ .............. ~.-y-N:'--;-~,~ .............. '~'"~'2-';"'o5 .................................... 99'2-7";--'00 .............. '~D'9";'-37:' ......................... '~-~"~"i ................ ":~'i'-~'~;'-'~9' ............ ~-~"5'~'-'i"'~ ........... '"' ........ "'"T"-""9927-~'50'T'"':'~3-~"~"4L'~'T ....... "~'-~:;~?OF':'"T""-":Ti'7::.~:"~'~-:" '"':'"~'(5' OF,'4'i --- ? 98 ' 17 ..... ....... ~'""9'9~-6:-;-50"':--:"~-3'9"~'59"': ............ ?':":'~'~'~"OT"':'--':' '"~3"-";-?-'~-~0 ,'-7i' ............ 795"'59 .... .......... ~'---:~'~"a'9';-:5o--'---:'~ :~'~--;'x7?'' ............... 'a;;-rr--':?-:: x~:!;-~-~-~---'¥---~ ~'4':;":~'?"-':-'-~ o'-~ ;'s"~ ........ .......... -T-"T"'~?99'$"I":;'5'O-'"::'"':'~5~'-~:75'"T'"?T-":~'~:-0:9'~'''I''''-:''?~:?:;~'-~:~iT''T'~'7:7~-'~-O'- .......... ~'09";;'~9 ................................ ....... """':':"': 9:93-~' ~'5~ ':":':':':-i::59"~:J[:'~"-::'"':!" '7"-:~";;:'-I"O"'"'"F--~::I'~':~9'~i :-"-' ........... :-'T":'"-":9:9~"$";SO-"-:'-'"'~J;'~"~'-;'~:9"::''-: ....... '"'-':8-:~?-~32'-'-"i'i' ii~"-1:5:'T'-"--'~"~77~'9'0'''-:--'- 803 T"' ':'" ~--'"9:93'~T;;;50':?' Z':'~' :7G"~ U~"':~-'":"-":'T"T~-'~"~i2T"'": ;~'":~'I7~!~'-5:~'i -'~: :'-~72' - ..................................... 9'9"35':U0'""-'"-:"-i'8;-I-'";"'8-9--~''-''-': .................. '6'-;'"i3 ............ :"--':'~'~I7':;"-$"3' ......... :'""'~-7;2- 37 .67 6 9 . I5 .......... 8"2"2'. 6 8 7'";'"8:~ ''~' .............. '~"7';-59 .......... ~'97~':;':97 .................. 8"i"9"";87 . PAGE S ARCO ALASKA INC, ................................. D";;'"~-~'"'~'"~"I~ APl 50"029~2'0~05 PRUDHOE: BAY NORTH SLOPE GR CCL CN S LS 74 99 ,0 119· 5 8.13 18.12 69 ·43 8 .70 ~7 995~ 116. 8 8.1 17.97 6 .78 791.68 T' ........ "'""i"9"95"~'"~"0'0'"'i":'"':""i'i'~"'~':'1'2' .......... '"'""':"'~"; 'i-O ......... T'"~-'i'?i~;'~'~"' "':'' ~'5'8,6'3 786. i2 ................................. '9'-'9-'5'5'-;50 ............. i":i'2';-'2'7 ............ '6-;-'i' 0 ...... '" ~:"i"T~'"5'~' ....... ~'39 ;'5'~' .............. 77'3; 0 0 .......................... :9'9'5'~':';'0"0 ............... i'~i'"l' '1'03 ................... ':'-""~ ;"i':O~::'":-':~-'':~i:'7:'~;-''9'~'''' '":'"'T~-$O"i;' GT, 72 .O9 ................................. '9'95"6";50 ........... "i02"';':'72' ............ ........ 8~:-'05 ...................... I'~-':'~-87: ............ '5'~'5'":"92 ............. 7'I"~. 0"7 ................................. '9:-9'-5"7~"~'--5-'0 .................... 9'-,~'- ;'4"9' :'-'" .......... :'"" '"'8' f"O"~'"" ": ............ 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'. ........ ----~ ........ :----:~-~-~-~:;--oo .......... ::'--7'-~'-;2~-----::'-~-!~--~i~i:'~- - ~ -~2'~";~o: ....... ............... ........... ~-'-~-'6 ~'-';-s-o-"--~'-'--'--- 7~'; ~:- ~--~-~'~'--'-~9': -' ' !'""~-~:'57~ ~ 3 ............... : .................. 9.9 .G -~.:.;. . 5.0 ..................... 7.~,_;2, ~:~:; ......... ' .............. :'"'"'!9'~'~5";"0'0'"":'"'"" -'7~; 7 ......... ............... --~--,---~-~-,~',5,,;-50 .................... ?5?5 ~. o~ ' 58."~ ~5';~'- ................................ ~.~.~'-~;-.50 .............. :---7-~'--;-:22 ............................ ~--;'-0~ ............... :---:,5a-~--0,~2' ............ ~.35.-~- 3'a ............. ~'2-,~'. 71 PA~E ~'- ARCO ALASKA INC. -"-"':-"~-~"~7~"'~'~'"i3---':~'p'i'"'"'"5'0'~'~-'29~'~':~3'~ ~':'-~'-'-P'~O:'~'~"O"~': B A Y NOR TH SL OP E ................................................... :. ............. ~ ................................ ~ .................. L.. ........................... : ...... ., _._,.~ ........ L ,., ............................. : ......... .. ................................. DATA EVERY ~ SAMPLES ,?,,,,.,., ~,,.:.._,,.,.,....,.,. _..,:.,......~ .................. 7,,.,,? ................. ~. ................... ,~,,.,,..,, ................. :._.~ .~,...-.,-,T,.,.,,yT,.-=,. ,.. ,:, ..................................... .. ................... ::, .............................................. ~"~"?'"?'-;'"~'~ ............ :``f~``.;.`~.~..`:`.`.~```.~````~.~`~y`.`.`7``7~:~;``?`~``;`":`~.`."~..?`~`:;``~"~' '- ~'~'~";"~ 5 :"~"?~';':'5-0'-"-'-"-:i'~"b-'f?~'~"-'?;''-'':'' .......... b-';:'~':~"" ................. "~'~':~'~?'~':'"'-v-"~"~2':;"~"~: ...... ~52 -'w-":~ ~ m_~ ~'='"" "~' r '~ '"~"':w IS1 ~ ~:.~: ''~' '"':~';~':~ ............ "'-"~"": ~" ......... y...~..7~-..7:.:......~?p~. 7-~~ ': ......... 5~m~?':"'~'r"~F;?' 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D'";'"'S";"q:";;]: '3'":'"/~"P" ' 1'""": "5``0`` ~;"029'"=-20 ':3'0"5. .......... p"RUDFtOE-'"-BA 'Y--' "N0 :R-Ti:: t SL'0P E SR CCL CN SS LS LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO Alaska, Inc. ECC 2475 Well D.S. 4-13 Field Prudhoe Bay _~ ..~ L~ Count)', S~ate North Slope, Alaska Curve Name ~ (Abbrev.) Standard Curve Name Logs Used Scale · Files 1-3 Date Casing Collar Locator t CN -Multispace CCL -~- CN t Compensated Neutron I " 60 - 0 SSN , Short Space 50 - 550 LSN ~ Long Soace ! " . 0- 200 GR t Gamma Ray- , File 4 .I 0 - 100, 100 - 200 60 - 0 NOV 0 ~ 1986 Oil & Gas Con~. 6(mm~ission Anchorage .E !&v :~ ? 41 .;:2. x - c i , i 't,p ,, L tO £ .' . ,. - ,, ,5, q '2 ,. ~7: t5,0.s 'z,.:.l_ ~?, ..? 4m.. c Io' . ] :t" , q ' -.. ~C, h · 1' 7 ? 05 -' ~6 '* &4.~' ., . . / ......... '.;r~ --:::-~ ........ / ~ I :..) '~ ~ ~" 'i .,.,, ,. . ...... .. ..:-: ¢~.: "'.: '~.'-- "- " 1- . 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