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182-026
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, November 14, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-17 PRUDHOE BAY UNIT 13-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/14/2025 13-17 50-029-20718-00-00 182-026-0 N SPT 8217 1820260 2054 1 2500 2389 2355 0 0 0 0 REQVAR P Adam Earl 10/8/2025 MIT-T tested as per AIO 4F.006 to MAIP 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 13-17 Inspection Date: Tubing OA Packer Depth 49 64 64 64IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE251008120806 BBL Pumped:2.9 BBL Returned:2.7 Friday, November 14, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, November 14, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-17 PRUDHOE BAY UNIT 13-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/14/2025 13-17 50-029-20718-00-00 182-026-0 N SPT 8217 1820260 2054 334 419 430 434 0 0 0 0 REQVAR P Adam Earl 10/8/2025 MIT-IA tested as per AIO 4F.006 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 13-17 Inspection Date: Tubing OA Packer Depth 49 2503 2353 2283IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE251008121158 BBL Pumped:2.7 BBL Returned:2.3 Friday, November 14, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-17 PRUDHOE BAY UNIT 13-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/05/2023 13-17 50-029-20718-00-00 182-026-0 N SPT 8217 1820260 2250 173 2460 2349 2315 0 0 0 0 REQVAR P Sully Sullivan 10/17/2023 MIT-T Per AIO 4F.006 to MAIP. 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 13-17 Inspection Date: Tubing OA Packer Depth 106 117 116 116IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS231018164229 BBL Pumped:2.3 BBL Returned:2 Tuesday, December 5, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9 9 MIT-T Per AIO 4F.006 James B. Regg Digitally signed by James B. Regg Date: 2023.12.05 15:42:50 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-17 PRUDHOE BAY UNIT 13-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/05/2023 13-17 50-029-20718-00-00 182-026-0 N SPT 8217 1820260 2250 198 328 370 380 0 0 0 0 REQVAR P Sully Sullivan 10/17/2023 MIT-IA per AIO 4F.006 to MAIP. 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 13-17 Inspection Date: Tubing OA Packer Depth 107 2491 2326 2252IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS231018165158 BBL Pumped:2.8 BBL Returned:1.6 Tuesday, December 5, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MIT-IA per AIO 4F.006 James B. Regg Digitally signed by James B. Regg Date: 2023.12.05 15:39:26 -09'00' MEMORANDUM TO: Jim Regg I/ P.I. Supervisor " FROM: Matt Herrera Petroleum Inspector Well Name PRUDHOE BAY UNIT 13-17 Insp Num: mitMFH210926093413 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, October 7, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-17 PRUDHOE BAY UNIT 13-17 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-20718-00-00 Inspector Name: Matt Herrera Permit Number: 182-026-0 Inspection Date: 9/25/2021 �- Packer Depth Well 13-17 Type Inj ^ N -ITVD 8217 Tubing PTD 1820260 Type Test SPT est psi 2026 IA BBL Pumped: 1.3 ` BBL Returned: 1.4 - OA Interval REQVAR P/F P Notes: MIT -IA Performed to MAIP per AIO 4F.006 ✓ Pretest Initial l5 Min 30 Min 45 Min 60 Min 537 649 661 661 �T -- 200 -- 2502 2351 2284 0 0 0 0 Thursday, October 7, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg (1j 'vl ] 1T1I z P.I. Supervisor I ` FROM: Matt Herrera Petroleum Inspector I Well Name PRUDHOE BAY UNIT 13-17 Insp Num: mitMFH210926081756 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, October 7, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-17 PRUDHOE BAY UNIT 13-17 Src: Inspector Reviewed By� P.I. Supry Comm API Well Number 50-029-20718-00-00 Inspector Name: Matt Herrera Permit Number: 182-026-0 Inspection Date: 9/25/2021 , Notes: MIT -T Performed to MAIP per AIO 4F.006 ✓ Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8217 Tubing 1 2533 ' 2467 2440 - 2026 IA 201 290 287 283 - - l.a OA 0 0 0 0 P Thursday, October 7, 2021 Page 1 of I Packer Well 13-17 Type In' N ' TVD PTD 1820260 Type Test SPT ITest psi BBL Pumped: 1.4 ' BBL Returned: Intervalt REQVAR P/F Notes: MIT -T Performed to MAIP per AIO 4F.006 ✓ Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8217 Tubing 1 2533 ' 2467 2440 - 2026 IA 201 290 287 283 - - l.a OA 0 0 0 0 P Thursday, October 7, 2021 Page 1 of I MEMORANDUM State of Alaska Permit Number: 182-026-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg J P.I. Supervisor 2�p� Il//�j`(j DATE: Thursday, November 7, 2019 SUBJECT: Mechanical Integrity Tests 66 444 BP Exploration (Alaska) Inc. FROM: Guy COOK Petroleum Inspector 13-17 PRUDHOE BAY UNIT 13-17 Ste: Inspector Reviewed By: p P.I. Supry ffs- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-17 API Well Number 50-029-20718-00-00 Inspector Name: Guy Cook Permit Number: 182-026-0 Inspection Date: 10/30/2019 1 Insp Num: mi[GDC191031074856 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well t3 -n "Type Inj N 'per sv7 Tubing 4 3200 - 3098 3055 - PTD 1820260 Type Test SPT Test psi 2054 IA 58 64 67 68 BBL Pumped: 2.3 BBL Returned: 2 OA 0 0 0 0 Interval REQVAR /Fi P �✓ Notes- AIO 4F.006 MIT -T Pressure test completed with Little Red Services pump truck and calibrated gauges. Thursday, November 7, 2019 Page I of 1 MEMORANDUM State of Alaska Inspector Name: Jeff Jones Alaska Oil and Gas Conservation Commission TO:Jim Regg p /� DATE: Thursday, October 17, 2019 p�q y P.I. Supervisor l �� (r I SUBJECT: Mechanical Integrity Tests l BP Exploration (Alaska) Inc. 13-17 FROM: Jeff Jones PRUDHOE BAY UNIT I3-17 Petroleum Inspector Well 13-17 'Type Ste: Inspector W Reviewed By: 8217 - P.I. Supry J -5p— NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-17 API Well Number 50-029-20718-00-00 Inspector Name: Jeff Jones Permit Number: 182-026-0 Inspection Date: 10/7/2019 ' Insp Num: miUJ191009090612 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-17 'Type Inj W VD 8217 - Tubing 1127 - 1126 1123 1122 - PTD 1820260 ' Type Test SPT Test psi 2850 IA 137 3200 - 3030 - 2956 " BBL Pumped: 2.9 , BBL Returned: 2.7 OA 109 407 394 - 390 - Interval REQVAR P/F P Notes: 2 yr MIT -IA to MAIP AA 4F.006. I well inspected, no exceptions noted. Thursday, October 17, 2019 Page 1 of 1 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, November 8, 2017 4:19 PM To: AK, OPS EOC Specialists;AK, OPS FS3 DS Ops Lead;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL;AK, OPS FS3 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; G GPB FS3 Drillsites; Odom, Kristine;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua; Worthington,Aras J; Regg,James B (DOA) Subject: OPERABLE: Injector 13-17 (PID# 1820260)AOGCC MIT-T Passed All, Injector 13-17 (PTD#1820260)was made Not Operable on 10/29/17 due to a lapse in the AOGCC required MIT-T. On 11/07/17 slickline set a tubing tail plug and fullbore performed a passing AOGCC witnessed MIT-T to 3636 psi.This well now satisfies requirements outlined in AIO 4F.006 for its continual operation.At this time the well is reclassified as OPERABLE. Please respond with any questions. Andrew Ogg Well Integrity Engineer SCANNED 1, BP Global Wells Organization-Alaska Office:907-659-8110 Cell:307-399-3816 Fro • AK, GWO Well Integrity Engineer Sent: S , October 29, 2017 2:40 PM To: AK, OPS •- Specialists;AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Field OTL; AK, OPS FS3 OSM; AK, RES GPB . ,Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; G GPB FS3 Drillsites; Odom, Kristine; 'chris.walla .Iaska.gov' Cc: AK, GWO Completions Well In -. ity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity ' Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hi.•- , Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, c 'ver R; Tempel, Joshua; Worthington, Aras J; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: NOT OPERABLE: Injector 13-17 (PTD# 1820260) CC MIT-T test will lapse due to surface work All Injector 13-17 (PTD# 1820260)operates under AIO AF.006 for having a shallow p. ker depth. The well requires an AOGCC witnessed MIT-T and MIT-IA every two years as a condition of continual oper. 'on. The MITs are due by the end of October this year, but due to ongoing surface work the MIT-T will not be completed b e required due date. At this time the well is reclassified as Not Operable and must remain shut in. Once surface repairs ar•,complete and SIMOPs issues are resolved the AOGCC MIT-T will be rescheduled. 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,November 08,2017 TO: Jim Regg P.I.Supervisor - 111011 7 SUBJECT: Mechanical Integrity Tests (( ` BP EXPLORATION(ALASKA)INC. 13-17 FROM: Brian Bixby PRUDHOE BAY UNIT 13-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-17 API Well Number 50-029-20718-00-00 Inspector Name: Brian Bixby Permit Number: 182-026-0 Inspection Date: 11/7/2017 Insp Num: mitBDB171108075120 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-17 I TypeTubing T e In� N �TVD 8217 1862 3747 - 3669 - 3636 PTD 1820260 Type Test SPT Test psi, 3050 _ IA 2375 - 2538 - 2519 - 2509 - BBL Pumped: j 1.4 ' BBL Returned: 1.9 - OA 0 0 0 0 Interval REQVAR p/Ii' P Notes: AIO 4F.006 The MIT-IA was completed on October 13th and witnessed by Bob Noble.This is the MIT-T. SCANNED r .;-1 2 O 2,1 ;', Wednesday,November 08,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, October 29, 2017 2:40 PM To: AK, OPS EOC Specialists;AK, OPS FS3 DS Ops Lead;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL;AK, OPS FS3 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; G GPB FS3 Drillsites;Odom, Kristine;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua; Worthington,Aras J; Regg,James B (DOA) Subject: NOT OPERABLE: Injector 13-17 (PTD# 1820260)AOGCC MIT-T test will lapse due to surface work All Injector 13-17 (PTD#1820260)operates under AIO AF.006 for having a shallow packer depth. The well requires an AOGCC witnessed MIT-T and MIT-IA every two years as a condition of continual operation. The MITs are due by the end of October this year, but due to ongoing surface work the MIT-T will not be completed by the required due date. At this time the well is reclassified as Not Operable and must remain shut in. Once surface repairs are complete and SIMOPs issues are resolved the AOGCC MIT-T will be rescheduled. Please respond if in conflict, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED Eb 2 WO 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Tuesday,October 17,2017 P.I.Supervisor q 1 0/1-7( SUBJECT: Mechanical Integrity Tests l (7 BP EXPLORATION(ALASKA)INC. 13-17 FROM: Bob Noble PRUDHOE BAY UNIT 13-17 Petroleum Inspector Src: Inspector Reviewed By�:i� P.I.Supry J 31-a" NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-17 API Well Number 50-029-20718-00-00 Inspector Name: Bob Noble Permit Number: 182-026-0 Inspection Date: 10/13/2017 Insp Num: mitRCNl71013170511 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-17 - Type Inj G "11TVD 8217 Tubing 2827 2825 2823 2812 I PTD 1820260 Type Test SPT yp Test psi 3100 - IA 3284 3750 - 3600 3505 BBL Pumped: 0.3 BBL Returned: 2.9 OA 54 58 - 56 . 54 Interval REQVAR P/F P Notes: AA 4F.006 for shallow packer depth.MIT-ia every 2 years to max injection pressure of 3100 psi.Second attempt on this well today. Tuesday,October 17,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,October 17,2017 Ree P.I.Supervisor � j 7 117 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 13-17 FROM: Bob Noble PRUDHOE BAY UNIT 13-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-17 API Well Number 50-029-20718-00-00 Inspector Name: Bob Noble Permit Number: 182-026-0 Inspection Date: 10/13/2017 Insp Num: mitRCN1710I3162704 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-17 Type Inj G " TVD 8217 Tubing 2835 2831 ' 2825 2820 PTD 1820260 Type Test SPT Test psi 3100 - IA 80 3740 ' 3456 - 3320 - BBL Pumped: 3.6 BBL Returned: OA 31 60 - 58 - 55 IntervalT REQVAR IP/F F Notes: AA 4F.006 for shallow packer depth.MIT-ia every 2 years to max injection pressure of 3100 psi.This is the first test and it failed due to 10% bleed off.The well was pressured up again for a second attempt. SCANNED 1 ` j6 LOA Tuesday,October 17,2017 Page 1 of 1 • c4 4c,1 c v a to o V _o a 'V > l ro VQ X ca p_ C \o� r . Q 1 li O Lit W r-z a) L L C won F- >.o ro O O _Jot CT) 55 4 a • >@ E • C o �; - QQ It Q I ,0 o �� tn ° v o E s coQ � L J I _ aNN V) CU OU O N ' L0 co 2 .aQZ ❑ ❑ ❑ ❑ E - T- 111 Q �: M N r O @ a) > a) Q f. v E O ? cciiii V Y CD ❑ ❑ ❑ ❑ ❑ ❑ +-,• V L L 0- W J J J J J J ca N V } W W w W W W pip ro O 0 ^'t F- LL LL LL LL LL LL ',-.7) a) E 'O v"i 0 LU L0 Fa- aaaaQa 0- -0 0 toC C '8 ❑' LL LL LL LL LL LL v L N 4 ) C0 CC w• C) M 4 Q O v v CS) E � ro " Zu aYo r_, O c0aci a) c t ... 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J r M r` U N NEZ `'�. a s N W o o a)•p� r 1 ri n C til n co ar rot` a a RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON .J[-\N 0 5 2016 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed O 0 C Off' Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well 0 Other:Cement OA PC Leak m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 182-026 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service Ed 6. API Number: 50-029-20718-00-00 7. Property Designation(Lease Number): ADL 0028311 8. Well Name and Number: PBU 13-17 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11551 feet Plugs measured 11360 feet true vertical 9160 feet Junk measured feet Effective Depth: measured 10043 feet Packer measured 10501 feet true vertical 8006 feet Packer true vertical 8346.97 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 40-120 40-120 1530 520 Surface 2468 13-3/8"72#L-80 39-2507 39-2507 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet LB h Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) No SSSV Installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): 3200'-10309' Treatment descriptions including volumes used and final pressure: 385 Bbls 15.8 ppg Class G Cement,34 Bbls Fresh Water,69 Bbls 1%Slick KCL,49 Bbls 50/50 Methanol,10 Bbls PowerVis,1408 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 9636 2 1974 Subsequent to operation: 12637 340 634 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service EZf Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG Il GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-108 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,AAA/ Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 1/5/16 Form 10-404 Revised 5/2015 ,jC.-RBDMS JAN 0 61018 Submit Original Only ! ! cD Q o 0 0 0 0 0 0 0 0 N I� CO CO r O N CO O CO I� O 'Cr LO O N L() O N LO LO N- N- CO h- t.) 'i 0 0 0 0 0 c 0 0 0 6. CO CO N- CO CO CO V CO LU C) CO .- NN--I� CO r V CO CO I� co CO f� CO O N- CO CA O LU O(NJ O C) O LU N CO in L() r LO CO CO N r = CON N N. CO CO CA CD CO H CO CO O) LO O C) N- O N L() CO - LU COCOCONNCOCOCO N- CO CO CO 4.4C CSO O LN O Lf) CO N Ln CO CO M LC) LO M CO N O O O r O r r r r C.) , I . 41 M � r ' O 6) N- a) V CO L(7 M LO V CO MCO O O O M CO a r r r r • CO a LO D o rn O o CD 00 cy) Co O Co V J , .11 OO , J O CoCO • cb = N *k (n CO J CO •NN CI) 'Cr 'cr o r r O) CO N - N - V Nc in o - ---- 0,5CD In LU 4." 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A m S g m ƒ § d ƒ . d T— o 5 ƒ d 1 .20 / ImO off $ I- \ � �� $ / \ , ii - t � � �« o � / / \ < o -0 / o / 0 / \ / / O / 2 il _ ¢ il q il p_ I I $ - cq - Eo / � clod - / d / •§ �� 2 / \ 2f �� \ 2. E CI / / 2 \ / j / \ , % G > / 0 _/ � > gzzmcU) c m ® O � / % / E� / c / / gym em \ ƒ § / E $ 0 / Ni- ? > / ƒ / .$ c $ $ o = $ a 7 2 2 o n w o o e m - o �� = g �� 2oIIc0 �� gd / \ 22 5- ( / 2 / $ II / P " O c Il O \ II $ \ f / co $ $ £ ? > - o > c > o > •@o 6aPo ® a / \ m 6 .gm6 = g6 = m SZmo .- ± El - 2 / CO / 0 0 0 0 / / /_ / 772 / / 2 / 7 / / 7 C CO t A CO a & \ / (N W LLIfAD= GRAY 1 i 1 ? aam WHEN oN Mi wa L REQUIRES A SSSV WHENACTUATOR= BAKER C ON MI"" OKB.ELEV= 87' I BF.ELEV= NA KOP= 3000' _"CONDUCTOR H ? Lai 2238' H4-112"CAMCO BAL-O SSSVN,ID=3.812" Max Angle= 57°@ 6975' _#, , Datum MD= 11187' ID= i Datum ND= 8800'SS ZA 13-3/8"CSG,72#,L-80 BTC,ID=12.347" —I 2507' TOC IN IA(06/19/15) — —3200' i �+yf,, ,#. 1 44 w.> 9-5/8"CSG,47#,L-80 XO TO SOO-96 BUTT __t 9894' 1�" •� �1 •4 4 TUBING PUNCH(05/10/15)1-1 10070'-10075' L`o TUBING PUNCH 2'@ 4SPF(04/22/15) — 10218'-10220' *,4 .:.,r.:4:4 �r77 ' 1 44 4,4* l.Minimum ID = 3.725" @ 10309' t1 4-112 HES XN NIPPLE •; �C 10309' 4-1/2"HES XN MP,D=3.725" r.. TOP OF 4-1/2"LNR -{ 10309' j 7''"• •.1 10309' 9-5/8"X 7"BKR ZXP Fl(R 7 .:fir w frlEf3ACK SLV,D=6.283" 3211 re: 4- = ' 10323' H9-5/8"X 7"BKR HMC HGR,D=6.31" 1111 •01� 1 10331' —16.25"SEAL BORE ECT,D=4.70- 1111 1111 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958"H 10347' • 11141 `4/� 10350' Hr X 4-112"XO,ID=1958" 1 1 111 11111 ,1111 TOP OF 7"LNR —1 10551' 11111 ,111. 11 ,14 9-5/8"CSG,47#,SOO-95 BUTT,D=8.681" --1 10848' I* 11 104 14 I* II I11 PERFORATION SUMMARY 44 111� REF LOG:BHON 04/03/82 1111 ,11 CS ANGLE AT TCN'PERF;38"@ 11050' 1111 111 ►111 111 Note:Refer to Production DB for historical perf data 1111 41. SIZE SPF INTERVAL Cpn/Sgz SHOT SQZ 1111 ,1� 2-1/2" 4 11050-11105 S 08/04/82 09/22/01 11 14 3-3/8" 4 11054-11064 0 06/29/03 ►111 ,1. 3-3/8" 4 11074-11084 0 06/29/03 I* /I1 14 3-3/8" 4 11094-11104 0 06/29/03 1111 .. 3-3/8" 4 11114-11124 0 06/29/03 ►111 L 2-1/2" 4 11129-11159 S 08/04/82 09/22/01 I14 3-3/8" 4 11132-11142 0 06/29/03 ►114 I I 3-3/8" 4 11146-11156 0 06/29/03 1111 `8�' 3-3/8" 4 11162-11182 0 06/29/03 111 2-1/2" 4 11166-11186 S 08/04/82 09/22/01 1..1 3-3/8" 4 11188-11198 0 06/29/03 1114 3-3/8" 4 11202-11220 0 06/28/03 ►111 2-1/2" 4 11202-11272 S 08/04/82 09/22/01 ►111 3-3/8" 4 11224-11234 0 06/28/03 �1�1 ^_ _ 3-3/8" 4 11248-11264 0 06/28/03 1114 1` 11359' --ICBP(06128/03) 3-3/8" 4 11370-11410 C 01/29/02 1111. FID — 11429' '►11111111'/1 1',11111/11110 11/1111111111q 4-1/2"LNR, 12.6#,L-80 BTC,.0152 bpf,D=3.958" —I 11473' 1111111/111/1/1/14 7'LNR,29#,L-80 BUTT,.0371 bpf, ID=6.184" 11550' 11/111/11/111111* H 1111//1/1/1/1/1/4 TD H 11551' .1•.-1.1.1.1.�1.1 DATE REV BY C) E�tTS _ P f DATE REV BY 0014/ENTS PRUDHOE BAY UNIT 04/14/82 OCW6.5 ORIGINAL COMPLETION 07/15/15 AL.MJIvD CMF IA&RETAINER(06/18-19/15) WELL 13-17 12/25/01 [3.16 RWO 07/15/15 M-VJWD MILLED C MT/REFANER&CSPS PERMIT No:'1820260 04/15/15 NLW/JMD PULLED PXN '08/31/15 JTG/JPoD SET XXN RUG(08/19/15) AR No. 50-029-20718-00 04/20/15 MGB/PJC SET(3)CBFVS(04/20-04/21/15) 10/08/15 MGS/JMJ PULLED XXN RUG(10/07/15) SEC 14,T1ON,R14E,2703'FNL&1634'RI 04/22/15 MGB/PJC TBG PUNCH — 05/10/15 GTW/PJC TBG PUNCH BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, December 01, 2015 7:48 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA); Pettus, Whitney Subject: UPDATE December 01, 2015: UNDER EVALUATION:Injector 13-17 (PTD #1820260)Well Approved for Continued Injection Attachments: Injector 13-17 (PTD #1820260) TIO and Injection Plot.doc All, Injector 13-17 (PTD#1820260) can remain in service following the water flow log performed on December 01, 2015. The well will remain Under Evaluation until an Administrative Approval (AA) can be approved for continued injection post annulus repair. Plan Forward: SCANN 1. Operations: Keep on injection as needed 2. Downhole Diagnostics: Perform AOGCC MIT-IA as required following AA approval 3. Well Integrity Engineer:Additional diagnostics as needed Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator VVCkpa zaton WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From:-AK, D&C Well Integrity Coordinator Sent: Sat`u day, November 28, 2015 8:05 AM To: AK, OPS FS3 OAK-OPSFS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent-AK-742K Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity ineer• AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; 'Regg, Jame DOA)'; Sayers, Jessica; Dickerman, Eric; AK, D&C Wells Eline Coordinator; Do, Matthew; Broussard, Mike G Subject: UNDER EVALUATION: Injector 13-17 (PTD #1820260) Place on Injection for Compliance Log • • Injector 13-17 (PTD #1820260) TIO Plot 1 Wet 13-17 4,000 - 3.000 f Tbg f-IA 2,000 -a-OA 00A -0--000A -On 1,000 ii 'IIIita , a1f 03/01/10 05/02/10 07/03/10 09/03/10 11/04/10 01/05/11 03/08/11 05/09/11 07/10/11 Injector 13-17 (PTD #1820260) Injection Plot Wet 13.17 3600, - 1I 3.,00. 3,200 -18,000 3,000 +I 2,800- 1 I -16,000 2,600- 11) t1 11 2,400- -14,000 2,200- L. —WHIPI` ?1�J 11.11 :12,OOD 2,000- +'i�V� yY:�.C�_ lf. SW 1800- -tOOWi —W 1.600- - a —n' 400- l -6,000 B _O 1.200- r.. 1,000. -6,000 r -4,000 600 400- 1_,______:-2.000 — elL--- 200- / ;'�-ter—� 03/01/10 05/02/10 07/03/10 0913/10 11/04/10 01/05/11 03/98/11 059)9/11 07/1011 • i Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, December 01, 2015 6:57 PM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; Regg, James B (DOA) Subject: Permission for continued operations Injector 13-17 (PTD #1820260) while waiting on AA approval Chris, As per our discussion, The water flow log for 13-17 (PTD#1820260) indicated no flow behind pipe post annulus cement squeeze. Based off the results of the log, BP intends to keep this well Under Evaluation on water injection while waiting on the administrative approval (AA) to be finalized. An AA request will be submitted by week's end. The well is currently on day 3 out of 28 on the Under Evaluation clock. A follow up email will be sent at the conclusion of this evaluation period; if necessary, it will include a request to extend the monitoring period beyond the current 28 day clock if the AA paperwork is still in the approval process. Please recommend an alternative plan forward if this does not meet expectations. Thank you, Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sen Saturday, November 28, 2015 8:05 AM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superinten ent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&ADHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; 'Regg, James B (DOA)'; Sayers, Jessica; Dickerman, Eric; AK, D&C Wells Eline Coordinator; Do, Matthew; Broussard, Mike G Subject: UNDER EVALUATION: Injector 13-17 (PTD #1820260) Place on Injection for Compliance Log All, Injector 13-17 (PTD#1820260) is a WAG injector with a known PC leak at 9647' MD that was mitigated by an inner annulus cement squeeze on June 19, 2015. A subsequently passing MIT-IA to 4000 psi was performed post squeeze on October 03, 2015 demonstrating two competent barriers to formation. In order to pursue administrat.I a approval (AA) for continued operations of the well, an initial water flow log will be run in order to verify that there is no significant flow • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, November 28, 2015 8:05 AM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou,Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Regg, James B (DOA); Sayers, Jessica; Dickerman, Eric;AK, D&C Wells Eline Coordinator; Do, Matthew; Broussard, Mike G Subject: UNDER EVALUATION:Injector 13-17 (PTD#1820260) Place on Injection for Compliance Log Attachments: Injector 13-17 (PTD#1820260) TIO and Injection Plot.doc All, Injector 13-17 (PTD#1820260) is a WAG injector with a known PC leak at 9647' MD that was mitigated by an inner annulus cement squeeze on June 19, 2015. A subsequently passing MIT-IA to 4000 psi was performed post squeeze on October 03, 2015 demonstrating two competent barriers to formation. In order to pursue administrative approval (AA) for continued operations of the well, an initial water flow log will be run in order to verify that there is no significant flow behind pipe. At this time,the well is reclassified as Under Evaluation to facilitate compliance diagnostics. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1. Operations: Place well on injection 2. Electric Line: Once thermally stable, perform water flow log 3. Well Integrity Engineer:Additional diagnostics as needed SCANNED AUG 1 8 2016. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, August 3E-2011_12:6.9 PM To: 'Maunder, Thomas E (DOA)'; 'ReggJames B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D&C W tt-Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Catron, Garry R (SAIC) Cc: AK, D&C Well Integrity Coordinator; Clingingsmith, Mike J (Swift); Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Injector 13-17 (PTD #1820260) Well Due for AOGCC 4 ear MIT-IA, Pending Flowline Repairs • • Injector 13-17 (PTD #1820260) TIO Plot Well:13-17 4,000 - 3,000 f Tbp -o—IA 2000Il —�0A 00A I +000A Ii On 1 1,000 kir I: il il 03/01/10 05/02/10 07/03/10 09/03/10 11/04/10 01/05/11 03/08/11 05/09/11 07/10/11 1 Injector 13-17 (PTD #1820260) Injection Plot Wet 13-17 3.600 - 3.400 I :20,OW 3200 ff -18.000 3100 II 2.800 I -16000 2.600 ` - 2.400- -14000 2.200- ppp o. 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CO O O O N CO (O 0) M C �L M 0 C) N 0 N M OD E m A 72 U) 0 Tr (O N N- CD U) U) •N 0 r` M N N O O O M N ENNNNNN NNN u N Ch O O CI) CA c O CA CA O _0 p -_ NNNNNNNN N Q1 0 0 0 0 0 O 0 0 0 O O O O O O O O O U) U) U) U) U) U) IA U) U)Om CO c w 3 C) — $ _ iZ O 0 F E u U OD,y,L W a+ Q i .0 it Q O W M m N m a N f0 ro Y a d0 M +..;.' Z _ In M N N !"' E ar F. ^ N N L. d man s D ry w J a (� 0o r a E Z a) roi O y a d 3Ak F` v a C.).2 L._ a c vt2 0 2-(17 -2,5163WELL LOG TRANSMITTAL -11 (RECEIVED DATA LOGGED PROACTIVE DIACINOSTIC SERVICES, INC. APR 1 g 2015 5/&/2016A ( � 2015 K.BENDER AOGCC To: AOGCC Makana Bender 333 W. 7th Ave SCANNED .'L'N p ;1,{-1 Suite 100 Anchorage,Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MU) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. Anchorage,AK 99508 gancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 18-Sep-15 13-17 BL/ CD 50-029-20718-00 2) ***Replacement CD*** 2b03(0. Metact-ozei4) at Signed : ''_/ Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM DWrchrves\IvtasterTemplateFJes\Templates\Distnbution\Transn ttaISheets\BP_Transmit docx • OF T4� rw\,\\1�j,s� THE STATE Alaska Oil and Gas 7/4"; �.;,-s��_ �, ofALAsKA Conservation Commission '• t itit_-4,,: 333 West Seventh Avenue Ilea W. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276 7542 www.aogcc.alaska.gov Irwin Chou CO' �/(�, Production Engineer P BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-17 Sundry Number: 315-108 Dear Mr. Chou: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ij-)—P- rft/-1, _ Cathy P Foerster Chair DATED this day of March, 2015 Encl. • RECEIVED STATE OF ALASKA FEB 2 5 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 3 1 -�l-� (S APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrdl❑ Perforate New Pool❑ Repair WellE • Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate El Pull Tubing❑ Time Extension❑ , Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate 1:1 Alter Casing❑ Other @Crn(,?/O,4Q 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number. ,1'4/cct,L. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 182-026-0 • 3.Address: Stratigraphic ❑ Service LI• 6.API Number. P O.Box 196612,Anchorage,AK 99519-6612 50-029-20718-00-00• 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU 13-17 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number). 10.Field/Pool(s). ADL0028311 • PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured). Junk(measured): 11551 • 9160 10309 8203 10309'/11360' None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 39.5-119 5 39.5-119.5 Surface 2468 13-3/8"72#L-80 39-2507.33 39-2507.26 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ '13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 2 - 14 Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended El 16 Verbal Approval. Date: WINJ ❑ GINJ ❑ WAG El , Abandoned El Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Irwin Chou Email Irwin.Chou@BP.Com Printed Name Irwin Chou Title Production Engineer Signature Phone 564-5538 Date Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 15^ /O is' Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: Spacing Exception Required? Yes El No Cil Subsequent Form Required: is — 4 G L, 91:9,t4-- APPROVED BYApproved by: COMMISSIONER THE COMMISSION Date• 3 . ?,S-l5" hr 3////1 s OD IGINpAiLis r�� 3-�s-4s .�; , 1\ dAt " nt �� �tForm 10-403 Revised 10/2012 valid for 12 months from the dat f approval. Submit Form and Attachments in Duplicate RBDMS- APR • 2 7015 ,.e. 44Glf- to -o00 °) 000000 m V 00 0 CO OD OD 0o DO co = J O J J ss J Cq N Q 0 0 0 0 0 0 0 0 O N O Cp r O N I� O O I� O V In O CO to N O V LO 10 I- N- N r-- C)U ', 000000000 CO I,- to co CO CO CO V n to co r CV V r 6) V N- CO r CO CO N- CO CO CO N- W O to co co O) O) co co N- N- 00 00 O co O 10 N CO O to t1) O CO N r r o N co I- 00 (ID O) O) NtCb I- Q O co co O) to ~ O I- O) N to CO O) Io �t COfn 'Cr CO COCVCV co CO CO Cr) CO L E a) EN- N C� fn co Cr)co OD to O co vJ C� 0 `- m O O r r N O co CD 2 r r r r r L _ 03 < E- O I- O7 V to CD to U 0 M co 23 0 0 M M M C r r r G COp O OD O O CIO 0 CO 00 J O O J CO J J N = *k W J CO J N C(O - Cn C COV r N \ r N tJ M fM v- V t17 LO O7 M O co Cr)O LC) r N O CO a) QO O V r Or N '- J r W W CC CAO00 713 U W W LU U U p CC CC CC a u Z Z Z W W W W W Cp Cp :71 U Z Z J J J C) Perforation Attachment ADL0028311 Well Date Perf Code MD Top MD Base TVD Top TVD Base 13-17 9/21/14 BPS 11050 11054 8767 8770 13-17 9/21/14 BPS 11054 11064 8770 8778 13-17 9/21/14 BPS 11064 - 11074 8778 8786 13-17 9/21/14 BPS 11074 11084 8786 8794 13-17 9/21/14 BPS 11084 11094 8794 8802 13-17 9/21/14 BPS 11094 - 11104 8802 8809 13-17 9/21/14 BPS 11104 11105 8809 8810 13-17 9/21/14 BPS 11114 - 11124 8817 8825 13-17 9/21/14 BPS 11129 - 11132 8829 8831 13-17 9/21/14 BPS 11132 11142 8831 8839 13-17 9/21/14 BPS 11142 - 11146 8839 8842 13-17 9/21/14 BPS 11146 11156 8842 8850 13-17 9/21/14 BPS 11156 - 11159 8850 8853 13-17 9/21/14 BPS 11162 - 11166 8855 8858 13-17 9/21/14 BPS 11166 \ 11182 8858 8871 13-17 9/21/14 BPS 11182 11186 8871 8874 13-17 9/21/14 BPS 11188 - 11198 8875 8883 13-17 9/21/14 BPS 11202 11220 8886 8900 13-17 9/21/14 BPS 11220 - 11224 8900 8904 13-17 9/21/14 BPS 11224 11234 8904 8911 13-17 9/21/14 BPS 11234 1 11248 8911 8922 13-17 9/21/14 BPS 11248 - 11264 8922 8935 13-17 9/21/14 BPS 11264 _ 11272 8935 8941 13-17 9/21/14 BPS 11370 11408 9018 9048 AB ABANDONED 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 Packers and SSV's Attachment ADL0028311 Well Facility Type MD Top Description TVD Top 13-17 PACKER 10343 7" Baker ZXP Top Packer 8228 13-17 PACKER 10551 7" Liner Top Packer 8385 tip Objectives The goal of the cement job is to repair a PC leak at 9,467' MD. New cement top will be -3100' MD. Contacts: Michael Hibbert Irwin Chou 564-4351 (w) 907-564-5538 (w) 903-5990 (c) 907-632-3992 (c) Job Notes • Cement Specifications are shown below. Note that the Key Parameters are listed; the Key Parameters are the main items to get correct for the cement blend. The other parameters listed should be checked- if they are out of the specified range, the blend should be retested. • There is no leak in the tbg. The well has passed various MIT-T's and recent caliper shows tubing in good condition. • LLR for IA is 12.53 GPM or 0.3 bpm at 1645 psi. • BHCT is estimated to be 170F. • BHST for 13-17 averages 178F. Cement Calculations volume Class G 385 bbls Total cement to pump 385 bbls WCTOC - Ft. Safety - Ft. Volume between CBP and Retainer bbls Key Class G- Typical Properties Parameters Ppg: 15.8 ppg. Field blend to be =lab ppg +1- 0.1 ppg Slurry Temperature: between 80° and 110°F API fluid loss: 80 - 120 cc Thickening Time: Minimum 9 hours 1 Compressive Strength: 2000 psi 2 Plastic viscosity: 25 - 45 cp Yield point: 5 - 15 Ibf/100ft2 Cement thickening time: Mix on the fly Activity Time(hours) Cement displacement 6 Cement contamination 1 Safety 2 Minimum required thickening time: 9 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 90 0 2:30 170 7500 6:00 178 7500 10:00 178 7500 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 4-1/2"tbg 0 10320 4-1/2" 12.6# 3.958" 0.0152 10320 157 4-1/2"x 9-5/8" annulus 0 10320 9-5/8"47# 8.681" 0.0536 10320 553 Slickline 1. MIRU SL. Pull PXN plug from 10,309'. 2. D&T at WSL discretion. RDMO. 1. MIRU EL. 2. Set 4-1/2" WTF composite bridge plug @ 10,295' (in bottom of first 40' joint above X-nipple @ 10,309'). See attached tubing tally. 3. MIT-T to 2500 psi to verify plug set. 4. Punch tubing @ 10,285'. 2' tubing punch centered @ 10,285'. 5. Verify circulation down tubing and up annulus. Determine return ratio. 6. RDMO. 2 Coil 1. RU 1.75" CTU. If possible rig up micromotion to IA returns. This will help determine if the PC leak is taking any losses and track the cement top in the IA. 2. MU 4-1/2"WTF one-trip composite cement retainer. a. This is a one-trip retainer. Tag CBP at —10,295'. PUH 25' and set retainer. 3. Establish circulation down CT and up IA to tanks. Verify coil backside is SI. Pump the following fluids down the coil into the IA: a. 220 bbls of warm diesel (have LRS preheat to 140 or heat/pump on the fly) b. 5 bbls fresh water spacer c. 385 bbls of cement per attached design. 4. Unsting from cement retainer w/ 1-2 bbls of cement still in the CT. 5. Pump 1.25# Powervis and circulate remaining cement to tanks. 6. Leave some 1.25# Powervis on top of retainer and circulate while POOH. Slow down while jetting across nipple at 1988'. 7. RDMO. Fullbore 1. WOC 5 days — MIT-IA to 2500 psi. LLR if fails. Coil 1. MIRU CTU. 2. MU —3.70"junk mill. RIH and tag retainer at —10,270'. PUH 50' and begin pumping. 3. Mill 25', within a few feet of CBP. Pump 10-20 bbl gel pill, circulate bottoms up to prevent solids on backside from bridging off if returns are lost when breaking through CBP. 4. Mill CBP and push to bottom. POOH. 5. RDMO. Slickline 1. Run memory SCMT per logging sheet in SOR. 11:14Activ osi,..,_ LEAKPOINTIm SURVEY .g. .4. .116 sf.eii, id' 4E_ imp „ xTu - GR - CM. - PRES - TEMP - LPT 18 - Sept - 2014 PiliciAc-riwii DiAiceimisbik. sit Kw ic e T, CS = Company BP EXPLORATION (ALASKA), INC. ,--Z. 2 Well 13 - 17 FINAL ze Field PRUDHOE BAY , = Borough NORTH SLOPE State ALASKA .7',7s rd 4.1 01-- Cl° 8- Surface Location Other Services Til r, 8 cr) 2.576.50' F S L & 1 634 01' FEL NODS a_ co 2o a 03 17- Ci_ Z < SEC: 14 TVVP. 1CN AGE, 14E - Elevation c .c c ca Permanent Datum MSL Eievaacm 0.00' K,B,87.0. 2 if- Log Measured From RKB 87.0 FT Above Perm, Datum D.F.NIA 0 15 Z ci '''' 0 it isi CO API Serial Number 50-029-20718-00 G I N/A Date '117,Siagt-29141_1___ Run Number One P B ID Driller : 11.429' i CIBP 6, 11,359' 'PA f 0 Logger Nat T-- . .ed Bottom Logged Interval 10,474' Top Log Interval Surface Open Hole Size NIA Type Fluid ' Produced Fluids Max Recorded Temp.(deg. F.) 182 Time Wel Rea• 03 FINAL PRINT Time Loqqef on Bottom 5- - Equipment Number SLB REW 12128 Location North Slo•0 Service InvtAce No 14114 ' Recorded By C Goerdt 1 D. Sparks L. Ramirez Witnessed 114 J. Morgan, I D. Stidd Borehole Record . _ ... Tutting Record r Run Number Bit From . To . SizeLB.1 Ft From To '1 4 112 12_60 Surface 10,347' , Casing Record Size LB 1 Ft Top Bottom Surface String 13 30' 72.00 Surface 50 -Prot.String 9 5/8" _ 47 00 Surface 10,848 Liner 1" 29.00 10,651' 11,550' T "Liner 4 ii-2. 12.60 10.350' 11.473' ,. 4 i 7 ), 4 tits.\\............_ 1's i r r , 9403 1 l i r i EMS= 1 i ...... -"•-•-- f i 9'517,0 --._...... Q.._ J.1 st 4 1 1 , i 4-..1-e Spee- ---5 . i I i\- 1 1 96'00 11 , 1 Temperature -Seir-z. Temperature Dfferent al"ernperature--114 -.7. 9 7 0: • \ \ i 1 4' 1 PA. e.1,rot,Tern - . Baseline Temperature ; I — 1 _ I 1 I 9800 C Pressur _ 4. 4 1 f , -,i- ,„ ressure —& 1 --"4 3- 1 I i ._... I I Ii ... ." I. Si _...... 1 0000 ' I E _... ) 4 in 1111-f) ,i 1 ,ffil ew LetikPoint " . A I _ 1 --..t--4. 1111" it clic LeakPoinr" -a • 10200 4 \ i L_ .,... LeekPant Tv -C li. ! 1 I i ' I 10300 ,. — 1 X N" N rip 0 I e : Seal Assy .t.-. t "i . Cress Oirer •we ; 5 I TUBING SUMMARY I1., P•`l 4 ', RIG DOYON 16 Date 12t2312001 WELL# .13-171 • �� TUBING 4 112" L-80 NSCT TBG WT. 12.6# 265 JTS ON RACK 258 JTS RAN 19.50 OKB TO BF 10510.16 FT ON RACK 10274 FT RAN ITEM Description includes: SIZE,TYPE,CONNECTION(JTS#4) _ ID OD LENGTH TOP BOTTOM BAKER SEAL ASSY 3.88 4.5 17.17 10329.89 10347.06 1 - 4 1/2" 12.6#L-80 NSCT TBG PUP 3.958 5.02 9.86 10320.03 10329.89 1 - 4 1/2"12.6#L-80 NSCT TBG PUP 3.958 5.02 9.79 10310.24 10320.03 4 1/2" "XN"NIPPLE(3.725"NoGo) 3.725 5.03 1.21 10309.03 10310.24 1 -4 1/2" 12.6#L-80 NSCT TBG PUP 3.958 5.02 9.07 10299.96 10309.03 203 JTS 4 1/2" 12.6#L-80 NSCT TBG 3.958 5.02 8048.78 2251.18 10299.96 1 -4 1/2" 12.6#L-80 NSCT TBG PUP 3.958 5.02 8.29 2242.89 2251.18 CAMCO SSSV BAL-0 WI DUMMY(2.25°!D) 3.812, 6.062 5.31 2237.58 2242.89 P 41/2"12.6#L-80 NSCT TBG PUP 3.958 5.02 9.81 2227.77 2237.58 54 JTS 4 1/2"12.6#L-80 NSCT TBG PUP 3.958 5.02, 2146.98 80.79 2227.77 P 41/2"12.6#L-80 NSCT TBG PUP 3.958, 5.02 3.69 77.10 80.79 P 4112"12.6#L-80 NSCT TBG PUP 3.958 5.02 9.52 _ 67.58 77.10 P 41/2"12,6#L-80 NSCT TBG PUP 3.958 5.02 19.81 47.77 67.58 1 JT 4 1/2"12.6#L-80 NSCT TBG PUP 3.958 5.02 40.72 7.05 47.77 P 41/2"12.6#L-80 NSCT TBG PUP _ 3.958 5.02 3.88 3.17 7.05 X/O 5 112"NSCC BOX x 4 1/2"NSCT PIN 3.958 . 6.41 1.80 1.37 3.17 TBG HANGER 5.5 12.97 1.37 _ . 1.37 1 6 TREE Y FMC — - WELLHEAD= GRAY I. .Y NOTES_ "'HRS READINGS AVERAGE 125 ppm .ACT!IATOR= BAKER 13-1 7 WI ONMI"'"WELL REQUIRES ASSSV WHEN ON OKB.ELEV= 8T BF.ELEV= NA KOP= 3000' Max Angle= 57°@ 7100' 2238' —14-1/T CAMCO BAL-O SSSVN,D=3.812' Datum MD= 11187' Datum TVD= 8800'SS 13-3/8'CSG,72#,L-80,ID=12.347" —1 250T Minimum ID = 3.725" @ 10309' 4-1/2" HES XN NIPPLE 4,1g 10309' _141/2'HES XN NP,ID=3.725" 9-5/8'X 7'BKR ZXP PKR W/TEBACK SLV,ID=6.283" H 10309' lilts 10309' H4-1/7 PXN PLUG(01/06/15) r F 10323' -19-5/8"X 7'BKR HMC HGR,D=6.31" 1111, ►K1� 10331' —TOP OF BKR SBR, =4.70" 1111 D 1 '1'1' 4-1/2'TBG,12.6#,L-80,.0152 bpf,D=3.958'—I 1034T 11/11 11. •1 10347' --I BTM OF SEAL ASSY,D=3.88-1 11111• 1*4 O••.., 111. 10350' —�7"X 41/2"XO,D=3.958" TOP OF 7'LNR --I 1055V 11 1� x;:111/• 1C 11• .1 111 1I 1 1 9-5/8"CSG,47#,L-80,D=8.681" --I 10848' �1 �. ..• . , 1 PERFORATION SUMMARY 1/ 111 RE=LOG:BRCS ON 04/03/82 •1 �� ANGLE AT TOP PERF:38°©11050' 111 111 Note:Refer to Roduction DB for historical perf data 1� 1I SIZE SPF INTERVAL Opn/Sgz DATE 111 11 2-1/2" 4 11050-11105 S 09/22/01 1/ 11 1 1 11 3.3/8" 4 11054-11064 0 06/29/03 1 1 1 3-3/8" 4 11074- 11084 0 06/29/03 11, 111 3-3/8" 4 11094-11104 0 06/29/03 1/ 111 3-318" 4 11114-11124 0 06/29/03 1• 111 2-1/2" 4 11129-11159 S 09/22/01 1 I 3-3/8" 4 11132-11142 0 06/29/03 1., 3-3/8" 4 11146 11156 0 06/29/03 1 rIml 3-3/8" 4 11162-11182 0 06/29/03 • 1 1 LI 2-1/2" 4 11166-11186 S 09/22/01 '1 I.,�I 33/8" 4 11188-11198 0 06/29/03 11 I 1.6-11 4I 33/8" 4 11203-11220 0 06/28/03 11 2-1/7 4 11202-11272 S 09/22/01 11 r7 3-3/8" 4 11224-11234 0 06/28/03 11 3-3/8" 4 11248-11264 0 06/28/03 11 v. • 33/8" 4 11370-11410 0 01/29/02 MN *i, 11359' --I CBP(06/28/03) 1�✓1111 PBTD — 11429' 1111111111 X1'1 • 4-1/2"LNR, 12.6#,L-80,.0152 bpf,D=3.958" 11473' 11111 ,1 } 11111111/1!1/' 1111111111111111( 111111111 7"LNR,29#,L-80,13=6.184" H 11550' 11111111111111111 TD —I 11551' I �������..../��., DATE REV BY CO LU4TS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/14/82 OCW6.5 ORIGINAL COMPLETION 01/13/15 JMWJM3 RESET PXN(01/06/15) VVELL. 13-17 12/25/01 D-16 RWO PERMT No: 1820260 02/09/11 M3/JM) ADDED SSSV SAFETY NOTE AR No: 50-029-20718-00 03/26/11 JMD/PJC TRIS CO(03/05/11) SEC 14,T1ON,R14E,2703'FNL&1634'FE. 12/17/11 PJC SAY NOTE WAG ON M 09/25/14 MJC'JJM) SET 4-1/2"PXN PLUG(9/23/14) BP Exploration(Alaska) 1T1EE= MU ..._ WELLIEA0 GRAY SAFETY NOT "*•KIS READINGS AVERAGE 126 ppm = ACTUATOR= BAKER C 1 3-1 7 WHEN ON MI"`..WEU.REQUIRES A SSSV WHEN ON MI. OKB.ELEV.= FIT 13F.LLEV= MA KOP= 3000 Max A-ralc= 57"a 7100' 22:16* H4-1r.reAtAtO BL-0 SUSVN,U=3.1312* Datum AU= iiisr L71 Datum TWO= 6805 3$ I3-3194 CSC..726.L-60.U,..-12347"[I--I 260T H-- _, .... Minimum ID= 3.725"a 10309' Leak @ —9,467' MD 4-1/2-HES XN NIPPLE 1030W 1_ 14-112 1-4%XN Poe U3125"1 ..1 5.6"*1"MR I.'. 5.14 VW 1111:14A0(6.1_V,61-6 2113'7--{ 10309' -• I ----- 1030W -4-1,2-Flat PLUG(01/06/15) 1.. 1 10323' 1-19 518"X r 1110-011.11.: 14.,u.,-6.31" I 143 1 Art •• 11# 10M31' —1 TOPOE 131B1S8R,lo 444 .4 . 44 14 [4.142-EUG.120 6' .66.L-80,.0152 bet, =1951 i 10347 144 41 4. 44 1/... 1034T H FiTIV OF SFA I ASSY,IP-3 Btilj 14 14 I'4' 44 103150' 1--17-x 4-1/7 KO,D=3 95W 1 ,11.414. 44 44 rrelP nr r I m0 1 16551' • 4 4- 41, , it 4 4 4 0 4 4 . $ . •0 9-5/WC:50 474 I-60,0-8 881F1—E101348' 1 • 44 I. • • 44 P • • •4 14÷5-01-041 UN St NPAVIANY • 41 REF LOG Bi 1M ON 0403182 I. •• 4 4 1 . ANGLE AT TOP FUT 38'.0 11050 41 Nolo.Rorer to Production LU to,Algoma'pert data , 41 • SIZE SW INIERVAL Ofin.Slir 1 DATE •1. 404 • 7-1..7' 4 11050-11105 5 1 0902/01 • •4 4 11054-11064 0 0629140 t• • 41 3-:1,11 4 11014-11064 0 06/79/0E1 1 • i• ti 396 4 11094 11104 0 06129403 1 3-348 4 11114-11124 0 '06/29.90 4 2-147 4 11120-11159 5 i 09/72101 )11 3 98" 4 11132 11142 0 !06129/03 • t 3-318' 4 11146-11156 0 !66/7960 /• 3-3/8" 4 11162-11182 0 :06/29/03 14 2 117 4 11166 11186 S .139422101 I. t•i 1-38 4 11188-11198 0 '06119103 3-18" 4 11203-11220 0 i 06128103 0 44 2 1.0" 4 11202 11272 S 06/22101 UP 1.1 3-3/8" 4 11224-11234 0 '06/28/03 411,411 3.-3113" 4 11248-11264 o ;06123103 rm S alr 4 1 11376 11416 0 i 016266V I. o P.! 113 59' 4 7.7.-.7 Xp 104%. 44"VIM 1T33/1) 1 1 1142W . 'V 1 V4*.4411 Vil 11,44,4.4.WI 14 IQ'tAIR,12 844 L-80 .0152 bpi',0 r.3.65e_I-1 11473' i--- rprIrtr•Vcr, , •••••••V 1•••••4•••••••••4 140444444 LNR,298,L-60,10=6.184L1 11550' 1144444444 144444444 444444444 1 To H tissf • •................. I 4-V EiY 4X314641-1615c OATF 191-V HY (171,04-141S 46131411-HAY143141 • 04/14432 OCWE.5 I 0121C0441.COY PLEI1ON 01:1:915.04.4.11413 RESET MN(01/06:15) VAIL: 13-17 12/25/01 D 15 IMO 18611107 No: 1820260 02109111 E.INJINU ADOG3 S435/GAPE!Y NOTE All No. 50-029-20718410 03:26111 .11.131PJC 'MEE CO 40.1'051111 .. SEC 14,T1019 R14-E 2703'RI_8 1634'FEL 1.-11[11 RX.: SI-1Y ND Ti 94.0.0 r94 M . . I, MIURA)'-4-I 4-1/7 MEP Y.(5 ('193414) . BP Exploration(Amara) ,----- TREE= EWE V.IELLI EAD- GRAY SAFETY NOTES_""'112S READINGS AVERAGE 125 ppM 1 --- 1 3-1 7 ON MI"•WELL REQUIRES A SSSV WHEN ON ACTUATOR6 V 4 �At(>ar Proposed PC Leak aHL LW.LLEV= NA Fix(Cement IA) KOP= 3000" Max A-lgle- 57'tEk 71001:7:11 2238' 1---14-1r2-(:A MIX)ttAl-O SSSVPL U=3.812' Ckatum MD= 11187' Datum TVD= 3366 SS ~3,100' MD H Proposed TOC 11 3/r CSG,720,1-80,D-12347' I 2507 i•—] Minimum ID=3.726 41osos' Leak @ '"9,467' MD 4-1/2 HES XN NIPPLE 10309' I4-1/2"F4 x N Nark 1D=3.725'1 Ill 93,11-x 7'HKu 1x1.114,1/ W,,It HA(x t:t V,l P .•8 s• I 40309' 10309" l4-1.2'I NRUG(omits)I e, . 10323• 1-{9 are-xrHAN41eC/x;t{It-631' I 11 010331' I—TOP of SKR std ID-4.70'III 4-172'196..12.67,L 80..31S2 tot,U=3-y51f" 10347 I►►ai YI�`•�i.. ..:_-_ 1'1:1 10347' H AIM OF SFA.ASSY,In-3 ear I 1441 r11, 10� ; 10360' I-I 7"X 4-1/24 x0,D=3 958"I 14111 j Tr1P nF r i MIh 10551' 140 P44 I1�1q)£ 1.4 44 114 - 9-VIV CMG.47M I-60,Al--8 681' I-10848' 10 14e 14 44 111 1441 PI-141-011A I KM St/811.05541 1111 1111 44 44 FEF LOG.11 CS ON 04933/82 1111 /III AN9,_C AT TOP FERE"38'3 11350' 041414 1111 Nota:Rater to 1 oducbon W tar trlctoncal pert data �14 ll X1,111 SVF SIF INTERVAL Opn/Sr e 1 DATE 1114 11I 2-1/7 4 110.50-11105 5 10927/01 1/ 11 3-378" 4 11054-11064 0 06'29/03 1411 11� 33.8" 4 11014-11064 O i 06.29103 1111 11* 3 318' 4 11094 11104 0 0E129103 140 ,11�1 3-378" 4 11114-11124 0 0629933 11, 711 7_.1/7 4 11129-11159 S i 0972761 1/ 8881 3 318" 4 11132 11142 0 06/29/03 I/;/ = 3-18' 4 11145-11156 0 i 0679/63 1111 3-318' 4 11162-11182 0 106129703 11 /4 2 177 4 11166 11186 S 09/22)01 1114 3-3/8" 4 11188-11198 0 j 06/79'03 1114 la 3-386"2 ' 4 11203-11220 0 08/03 I�144 2 112' 4 11202 11272 S 09/2261 1114 3-378' 4 11224-11234 0 05728/03 1444 MIN 3--3/8" 4 11248-11264 0 (0E128/03 1114 .6. 3 3/{t' 4 11370 11419 1 O 0911502 1114 ;---- A�� a 11359' Heim.los/26O3) I FVTD I I 11429• 1414141141411 � 1'411111;41 4-1/2"U4R 12 60,L-80..0152 bof,D-3.958' —, 11473' 11 11144 41 I I /=11111111114 1� ----- 111111411111111111 /11111111 7"Lt41t,tsar,L-6D,D-8.1s4" ) L11660'.__ 1�/Ii/41.1i40 I ,O1 { 11561' 1.1....1..1.... ' 1Yt 0- 60-V t1Y FX:Is,u-Nils 11.TE Fl-V HY (X1AI4N1 S 14611666-HAY IMI W114182 OCW6-5 ORIGINAL COSI PIETKN4 01/13115 JM.6,11.3 RESET PXN(01.o6115y toW12._- 13-17 12725101 1116 tAYO FERMTT Not 1820260 03609711 MAID ADDED SSS/SAFETY NOTE - AH No. 50-329-20716-00 1 03/26711 JM31PJC TME O'0/03725111) SEC 14,T1014 1211-E 2793 EN_8 1634'FEL 12/17111PJC SI-IY NOTE WA ON 84 09171.114+MJCI.IM)SI-1 4-177-"Pi PI LIG(8173/14) BP Exploration(Alaska) • Loepp, Victoria T (DOA) From: Chou,Irwin <Irwin.Chou@bp.com> Sent: Wednesday, March 18, 2015 2:38 PM To: Loepp,Victoria T(DOA) Cc: Hibbert, Michael (Alaska);Stechauner, Bernhard Subject: RE: PBU 13-17(PTD 182-026, Sundry 315-108)Cement OA/PC leak Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, The 3100' cement top is recommended because it still allows a rotary sidetrack and it mitigates any PC or tubing leaks from that depth and below. It also still leaves an annulus of 165 bbls to manage pressure in the IA. I hope that helps, please let me know if you have any further questions. Thanks, Irwin Chou Production Engineer BM East Waterflood Team BP Exploration(Alaska) Office: (907)564-5538 Cell: (907)632-3992 Irwin.Chou@bp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loeppC)a alaska.gov] Sent: Wednesday, March 18, 2015 1:12 PM To: Chou, Irwin Subject: RE: PBU 13-17(PTD 182-026, Sundry 315-108) Cement OA/PC leak Irwin, Why are you bringing the cement up to 3100' MD if the leak is at 9467' MD? Thanx, Victoria From: Chou, Irwin [mailto:Irwin.Chou(abp.com] Sent: Monday, March 09, 2015 11:41 AM To: Loepp, Victoria T(DOA) Cc: Stechauner, Bernhard; Dean, James A; Hibbert, Michael ( Alaska ) Subject: RE: PBU 13-17(PTD 182-026, Sundry 315-108) Cement OA/PC leak Hi Victoria, I have attached updated schematics per your request. Please let me know if you require any additional information. Thanks, 1 Irwin Chou Production Engineer BM East Waterflood Team BP Exploration (Alaska) Office: (907)564-5538 Cell: (907)632-3992 Irwin.Chou@bp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loeppCa alaska.gov] Sent: Thursday, March 05, 2015 8:25 AM To: Chou, Irwin Subject: PBU 13-17(PTD 182-026, Sundry 315-108) Cement OA/PC leak Irwin, Please indicate the leak on your schematics. Also, provide a schematic post procedure showing the new cement and the new TOC. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Od&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loepp aC�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp©alaska.gov 2 3Q2011 Not Operable Injector Report 40 • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, November 24, 2011 9:59 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 302011 Not Operable Injector Report Attachments: Not Operable Injector Report 3Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 3Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 3Q2011.zip» Notes on wells: ,fi i,f Removed from Quarterly Injection Report: MPF -74 (PTD #1961080): Long term shut in that was returned to service. Passed MIT -IA on 09/11/11. Added to Quarterly Injection Report: 09 -36C (PTD #1951140): Leak found in tubing patch - PTD x1820260 : Well reclassified while flowline repair is being performed END 3- 43/P -36 (PTD #1931700): Surface casing leak discovered post Brinker treatment MPC -08 (PTD #1850140): Long term shut in requiring MITIA to be compliant MPF -89 (PTD #2050900): Surface casing leak MPF -99 (PTD #2061560): Long term shut in requiring MITIA to be compliant NGI -10 (PTD #1760690): TxIA communication when on gas injection, AA for IAxOA communication. R -02 (PTD #1781000): Identified TxIA communication with leak detect log S -09 (PTD #1821040): Shut in for rig workover to replace tubing U -04A (PTD #1920270): Starting head leak with a Furmanite repair failure Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/28/2011 NOT OPERABLE: Injector 13 -17 (PTD #1820260) Well Due for AOGCC 4 year MIT -I... Page 1 of 1 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Wednesday, August 31, 2011 1:59 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; Catron, Garry R (SAIC) Cc: AK, D &C Well Integrity Coordinator; Clingingsmith, Mike J (Swift); Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Injector 13 -17 (PTD #1820260) Well Due for AOGCC 4 year MIT -IA, Pending Flowline Repairs Attachments: Injector 13 -17 (PTD #1820260) TIO and Injection Plot.doc All, WAG injector 13 -17 (PTD #1820260) will be due for a 4 year compliance AOGCC MIT -IA on 09/03/2011. Currently the well has been shut -in since May, 2011 while repairs to the flow line are being performed. No tentative date has given for resumption of injection into the well. The well is reclassified as Not Operable until such time as the flowline is repaired. The well will be included on the quarterly AOGCC Not Operable Injector report. A TIO and injection plot has been included for reference. «Injector 13 -17 (PTD #1820260) TIO and Injection Plot.doc» Please call if you have any questions. Thank you, ti FVl Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 9/1/2011 • • Injector 13 -17 (PTD #1820260) TIO Plot 08 -31 -2011 Well: 1 3-1 7 f Tbg t IA — OA 00A I --40-- 000A —On 4r U I I ,I 1f II _'3/01/10 05/02/10 07/03/10 09/03/10 11/04/10 01/05/11 03/08/11 05/09/11 07 /10 /11 1 Injector 13 -17 (PTD #1820260) Injection Plot Wet 1 3-1 7 360 — 3,400 1 :0,000 3.200 1 I - 18,000 • 3,000 2,800 - - 16,000 2.600 - 2,100 - V - 14.000 • 2.200 - pw _ _ BI 1,400 I - 8,000 a 1.200 - I 6,000 1.000 800 r - 4.000 600 L , I. _ ^ - 2 000 200 - 03/01/10 05/02/10 07/03/10 09/03/10 11/04/10 01 /05/11 33/08/11 05/09/11 07/10/11 Sehluumb~r~r NO. 5473 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Su{te 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken A7TN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Web Job k Log Description Date BL Color CD MPC-22A F-21 13-17 P2-48 16-Oi MPC-24A V-224PB1 BAUJ-00007 AYKP-00073 AYKP-00072 AVYO-00057 BBSK-00006 BAW-00005 08AKA0147 MEM PROD PROFILE W/GLS PROD PROFILE INJECTION PROFILE PROD PROFRE USIT MCNL OH MWD/LWD EDIT 2/11/10 02/16/10 02/14/10 02/11/10 02/11/10 - 01/0980 11/28/09 1 1 1 1 1 2 1 1 1 1 1 1 1 1 BP Expio2tion (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2938 02/ t 8110 • MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 7/ G/'-/ }-/ ?/,. ; '=' l. 7 '...../-r1· , DATE: Wednesday, September 05,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-17 PRUDHOE BAY UNIT 13-17 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :1(;V Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 13-17 API Well Number: 50-029-20718-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ070904202205 Permit Number: 182-026-0 Inspection Date: 9/3/2007 ReI Insp N um: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-17 Type Inj. w TVD 8227 ./ IA 320 4000 3920 3890 P.T. I ~lUlóU TypeTest SPT Test psi 2056.75 '" OA 160 380 380 380 Interval OTHER PIF P / Tubing 570 570 570 570 - Notes: Pre MI swap, 6 BBLS methanol pumped. 1 well house inspected; no exceptions noted. sCANNED SEP 1 0 2007 Wednesday, September 05, 2007 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor '~~1 D¡~lD7 DATE: Monday, August 27,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-17 PRUDHOE BAY UNIT 13-17 . FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 31St.- Comm Well Name: PRUDHOE BAY UNIT 13-17 API Well Number: 50-029-20718-00-00 Inspector Name: John Crisp Insp Num: mitJCr070826 I 64405 Permit Number: 182-026-0 Inspection Date: 8/25/2007 ReI Insp N um: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-17 Type Inj. N TVD 8227 IA P.T. 1820260 TypeTest SPT Test psi 2056.75 OA Interval OTHER PIF .../ JVi Tubing Notes: MIT IA to 4K for MI swap. Flow 3 had shut down & injection on this well was stopped. Tubing was found with 0 psi. The WIE made the call¡/"" not to PT to 4,000 due to 0 tubing pressure. Hot Oil was rigged up on this well but no PT performed. NON-CONFIDENTIAL stANNED SEP 1 0 2007 Monday, August 27, 2007 Page I of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ---:> ,^\:J , ~: ''='I " '-' {Y¡ Ltp DATE: Tuesday, August 01,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) mc 13-17 PRUDHOE BAY UNIT 13-17 \~;}....D~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: '~-7 P.I. suprvJ6~ Comm Well Name: PRUDHOE BAY UNIT 13-17 API Well Number 50-029-20718-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS06080 1 061430 Permit Number: 182-026-0 Inspection Date: 7/31/2006 Rei Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. !Type Inj. i W ! TVD -- i Well I 13-17 L 8217 ! IA I 230 , 2250 2240 2250 I I --t-~- P.T. ! ]820260 !TypeTest· SPT I Test psi I 2054.25 ! OA I 140 I 250 I 250 250 .' I I I Interval 4YRTST P/F P '-"'" Tubing I 600 ! 600 i 600 600 : I Notes Preteat pressures were observed and found stable, Well demonstrated good mechanical integrity, NON-CONFIDENTIAL ,'~('.~j\JN.t::.n ___ ~t fi.-} 1:..~, ('l-' f;";; \J '., Tuesday, August 01, 2006 Page I of 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ,~ ~ ¡?/r; 1{' - Yl ;'{ , DATE: Wednesday, July 05, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-17 PRUDHOE BAY UNIT 13-17 ".o~ \~o-- FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv , -IKi:- Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT 13- I 7 API Well Number 50-029-207 I 8-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG060703065750 Permit Number: 182-026-0 Inspection Date: 6/28/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 13-17 ¡Type Inj. ¡ W i TVD 8456 I IA I 210 1910 I 1885 1880 i ¡ i ¡ I P.T. I 1820260 ¡TypeTest i SPT ! Test psi 2114 I OA I 100 ! 250 I 250 I 250 I I I I ! r--- Interval 4YRTST P/F -y r Tubing i 640 660 i 660 i 660 I I , Notes During pressure up ofIA loud noise heard fipm wellhead area. Pump was stopped and IA was bled (intentionally) from approx 2000 psi to 1910 psi. Observed well for thirty minutes w~ile Grant conferred with office. Test was terminated pending diagnostics. ::f?,£- -¡!U. (~ < (,·<.1, Wednesday, July 05, 2006 Page 1 of 1 i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanon r-1 suspendS] Operation Shutdown r-] Perforate[] Variancem'-] Annuar Disposalm--{ After casineD Repair WellD Plu.o Perforationsr"~ Stimulatem~ Time Extension F"] Other[] Change Approved Programr-] Pull Tubing{--{ Perforate New Poolr"~ Re-enter Suspended Wellr-'m ClBP / ADD PERFS 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development {--] Exploratoryr-m 182-026 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic [--{ Service [ 50-029-20718-00-00 7. KB Elevation (ft): 9. Well Name and Number: 87.00 13-17 8. Property Designation: 10. Field/Pool(s): ADL 028311 Prudhoe Bay Fiei~l 11. Present Well Condition Summary: JUL 0 ~ 2_003 Total Depth measured 11551 feet true vertical 9172 feet Plugs (measured) Tagged CIBP @~ !~1~59' (06/28/2003). Effective Depth measured 11359 feet Junk (measured) true vertical 9022 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 145' 145' 40K 520 Surface 2665' 13-3/8" 2507' 2507' 80K 2670 Intermediate 10781' 9-5/8" 10848' 8623' 80K 4760 Liner 997' 7" 10551'-11548' 8398'-9170' 80K 7020 Scab Liner 1123' 4-1/2" 10350'-11473' 8247'-9111' 80K 7500 Perforation depth: Measured depth: Open Perfs 11054'-11064', 11074'-11084', 11094'-11104', 11114'-11124', 11132'-11142', 11146'-11156', 11162'-11182', 11188'-11198', 11202'-11220', 11224'-11234', 11248'-11264', Open Perfs Below CIBP 11370'-11410'. True vertical depth: Open Perfs 8782'-8790', 8798'-8806', 8814'-8822', 8829'-8837', 8844'-8851', 8855'-8862', 8867'-8883', 8888'-8895', 8899'-8913', 8916'-8924', 8935'-8947'. Open Perfs Below CIBP 9030'-9061'. Tubing: ( size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 10330' MD. Packers & SSSV (type & measured depth) 9-5/8" x 7" BKR ZXP Packer W/Tieback SLV @ 10309' MD. Top of BKR SBR @ 10331'. 4-1/2" Camco BAL-O SSSVN @ 2238'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casin~l Pressure Tubin~ Pressure Prior to well operation: 9142 1017 Subsequent to operation: 9117 376 14. Attachments: 15. Well Class after proposed work: Exploratoryr-] DevelopmentE~ Service~ Copies of Logs and Surveys run __ 16. Well Status after proposed work: oill-I Gasl--I WAG~ GINJI--I WINJI--] WDSPLI--I Daily Report of Well Operations _X Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true encee,the best of my knowledge. ISundry Number or N/A if C.O. Exempt: ..... '-"- I N/A Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr Title Techical Assistant Signature .~~-~...e.~~..~.,~~ Phone 907/564-5174 Date July 01,20.03 ~" ~ ~, ,i, ~, , ~ ! m_ · · Nm Form 10-404 Revi.4.:-' :! ? '26,:.~. , JUt. 8 2_003 13-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/26~2003 PERFORATING: DRIFT/TAG 06~28/2003 PERFORAT:ING: CAST :IRON BR:IDGE PLUG; PERFORAT:ING 06/29/2003 PERFORAT:ING: PERFORAT]'NG 06/30/2003 TESTEVENT---INJECTION PRESSURE, PSI: 376 TYPE: PW VOLUME: 3,571 BWPD EVENT SUMMARY O6/26/03 <<< WELL INJECTING UPON ARRIVAL >>> PULL 4-1/2" CAMCO WRDP SSSV # HPS-381 FROM 2242' WLM. (JARRED FOR 45 MINUTES BEFORE COMING FREE). RUN 3.625 CENT., AND 3-1/2" X 11' ALUMINUM DUMMY GUN TO BTM @ 11393' WLM. TURN WELL BACK TO DSO. 06/28/03 SET BAKER CIBP. ELEMENT SET AT 11360 FT MD. TOP SET AT 11359.4 FT MD. PERFORATE MULTIPLE INTERVALS WITH 3 3/8" HSD - 3406 POWERJETS @ 4 SPF. GUN #1 INTERVAL- 11248-11264 FT MD. GUN #2 INTERVALS = 11224- 11234 AND 11203-11220 FT MD. O6/29/O3 PERFORATE - 3 3/8" HSD, 3406 POWERJETS @ 4 SPF. TIED INTO SWS CIBP SET RECORD DATED 6-28-03 REFERENCED BACK TO THE SWS BHCS DATED 4-18-82. GUN #1 INTERVALS: 11188-11198 AND 11202-11203 FT. GUN #2 INTERVAL = 11162-11182 FT. GUN #3 INTERVALS = 11132-11142 FT AND 11146-11156 FT FT. GUN #4 INTERVALS = 11094-11104 FT AND 11114-11124 FT. GUN #5 INTERVALS = 11054-11064 FT AND 11074-11084 FT. <<< WELL LEFT SHUT IN >>> 06/30/03 TESTEVENT --- INJECTION PRESSURE, PSI: 376 TYPE: PW VOLUME: 3,571 BWPD FLUIDS PUMPED BBLS 3 DIESEL FOR PRESSURE TESTING SURFACE EQUIP (3 TESTS) 3 TOTAL ADD PERFS 06/28-29/2003 THE FOLLOWING INTERVALS WERE PERFORATED WITH 3-3/8" HSD, 3406 POWERJETS, 4 SPF, PHASED 60 DEGREES, RANDOM ORIENTATION. 11054'-11064' 11074'-11084' 11094'-11104' 11114'-11124' 11132'-11142' 11146'-11156' Page I 13-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ADD PERFS (CONTINUED) 11162'-11182' 11188'-11198' 11202'-11220' 11224'-11234' 11248'-11264' Page 2 \ TREE =5-1/8" GRAY GI~I 2 SAFETY NOTES: WB_LFEAD: GRAY I ACTUATOR= AXELSON 13-17 KB. ELEV = 87' B F. F_LEV = NA KOP: 3000" Max An~lle = 57 (~ 7100' ~_~ i~i ' , I 13-3/8" CSG, 72#, L-80, ID: 12.347" H 2507' ' ; Minimum ID = 3.725" @ 10309' 4-1/2" HES XN NIPPLE 9-5;~"X~',K~ZX,~KRWmE~ACKSLV.,D:6.2~3"H ~o3o~' ]----- [I I'J t~°3°9' H4'11z'~sxN~""''D=3'72~'l 19-5/8"X?'BKRHMCHGR, ID:6.31"H 10323' !------- 14-1'2" TBG, 12.6#, L-80,.0152 bpf, ID:~.~"1-1 ~0330' I--- ---I ~033~' H.o.O..K. s~., ,~= 4.70" I ISBE~OXX4.112"P,NXO.,D:3.95~"I--I 10350' F__._._ ' ~ 10347' HBTMO~SE~LASSY. D:3.~"I ITOPOF?'LNR H lo551' I-- , I 9-5/8" CSG, 47#, L-80, ID: 8.681" H 10848' I~ PERFORATION SUMMA RY REF LOG: BHCS ON 04/03/82 ANGLEATTOP PB~F: 38 @ 11050' Note: Refer to R'oduction DB for historical perf data ) SIZE SPF INTERVAL : Opn/Sqz DATE SEE PAGE 2 FOR PERF BREAKDOWN ~ ~429,I 14-1/2'' LNR, 12.6~, L-80, .0152 bpf, ~D= 3.958" I--I 11473' ~ ~ 17" LNP, 29~, L-80, ~D = 6.184" I--t 11550' · ~ 11551' I''-'~~ I DATE REV BY COIVlVIENTS DATE REV BY COMMI~ITS PRUDHOE BAY UNIT 04114182 OCW6.5 ORIGINAL. COMPLETION WRL: 13-17 12125101 RWO PERMIT No: 1820260 09/10/01 RN/TP CORRECTIONS APINo: 50-029-20718-00 01/07/02 CH/TP NEW WELL SEC 14, T10N, R14E, 2703' FNL & 1634' FEL 01/29/02 CWS/KK ADPERF 6/28-29/0." BJrvl/KK ADFERFS BP Exploration (Alaska) PERFORATION SUMMA RY REF LOG: BHCS ON 04/03/82 ANGLEATTOP PBRR 38 @ 11050' Note: Refer to Ffoduction DB for historical perf data SIZE SPF INTERVAL Opn/Sclz DATE SEE PAGE 2 FOR PERF BREAKDOWN DATE REV BY COrvtVlENTS DATE REV BY COMMI~ITS 04114182 OCW6.5 ORIGINAL COMPLETION 12125101 RWO 09/10/01 RN/TP CORRECTIONS 01/07/02 CH/TP NEW WELL 01/29/02 CWS/KK ADPERF 6/28-29/0.. BJrvl/KK ADPERFS 13-17 PERFS PERFORATION SUMMA RY' REF LOG: BHCS ON 04/03/82 ANGLEATTOP'PERF: 38 @ 11050' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 11050 - 11105 S 09/22/01 3-3/8" 4 11054 - 11064 O 06/29/03 3-3/8" 4 11074 - 11084 O 06/29/03 3-3/8" 4 11094 - 11104 O 06/29/03 3-3/8" 4 11114- 11124 O 06/29/03 2-1/2" 4 11129- 11159 S 09/22/01 3-3/8" 4 11132- 11142 O 06/29/03 3-3/8" 4 11146- 11156 O 06/29~03 3- 3/8" 4 11162 - 11182 O 06/29/03 2-1/2" 4 11166- 11186 S 09/22/01 3-3/8" 4 11188 - 11198 O 06/29/03 3-3/8" 4 11202- 11220 O 06/28/03 2-1/2" 4 11202 - 11272 S 09/22/01 3-3/8" 4 11224 - 11234 O 06/28/03 3-3/8" 4 11248 - 11264 O 06/28/03 3-3/8" 4 11370- 11410 O 01/29/02 DATE REV BY COMMENTS DATE REV BY OOMMBqTS 04114/82 OCW6.5 ORIGINAL COMPLETION 12/25/01 RVVO 09/10/01 RNf'I'P CORRECTIONS 01/07/02 CH/'FP NEW WB.L 01/29/02 CWS/KK ADPERF 6/28-29/0,'. BJIVl/KK ADPERFS PRUDHOE BAY UNIT WELL: 13-17 PERMIT No: 1820260 APl No: 50-029-20718-00 SEC 14, T10N, R14E 2703'FNL & 1634' FEL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERFS 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 2703' FNL, 1634' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 2746' FNL, 3052' FEL, Sec. 11, T10N, R14E, UM At effective depth 2514' FNL, 3047' FEL, Sec. 11, T10N, R14E, UM At total depth 2438' FNL, 3047' FEL, Sec. 11, T10N, R14E, UM (asp's 685566, 5932602) (asp's 684015, 5937803) (asp's 684014, 5938035) ~sp~ 68401~ 5938111) 6. Datum elevation (DF or KB feet) RKB 87 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 13-17 9. Permit number / approval number 182-026 10. APl number 50-029-20718-00 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 78' Surface 2507' Production 10848' Liner 997' Scab Liner 1123' 11551 feet Plugs (measured) 9172 feet 11429 feet Junk (measured) 9076 feet Size Cemented Measured Depth True Vertical Depth 20" 1706# Poleset 78' 78' 13-3/8" 2450 sx Arcticset III 2507' 2507' 9-5/8" 500 sx Class 'G' 10848' 8623' 7" 365 sx Class 'G' 10551' - 11548' 8398'- 9170' 4-1/2" 10350' - 11473' 8247' - 9111' Perforation depth: measured Open Perfs 11370'-11410', Sqzd Perfs 11050'-11105', 11129'-11159', 11166'-11186', Sqzd Perfs continued 11202'- 11272' true vertical Open Perfs 9030' -9061 ', Sqzd Perfs 8779' - 8822', 8841' - 8865', 8870' - 8886', 8899' - 8953' ]'ubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 to 10330' 9-5/8" x 7" BKR ZXP PKR W/TIEBACK SLV @ 10309'; 9-5/8" X 7" bkr hmc hgr @ 10323' TOP OF BKR SBR @ 10331' W/BTM OF SEAL ASSY @ 10347'-- ,,,,,, ,,,,,~ e,.' l% 4-1/2" CAMCO BAL-O SSSV Nipple @ 2238' 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) ~AR Treatment description including volumes used and final pressure Representative Daily Average Production or Injection O.a,ta,i;10~&~,~C'.~ 14. Prior to well operation 01/20/2002 Subsequent to operation 02/16/2002 OiI-Bbl Gas-Mcf Water-Bbl Casid'~ Tubing Pressure Shut-In 4391 603 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _ Gas _ Suspended Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DeWayne R"~-'"Schnorr ~ Form 10-404 Rev 06/15/88 · ORIGINAL Date March 18, 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 13-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/31/2001 DR:ILL-POST WORK: POST RIG WORK 01/22/2002 DR:ILL-POST WORK: FTLL (:::LEAN OUT 01/27/2002 DRZLL-POST WORK: DR:[FT/TAG 01/29/2002 DRILL-POST WORK: PERFORAT]:NG 02/16/2002 DRILL-POST WORK: MZT-TA 02/21/2002 DR]:LL-POST WORK: AC-MTTTA EVENT SUMMARY 12/31/01 DRIFT W/3.5 CENT. AND SAMPLE BAILER. OBSTRUCTION @ 10890' BROKE FREE TO 10950', THEN 11068' AND UNABLE TO WORK PAST 11090' SLM. 01/22/O2 MIRU DOCT #3. RIH W/3.0" JS NOZZLE. NOTICE SMALL WT DROP @ 10890' CTD. TAG PBTD @ 11427' CTMD. PUH 200', RUN BACK AND TAG AGAIN @ 11427' CTMD. CIRC. BU AND POOH AT 80%, FREEZE PROTECT TO 2500'. RETURNS FROM 11400' APPEARED TO SHOW DIESEL, H20, TRACE SOLIDS. WAIT ON WEATHER TO RDMO. NOITIFY DSO THAT JOB IS COMPLETE, WELL FREEZE PROTECTED, AND SWAB CLOSED. RDMO CTU. 01/27/O2 01/29/02 02/16/O2 DRIFTED TUBING WITH 14' 3 3/8" DUMMY GUN TO 11395' SLM WORKED IT TO 11409' SLM, BAILER EMPTY. ***LEFT WELL SHUT IN*** PERFORATE, 3 3/8" HSD 4spf, PJ 11370'-11410' (40') DONE IN TWO RUNS, TAGGED TD @ 11410', MADE JEWELRY LOG UP TO 10000', POOH, RDMO, LEFT WELL SI AND FUSABLE CAP ON DUE TO SSV PROBLEM. T/I/O: 600/650/400 MITIA TO 2500 PSI (PASSED) PREP FOR AOGCC. INITIAL IA FL @ SURFACE. PUMPED 3 BBLS OF METHANOL DOWN IA, IA PRESSURED UP TO 2500 PSI. IN THE FIRST 15 MINUTE TEST IA LOST 0 PSI AND IN THE SECOND 15 MINUTE TEST IA LOST 0 PSI FOR A TOTAL OF 0 PRESSURE IN 30 MINUTES. BLED IA BACK TO 550 PSI. FINAL WHP's = 600/550/400. 02/21/02 STATE WITNESSED (JOHN SPALDING) MITIA TO 2500 PSI PASSED. MITIA LOST 5 PSI IN THE FIRST 15 MINS AND 5 PSI IN THE SECOND 15 MINUTES FOR A TOTAL OF 10 PSi IN 30 MINUTES. FLUIDS PUMPED BBLS 2 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (2 TESTS) 3 METHANOL 105 60/40 METHANOL WATER ~.:.. :~ . . 360 2% KCL EXTRA SLICK WATER Page I 13-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 470 ITOTAL ADD PERFS 01/29/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 3-3/8" POWER JET, 4 SPF, 90 DEGREES PHASING WITH ZERO ORIENTATION. 11370' - 11410' Page 2 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWelllntegrityEngineer ©BP.com] Sent: Friday, February 22, 2002 7:56 AM To: Maunder, Thomas E (DOA) Subject: 13 -17 (PTD 1820260), Cancel Sundry #298 -275 Attachments: 13- 17.ZIP 13- 17.ZIP Hello Tom. We request sundry number 298 -275 for well 13 -17 (PTD 1820260) be canceled. During 12/01, the tubing was replaced. Injection started 02/11/02 and an AOGCC MITIA passed on 02/21/02. Recent events: > 12/25/01: RWO complete, tubing replaced. > 02/11/02: Injection started. > 02/21/02: MITIA passed, AOGCC witnessed. Unless advised differently, we will cease sundry compliance testing and return the well to a 4 -year MITIA schedule. Attached is the updated wellbore schematic. Please call if you have any questions. Thanks! Joe Joe Anders, P.E. / Kevin Yeager Well Integrity Engineer BP Exploration, (Alaska) Inc. en's (907) 659 -5102 email: NSUADWWellIntegrityEngineer @bp.com , * ,?: «13 -17 . ZIP» 1 TREE = 5 -1/8" GRAY GEN 2 I SAFETY NOTES: I ACTUATOR = GRAY 13 17 ACTUATOR = AXELSON KB. ELEV = 87' BF. ELEV = NA KOP = 3000' Max Angle = 57 @ 7100' Datum MD = 11187' _ 1 I 2238' H4 -1/2" CAMCO BAL -O SSSVN, ID = 3.812" I Datum ND = 8800' SS ,_ �, I [ 113 -3/8" CSG, 72#, L -80, I) = 12.347" H 250r Minimum ID = 3.725" @ 10309' 4 -1/2" HES XN NIPPLE I9 -5/8" X 7" BKR ZXP PKR W/71EBACK SLV, ID = 6.283" H 10309' I ' T 1 10309' H4 -1/2" HES XN NIP, El = 3.725" X 7" BKR 1 4 -1 /2" I G, 85/" 2.6#, L-80, 1522 bpf, = 3.958 " 10330' # * 10331' H TOP OF BKR SBR, ID = 4.70" I H I I SBE BOX X 4 -1/2" PIN XO, ID = 3.958" H 10350' � ��� � I 10347' HBTM OF SEAL ASSY, ID = 3.88" .1 444 (TOP OF 7" LNR 1 A 1� • 4 • 41 • • •• 411 / 41 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 10848 a 1 •� • 1 1 1 1 PERFORATION SUMMARY • 1 1 REF LOG: BHCS ON 04/03/82 • • N ANGLE AT TOP PERF: 38 @ 11050' ∎ 1 ∎/ Note: Refer to Production DB for historical pert data ■• �1 SIZE SPF INTERVAL Opn /Sqz DATE �� � 2 -1/2" 4 11050 -11105 S 09/22/01 2 -1/2" 4 11129 -11159 S 09/22/01 • 1 2 -1/2" 4 11166 -11186 S 09/22/01 •+' 2 -1/2" 4 11202 -11272 S 09/22/01 • • 3 -3/8" 4 11370 -11410 0 01/29/02 i • • PBTD 11429' f, ,.1N, i vj/ 1',,1.1 14-1/2" LNR, 12.6 #, L -80, .0152 bpf, b = 3.958" H 11473' 44444444 4 1 144414441 ( 7" LNR, 29#, L -80, ID = 6.184" H 11550' I � 1 TD 11551' 4444 •44 4 4 4 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/14/82 OCW6.5 ORIGINAL COMPLETION 01/07/02 CHITP NEW WELL WELL: 13 -17 01/03/01 SIS -SLT CONVERTED TO CANVAS 01/29/02 CWS/KK ADPERF PERMIT No: 182 -0260 01/29/01 SIS -LG REVISION API No: 50- 029 - 20718 -00 09/10/01 RN/TP CORRECTIONS SEC 14, T1ON, R14E 2703' FNL & 1634' FE- 12/25/01 _RWO BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor [~ DATE: February 21, 2002 Chair ~,,SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder _/~ '/N~~ BPXA P.I. Supervisor .,~~,~ '(' .%% ~¢;:)'~' DS-13 ~,j~..~- x 17 FROM: John H. Spaulding PBU Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. vv""l I i. oo i i.,oo , ' P'.T.D.I 1820260 IType testI P I Test psiI 2054 I Casing I , 855 I 25O0 I 2495 I 249O I, P/FI P Notes: Post RWO to replace tubing Well P.T.D, Notes: "We~i P.T.D. Notes: P.T.D. Notes: P'.T.D. N~t~s: JType Inj. Type test Type testI ITM psi l I Casing I , I , I I , I p,/F I ..... IType Inj. I' ' I' T.V:D, I" I Tubi'ng ,'!' I ' I'" ! ..... ITMI TYPetestl, I'restpsil I Casing.I I ,, I , I I P/F 1 IType Inj. I I T.V.D. ] "I Tubing J ] ,. I' I ,' "]lnterval-I " TyPetestI , , Imes!psiI i casing I , I I, I , ! P/F I 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 The well was recently worked over and had the tubing replaced. This test was the initial on the tubing by inner annulus since the RWO. As noted the test passed and is in compliance with area injection orders. M.I.T.'s performed: 1_ Attachments: none Number of Failures: 0 -- Total Time during tests: 1.5 cc: M IT report form 5/12/00 L.G. mit bpxa 13-17 2-21-02 js.xls 3/8/02 STATE OF ALASKA ~ ALASKA (J~L AND GAS CONSERVATION COMMI~,.,tON 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 = 87' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 I~1 Service 4. Location of well at surface 8. Well Number 2703' SNL, 1634' WEL, SEC. 14, T10N, R14E, UM 13-17i At top of productive interval 9. Permit Number / Approval No. 182-026 301-257 2533 NSL, 3052' WEL, SEC. 11, T10N, R14E, UM 10. APl Number At effective depth 50- 029-20718-00 2766' NSL, 3046' WEL, SEC. 11, T10N, R14E, UM 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 2842' NSL, 3046' WEL, SEC. 11, T10N, R14E, UM Pool 12. Present well condition summary Total depth: measured 11551 feet Plugs (measured) true vertical 9172 feet Effective depth: measured 11429 feet Junk (measured) true vertical 9076' feet Casing Length Size Cemented M D TV• Structural Conductor 78' 20" 1706# Poleset 78' 78' Surface 2507' 13-3/8" 2450 sx Arcticset III 2507' 2507' Intermediate 10848' 9-5/8" 500 sx Class 'G' 10848' 8623' Production Liner 997' 7" 365 sx Class 'G' 10551' - 11548' 8398' - 9170' Liner 1164' 4-1/2" 168 sx Class 'G' 10309'- 11473' 8217'- 9111' Perforation depth: measured Sqzd: 11050'- 11105', 11129'- 11159', 11166'- 11186', 11202'- 11272' true vertical Sqzd: 8779' - 8822', 8841' - 8865', 8870' - 8886', 8899' - 8953' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10347' Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker 'ZXP' packer at 10309'; 4-1/2" Camco BaI-O SSSV Nipple at 2238' 13. Stimulation or cement squeeze summary ~=l[~.=,~i.~r_.l V Intervals treated (measured) 11050' - 11272': See Attached Pre-Rig Summary JAN3 0 Z00 Treatment description including volumes used and final pressure 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: " r"l copies of Logs and Surveys run ~ Oil r"! Gas ~ Suspended Service Water & Gas Injector [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge '- Signed Terrie Hubble ~'"~~_/ ~ Title Technical Assistant . Date Prepared By Name/Number: Terrie Hubble, 564-4628 · aL I ! -~ J- ........ Form 10-404 Rev. 06/15/88 0 RI GIN A L""""s BFL Submit In Duplicate Well: 13-17i - Rig Workover Rig Accept: 12/06/01 Field: Prudhoe Bay Unit Rig Release: 12/25/01 APl: 50-029-20718-00 Permit: 182-026 Drilling Rig: Doyon 16 PRE-RIG WORK 09108/01 A"Fi'EMPTED TO PULL IBP SET @ 10,506' CTD. SAT DOWN @ 10409' SLM. RECOVERED FULL BAILER OF FORMATION SAND. (APPROX 97' OF FILL) LEFT WELL SHUT IN. 09/19/01 MIRU CTU #3, FLUID PACK IA, RIH. PUMP 40 BBLS IN 3 SWEEPS CLEAN OUT TO IBP @ 10492'. CHASE OUT @ 80O/o TO SURFACE. MU BAKER FISHING STRING FOR IBP. RIH W! FISHING STRING. 09/20/01 LATCH IBP @ 10490'. EQUALIZE, WAIT i HR. BRING TO SURFACE. CHANGE OUT TS. RIH W/JDC, LATCH PRONG, POOH. DID NOT HAVE FISH AT SURFACE. RIH 2ND TIME W/JDC. TAG FISH. LOAD HOLE DOWN BACKSIDE. POH. NO PRONG RETRIEVED. SAFETY STANDBY. PERFORM WEEKLY BOP TEST. MU VENTURI TS. 09121101 RIH W/VENTURI TS. WORK FROM 10400'-10520'. POH. RETRIEVED I IBP SEALING ELEMENT. RIH W/VENTURI TS. WORK FROM 10400'-10520'. POH. RETRIEVED 2ND IBP SEALING ELEMENT. RIH W/ HYD JDC, TAGGED PRONG @ 10,541'. SIGNIFICANT OVER PULL, POOH. RETRIEVED PRONG. DELAYS AT SURFACE W/MECHANICAL PROBLEMS. CUT 200' PIPE. RIH W/HYD GS. PUMP 10 BBL BIO SWEEP, CLEAN OUT TO PLUG. CHASE TO 10000'. LATCH PLUG, JAR, POH. 09122/01 ON SURFACE. NO PLUG. REDRESS TS. RIH W/GS. LATCH PXN, JAR UP TO 10514'. JARS QUIT. NO PROGRESS W/OUT JARS. PUMP OFF, WASH, LATCH @ 10554', UNLATCHED. HAD TROUBLE RELATCHING. POH. RECOVERED PLUG. RIH W 3" JOUST NZL. TAGGED 10851' CTMD. GOT AGREEMENT TO CHANGE PROGRAM. FLUFFED UP 50' FILL, WAIT 30 MIN TO SE"CI'LE, TAG UP @ 10,841'. PU TO 10,831'. PUMPED 11 BBLS 15.8 PPG CEMENT, SQZ i BBL W/500 PSI BUMP. DROP 3/4" BALL, CLEAN OUT FROM 10,530' TO 10,680' W/ 104 BBLS BIO, 3 PASSES. LEFT 150' CEMENT PLUG. CHASED CONTAM CEMENT TO SURFACE. CIRC 16 BBL DIESEL PILL TO TOP OFF TBG. ON SURFACE. TRAP 470 PSI ON WM. BLOW DOWN CT W/N2 TO TANKS. RDMO TO SHOP FOR MAINT/REEL SWAP. 09/23101 PPPOT-IC FOR PRE-RIG (PASSED.) 09126101 DRIFT TBG W/3.65 CENT & SAMPLE BAILER & TAGGED TOC @ 10,61:1.'. WORKED TOOLS DOWN TO 10,627' (STICKY BOTTOM). POOH W/CEMENT IN BAILER. PRESSURE TUBING TO 1500 PSI FOR 30 MIN TO TEST CEMENT PLUG. GOOD TEST. WITH TBG PRESSURE @ 1500 PSI, TAG TOC W/3.65 CENT @ 10,624' (STICKY BO'I-I'OM). DRIFT 5-1/2 TUBING W/4.50" CENT TO XO @ 10,471' WLM, NO PROBLEMS. 09/27101 COMPLETED TBG PUNCH, STRINGSHOT, CHEM CUT. RIH W/1-11/16" TUBING PUNCH, 4 SPF, 0 DEG PHASING, SHOI FROM 10430 FT TO 10432 FT. RIH W/3 S/RANDS OF STRING, SHOI FROM 10433.5 FI TO 10446.5 FT lO CLEAN OUT/HE AREA FOR THE CHEMICAL ANCHORS AND IUBING CUI. RIH W/4-7/16" CHEM; CUT @ 10440 FT. EACH OF THE RUNS SHOI SUCCESFULLY. DID NO//AG ID. IBG & IA EQUALIZED. 13-17i, Rig Workover Page 2 09128/01 MITOA PASSED PREP FOR RWO 09/30/01 CIRC OUT WITH 870 BBLS KCL H20, 140 BBLS DIESEL AND 20 BBLS METH. 10111101 CMIT-TXIA PASSED TO 3000 PSI 10112/01 ALL TUBING LDS FUNCTION TEST OKAY Legal Well Name: 13-17 Common Well Name: 13-17i Spud Date: 11/15/2001 Event Name: WORKOVER Start: 12/6/2001 End: 12/25/2001 Contractor Name: DOYON Rig Release: 12/25/2001 Rig Name: Doyon 16 Rig Number: 12/4/2001 21:00 - 00:00 3.00 MOB P DECOMP MOVED RIG OFF WELL Y-241, 12/5/2001 00:00 - 06:00 6.00 MOB P DECOMP WORKED ON DERRICK AS PER BP SAFETY AUDIT. 06:00 - 22:00 16.00 MOB P DECOMP MOVED OFF Y - PAD TO DS 13 22:00 - 00:00 2.00 MOB P DECOMP PJSM, RAISED DERRICK 12/6/2001 00:00 - 01:30 1.50 MOB P DECOMP HELD PJSM. R / U DRILL FLOOR. 01:30 - 04:00 2.50 MOB P DECOMP SPOTTED AND LEVELED RIG OVER WELL. SPOTTED SLOP TANK. 04:00 - 05:00 1.00 RIGU P DECOMP TOOK ON 300 BBLS OF SEAWATER. CHECKED ANNULUS PRESSURE, 0 PSI. i05:00 - 06:00 1.00 WHSUR P DECOMP R / U DSM LUBRICATOR. PULLED BPV. TUBING ON SLIGHT VACUUM. R / D DSM. 06:00 - 08:30 2.50 WHSUR P DECOMP HELD PJSM. R / U ON TREE AND ANNULUS TO DISPLACE DIESEL w/SEAWATER. ;08:30 - 10:30 2.00 CLEAN P DECOMP PRESSURE TESTED LINES TO 2,000 PSI, OK. PUMPED SEAWATER DOWN TUBING TO DISPLACE DIESEL FREEZE PROTECT OUT OF IA. PUMP RATE 5 BPM, 250 PSI. CIRCULATED UNTIL RETURNS CLEAR OF DIESEL. TOTAL PUMPED 110 BBLS. SHUT DOWN PUMP, LINED UP TO PUMP DOWN IA TO DISPLACE DIESEL FREEZE PROTECT OUT OF TUBING. PUMP RATE 5 BPM, 250 PSI. CIRCULATED UNTIL RETURNS CLEAR OF DIESEL. TOTAL PUMPED 193 BBLS. SHUT DOWN PUMPS. 10:30 - 11:30 1.00 WHSUR P DECOMP R / U DSM, SET BPV, R / D DSM. 11:30 - 12:30 1.00 WHSUR P DECOMP HELD PRE-SPUD MEETING w/DRILLING CREWS AND SERVICE HANDS. 12:30 - 14:30 2.00 WHSUR P DECOMP HELD PJSM. FMC BLED DOWN CONTROL LINES. N / D TREE. 14:30 - 15:30 1.00; WHSUR P DECOMP CHECKED BPV, CHECKED XO MAKE UP. 15:30 - 00:00 8.50 BOPSUR P DECOMP N / U BOPE. CHANGED PIPE RAMS, TOP 4 1/2" X 7" BO'II'OM 3 1/2" X 6" ( NOTE]!! PRESSURE TESTED CHOKE MANIFOLD WHILE CHANGING PIPE RAMS, LOW 250 PSI AND HIGH 3500 PSI ) 12/7/2001 00:00 - 01:30 1.50 BOPSUR P DECOMP HELD PJSM. CLOSED & SECURED PIPE RAM DOORS. M / U TEST JOINT. 01:30 - 05:00 3.50 BOPSUF P DECOMP HELD PJSM. TESTED BOPE. TESTED UPPER PIPE RAMS, BLIND RAMS, VALVES, HCR, KILL LINE, CHOKE LINE AND VALVES TO 3,500 PSI HIGH / 250 PSI LOW. TESTED ANNULAR TO 3,500 PSI HIGH / 250 PSI LOW. HIGH PRESSURE TESTS HELD FOR 10 MIN, LOW PRESSURE TESTS HELD FOR 5 MIN. ALL PRESSURE TESTS HELD w/ NO LEAKS OR PRESSURE LOSS. TESTED LEL AND H2S GAS ALARMS, CHUCK SHEEVE w/AOGCC WAIVED WITNESSING TEST. 05:00 - 07:30 2.50 BOPSUF P DECOMP HELD PJSM. R / U DSM LUBRICATOR TO PULL BVP. MADE SEVERAL ATTEMPTS TO RETRIEVE BPV, COULD NOT GET OVER PLUG. P / U JT DP & FLUSHED STACK. P / U LUBRICATOR AND RETRIEVED BPV. R / D DSM. 07:30 - 08:00 0.50 PULL P DECOMP M / U BAKER DOUBLE SPEAR w/5-1/2" GRAPPLES AND PACK OFF. TOTAL LENGTH OF SPEAR 22.5'. M / U SPEAR TO 1 JOINT OF 3-112" DP. LOWERED SPEAR THROUGH TUBING HANGER AND ENGAGED TUBING w/SPEAR. OBSERVED 0 PSI ON IA. 08:00 - 11:00 3.00 PULL P DECOMP BACKED OUT LOCK DOWN SCREWS IN TUBING HEAD. Printed: 12/26/2001 8:37:28 AM Legal Well Name: 13-17 Common Well Name: 13-17i Spud Date: 11/15/2001 Event Name: WORKOVER Start: 12/6/2001 End: 12/25/2001 Contractor Name: DOYON Rig Release: 12/25/2001 Rig Name: Doyon 16 Rig Number: 12/7/2001 08:00 ~ 11:00 3.00 PULL P DECOMP MADE STRAIGHT PULL ON TUBING STRING TO 225,000#, TUBING HANGER CAME FREE, WEIGHT DROPPED BACK TO 155,000~. PULLED ON TUBING STRING TO 225,000~, NO MOVEMENT. WORKED TUBING STRING FROM 150,000~ TO 225,000~, NO MOVEMENT. PULLED ON TUBING STRING TO 250,000~, NO MOVEMENT. WORKED TUBING STRING FROM 150,000~ TO 250,000~, NO MOVEMENT. PULLED ON TUBING STRING TO 260,000~, NO MOVEMENT. WORKED TUBING STRING FROM 150,000~ TO 260,000~, NO MOVEMENT. PULLED ON TUBING STRING TO 275,000~, NO MOVEMENT. WORKED TUBING STRING FROM 150,000~ TO 275,000~, TUBING STRING MOVED UP w/STEADY PULL OF 250,000~. WORKED TUBING STRING FROM 110,000~ TO 250,000#, PULLED TUBING HANGER THROUGH ROTARY TABLE w/ 250,000#. CONTINUED TO WORK TUBING STRING UNTIL TUBING HANGER WAS 10' ABOVE FLOOR w/175,000~. SET TUBING IN SLIPS. 11:00 - 11:30 0.50 PULL ~ DECOMP BROKE OUT AND L / D 1 JOINT OF 3-1/2" DP AND TUBING SPEAR. 11:30 - 12:30 1.00 PULL :~ DECOMP R / U TUBING TONGS AND EQUIPMENT. BROKE OUT AND L / D TUBING HANGER. R / U XO, CIRCULATING HEAD AND HOSES. R / U CAMCO SPOOLING EQUIPMENT TO SPOOL UP CONTROL LINES. 12:30 - 15:30 3.00 PULL P DECOMP PUMPED AND CIRCULATED AROUND HI-VIS SWEEP. PUMP RATE 8.5 BPM, SPP 750 PSI. GAS TO SURFACE 85 BBLS SHORT OF BOTTOMS UP. CLOSED ANNULAR AND CONTINUED TO CIRCULATE THROUGH CHOKE AS A PRECAUTION. CIRCULATED BACK GAS, SCALE AND CEMENT. CIRCULATED 3 BOTTOMS UP UNTIL ALL GAS WAS OUT OF HOLE. CIRCULATED UNTIL RETURNS OVER SHAKER WERE CLEAN. 15:30 - 19:00 3.50 PULL P DECOMP POOH, BROKE OUT AND L / D 54 JTS 5-1/2" 17# TUBING. BROKE OUT AND L / D SSSV ASSEMBLY. R / D CAMCO CONTROL LINE SPOOL AND EQUIPMENT. 19:00-00:00 5.00 PULL 3 DECOMP POOH, L/DTUBING. L/DTOTAL 195 JOINTS 5-1/2" 17# TUBING AT REPORT TIME 12/8/2001 00:00 - 03:30 3.50 PULL ~ DECOMP HELD PJSM. POOH, L / D 5-1/2" 17# TUBING. TOTAL TUBING PULLED 265 JTS AND CUT JOINT = 20.19'. 03:30 - 04:30 1.00 PULL :~ DECOMP R / D TUBING EQUIPMENT, CLEARED AND CLEANED RIG FLOOR. 04:30 - 05:00 0.50 BOPSUR P DECOMP P / U KELLY, RAN THROUGH ROTARY TABLE, TIGHTENED AND TORQUED ALL CONNECTIONS. 05:00 - 06:00 1.00 BOPSUI~ P DECOMP HELD PJSM. M / U TEST PLUG AND TEST JOINT. RAN AND SET TEST PLUG IN WELLHEAD. TESTED LOWER PIPE RAMS, KELLY VALVES, KELLY AND STANDPIPE. 250 PSI LOW f/5 MINUTES, 3,500 PSI HIGH f/10 MINUTES. ALL PRESSURE TESTS HELD w/NO LEAKS OR PRESSURE LOSS. 06:00 - 06:30 0.50 BOPSUF!P i DECOMP PULLED TEST PLUG, BROKE OUT AND L / D DOWN TEST JOINT. 06:30 - 07:30 1.00 BOPSUF:P DECOMP RAN AND SET WEAR BUSHING. 07:30 - 09:30 2.00 PULL P DECOMP HELD PJSM. MADE UP FISHING BHA-8-3/8" CUT LIP Printed: 12/26/2001 8:37:28AM Legal Well Name: 13-17 Common Well Name: 13-17i Spud Date: 11/15/2001 Event Name: WORKOVER Start: 12/6/2001 End: 12/25/2001 Contractor Name: DOYON Rig Release: 12/25/2001 Rig Name: Doyon 16 Rig Number: 12/8/2001 07:30 - 09:30 2.00 PULL P DECOMP GUIDE, OVERSHOT w/5-1/2" BASKET GRAPPLE - BUMPER SUB - 6-1/4" OIL JARS - XO - 9-6" D.C. - XO - ACCELERATOR JARS - PUMP OUT SUB. BHA LENGTH 318.73'. TOP OF FISH 10,442'. 09:30-13:30 4.00 PULL P DECOMP RIH w/ BHA ON 3-1/2" DP. P / U AND DRIFTED 3-1/2" DP FROM PIPE SHED. 13:30- 14:00 0.50 PULL P DECOMP SERVICED RIG. 14:00- 14:30 0.50 PULL N RREP DECOMP REPAIRED PIPE SKATE. 14:30 - 22:00 7.50 PULL P DECOMP RIH w/BHA ON 3-1/2" DP TO 10,363'. TAGGED FILL AT 10,363'. P / U AND DRIFTED 3-1/2" DP FROM PIPE SHED. 22:00 - 23:30 1.50 PULL P DECOMP WASHED DOWN FROM 10,363' TO TOP OF FISH AT 10,440', CIRCULATED AT 7 BPM, SPP 1,500 PSI. 23:30 - 00:00 0.50 PULL P DECOMP ATTEMPTED TO REVERSE CIRCULATE, PLUGGED OFF, CIRCULATED AND CLEARED, PUMPED 20 BBL HI-VIS PILL, CIRCULATING AT REPORT TIME. 12/9/2001 00:00 - 01:30 1.50 PULL N DPRB DECOMP HELD PJSM. PUMPED AND CIRCULATED AROUND HI-VIS SWEEP. PUMP RATE 6 BPM, SPP 1,200 PSI. OBSERVED ONLY FLUID RETURNS OVER SHAKER. 01:30 - 04:00 2.50 PULL N DPRB DECOMP LINED UP AND REVERSE CIRCULATED HOLE. STARTED 60' ABOVE FISH AT 10,380'. SLOWLY STRIPPED INTO HOLE WHILE REVERSE CIRCULATING. PUMP RATE 7 BPM, SPP 1,250 PSI. CIRCULATED BACK LARGE AMOUNT OF SAND AND CEMENT. CIRCULATED UNTIL RETURNS WERE CLEAN. 04:00 - 05:00 1.00 PULL N DPRB DECOMP WASHED DOWN TO 10,447', ATTEMPTED TO LATCH FISH, NO SUCCESS. 05:00 - 05:30 0.50 PULL N DPRB DECOMP :SET BACK AND BLEW DOWN KELLY. 05:30- 09:30 4.00 PULL N DFAL DECOMP POOH w/3-1/2" DP. 09:30 - 10:30 1.00 PULL N DFAL DECOMP POOH w/BHA. SET BACK BHA. 10:30- 11:30 1.00 PULL N DFAL DECOMP BROKE DOWN OVERSHOT. GRAPPLES BURNED SMOOTH, OBSERVED GROOVE ON BOTTOM OF NO-GO WHERE TUBING STUB WAS ROTATING. RE-DRESSED OVERSHOT w/NEW GRAPPLES. P / U AND M / U OVERSHOT. 11:30 - 12:30 1.00 PULL N DFAL DECOMP HELD PJSM. MADE UP FISHING BHA-8-3/8" CUT LIP GUIDE, OVERSHOT w/5-1/2" BASKET GRAPPLE ~ BUMPER SUB - 6-1/4" OIL JARS - XO - 9-6" D.C. - XO - ACCELERATOR JARS - PUMP OUT SUB. BHA LENGTH 318.73'. TOP OF FISH 10,440'. 12:30 - 16:00 3.50 PULL N DFAL DECOMP RIH w/BHA ON 3-1/2" DP TO 10,420'. 16:00 - 16:30 0.50 PULL i P DECOMP P / U KELLY, BROKE CIRCULATION, PUMP RATE 3 BPM, SPP 350 PSI. STRING WEIGHT UP 175,000~, STRING WEIGHT DOWN 115,000#, STRING WEIGHT ROTATING 136,000#. LOWERED OVERSHOT ONTO FISH, PUMP PRESSURE INCREASED 500 PSI. SHUT DOWN PUMP. LOWERED STRING AND FULLY ENGAGED FISH. PULLED UP TO 190,000~, FISH ENGAGED. LOWERED STRING TO 150,000# AND ROTATED STRING, ATTEMPTED TO RELEASE K ANCHOR. GRAPPLES SLIPPED. RE-ENGAGED FISH AND RE-ATTEMPTED TO RELEASE K ANCHOR. GRAPPLES SLIPPED. RE-ENGAGED FISH AND PULLED UP TO 200,000# AND JARRED ON PBR. NO SUCCESS. JARRED ON PBR w/225,000#, NO SUCCESS. PULLED UP Printed: 12/26/2001 8:37:28AM Legal Well Name: 13-17 Common Well Name: 13-17i Spud Date: 11/15/2001 Event Name: WORKOVER Start: 12/6/2001 End: 12/25/2001 Contractor Name: DOYEN Rig Release: 12/25/2001 Rig Name: Doyen 16 Rig Number: 12/9/2001 16:00 - 16:30 0.50 PULL P DECOMP TO 250,000~, PBR CAME FREE. 16:30 - 17:30 1.00 PULL P DECOMP PULLED UP 10', CIRCULATED THE LONG WAY f/5 i MINUTES, PUMP RATE 8 BPM, SPP 1,900 PSI. LINED UP AND REVERSE CIRCULATED THE HOLE. PUMP RATE 8.5 BPM, SPP 2,000 PSI. CIRCULATED 3 x BOTTOMS UP. CIRCULATED BACK SAND AND CEMENT, CIRCULATED UNTIL RETURNS WERE CLEAN. 17:30 - 23:30 6.00 PULL P DECOMP SHUT DOWN PUMPS, SET BACK KELLY. POOH w/3-1/2" DP ( RECOVERED CUT OFF JOINT, 9' PUP AND PBR TOTAL LENGTH 45.72' ) 23:30 - 00:00 0.50 PULL P DECOMP HELD PJSM. MADE UP FISHING BHA-5-3/4" SPEAR - XO - BUMPER SUB - 6-1/4" OIL JARS - XO - 9-6" D.C. - XO - ACCELERATOR JARS - XO - PUMP OUT SUB. BHA LENGTH 325.68'. 12/10/2001 00:00 - 03:00 3.00 PULL P DECOMP RIH w/SPEAR BHA ON 3-1/2" DP TO 4,904'. 03:00 - 03:30 0.50 PULL N DPRB DECOMP STACKED OUT AT 4,904' w/5,000~ ON STRING. ROTATED STRING, FELL THROUGH 4,904'. STACKED OUT AT 4,944' w/5,000# ON STRING. ROTATED STRING, FELL THROUGH 4,944'. STACKED OUT AT 4,985' w/5,000~ ON STRING. NO-GO ON SPEAR HANGING UP ON CASING COLLARS. 03:30- 05:30 2.00 PULL N DPRB DECOMP POOH w/3-1/2" DP. 05:30 - 06:30 1.00 PULL N DPRB DECOMP POOH w/BHA. CHANGED OUT 8-1/4" NO-GO TO 7-5/8" NO-GO w/CAMMED EDGES. 06:30 - 07:00 0.50 PULL N DPRB DECOMP MADE UP FISHING BHA-5-3/4" SPEAR - XO - BUMPER SUB - 6-1/4" OIL JARS - XO - 9-6" D.C. - XO - ACCELERATOR JARS - XO - PUMP OUT SUB. BHA LENGTH 325.68'. 07:00 - 10:30 3.50 PULL N DPRB DECOMP RIH w/FISHING BHA ON 3-1/2" DP TO 10,442'. 10:30 - 11:30 1.00 PULL P DECOMP HELD PJSM. SLIPPED AND CUT DRILLING LINE. 11:30 - 12:30 1.00 PULL P DECOMP P / U KELLY, BROKE CIRCULATION, PUMP RATE 3.5 BPM, SPP 500 PSI. STRING WEIGHT UP 175,000~, STRING WEIGHT DOWN 125,000~, STRING WEIGHT ROTATING 145,000#. LOWERED SPEAR INTO FISH, PUMP PRESSURE INCREASED TO 600 PSI. SHUT DOWN PUMP. LOWERED STRING AND FULLY ENGAGED SPEAR INTO FISH. SET DOWN w/20,000~. PULLED UP TO 190,000#, TO ENSURE FISH ENGAGEMENT. SLACKED OFF TO 165,000~ AND ROTATED STRING 22 TIMES, TORQUE INCREASED TO 20,000 fi/lbs, AFTER 22-1/2 ROTATIONS, TORQUE AND WEIGHT DROPPED OFF. 12:30 - 13:00 0.50 PULL P DECOMP PULLED UP 10', LINED UPAND REVERSE CIRCULATED THE HOLE. PUMP RATE 8.5 BPM, SPP 2,000 PSI. CIRCULATED 2 x BOTTOMS UP. CIRCULATED BACK SAND AND CEMENT, CIRCULATED UNTIL RETURNS WERE CLEAN. SHUT DOWN PUMPS. SET BACK KELLY. 13:00 - 17:00 4.00i PULL P DECOMP POOH w/3-1/2" DP 17:00 - 18:00 1.00 PULL P DECOMP POOH w/BHA, BROKE DOWN JARS AND SPEAR. ( NO RECOVERY ) 18:00 - 18:30 0.50 PULL P DECOMP CHANGED WEAR BUSHING 18:30 - 20:30 2.00 PULL !P DECOMP MADE UP 8 1/2" BURN SHOE ONE JOINT 8 1/8" WASH PIPE, 3 - 7" BOOT BASKETS, BUMPER SUB, OIL JARS AND 9 - 6" DRILL COLLARS BHA LENGTH=350.89' 20:30 - 00:00 3.50 PULL P DECOMP RIH WITH BURN SHOE BHA TO 9608' AT REPORT TIME Printed: 12126/2001 8:37:28 AM Legal Well Name: 13-17 Common Well Name: 13-17i Spud Date: 11/15/2001 Event Name: WORKOVER Start: 12/6/2001 End: 12/25/2001 Contractor Name: DOYON Rig Release: 12/25/2001 Rig Name: Doyon 16 Rig Number: 12/11/2001 00:00 - 01:00 1.00 PULL P DECOMP FINISH RIH WITH BURN SHOENVASH PIPE BHA TO 10,436' 01:00 - 07:00 6.00 PULL P DECOMP PICKED UP KELLY, BROKE CIRCULATION, TAGGED AT 10,465', MILLED OVER TO 10,485'( LOST TORQUE ) 07:00 - 09:30 2.50 PULL P DECOMP MILLED OVER FROM 10,485' TO 10,485.5' ( 6" ) 09:30 - 11:00 1.50 PULL P DECOMP REVERSE CIRCULATED 3 BOTTOMS UP, PUMPED DRY JOB 11:00 - 14:30 3.50 PULL :' DECOMP POOH TO BHA 14:30 - 16:00 1.50 PULL ~ DECOMP LAID DOWN BURN SHOE AND WASH PIPE, ( RECOVERED 4 GAL METAL CUTTINGS IN BOOT BASKETS ) 16:00 - 17:30 1.50 PULL ~ DECOMP MADE UP SPEAR BHA 17:30- 21:00 3.50 PULL ~ DECOMP RIH TO 10,442', KELLY UP 21:00 - 21:30 0.50 PULL 3 DECOMP WASH DOWN OVER PBR, PICKED UP 30,000 OVER WT, SET JARS OFF, PBR FREE 21:30 - 22:00 0.50 PULL ~ DECOMP PUMPED DRY JOB, BLOWED KELLY DOWN 22:00 - 00:00 2.00 PULL P DECOMP POOH WITH SPEAR BHA TO 4426' AT REPORT TIME 12/12/2001 I00:00 - 02:00 2.00 PULL P DECOMP POOH WITH SPEAR BHA ( NO RECOVERY ) 02:00- 02:30 0.50 PULL P DECOMP SERVICED RIG 02:30 - 03:30 1.00 PULL P DECOMP MADE UP SPEAR BHA ADDED 5' EXTENTION AND CHANGED BOTTOM GRAPPLE 03:30- 08:00 4.50 PULL P DECOMP RIH WITH SPEAR BHA 08:00 - 09:30 1.50 PULL P DECOMP KELLY UP, BROKE CIRCULATION, ENGAGED FISH AT 10,465' WORKED OVER 16' TO 10,481' GAINED 50 PSI PUMP PRESSURE, ENGAGED GRAPPLES, PICKED UP TO 155,000 LB ROTATED 39 TURNS TO RIGHT 28 TURNS BACK ( ROTATED SAME TWO TIMES ) 350 AMPS=I 5,500 FOOT LB TORQUE. PICKED UP SET OFF JARS ONE TIME. 09:30- 10:00 0.50 PULL P DECOMP PUMPED DRY JOB 10:00 - 14:00 4.00 PULL :' DECOMP POOH WITH 3 1/2" DRILL PIPE TO BHA 14:00 - 15:00 1.00 PULL 3 DECOMP LAID DOWN ACCELERATOR, DOWN JARS, LAID DOWN SPEAR, ( NO RECOVERY ) ( LOST UPPER SPEAR GRAPPLE IN HOLE ) 15:00 - 16:30 1.50 PULL ~ DECOMP MADE UP 8 1/8" BURN SHOE/8 1/8" WASH PIPE BHA COMPLETE WITH THREE BOOT BASKETS 16:30 - 17:30 1.00 PULL P DECOMP RIH WITH 3 1/2" DRILL PIPE TO 2250' ( PIPE OVERFLOW ) 17:30 - 18:00 0.50 PULL P DECOMP PUMPED SLUG, SERVICED DRAWWORKS AND BLOCKS 18:00 - 20:30 2.50 PULL P DECOMP RIH TO 10,435' 120:30 - 22:00 1.50 PULL P DECOMP MILL & WASH DOWN TO TOP OF PACKER AT 10,485', 22:00 - 00:00 2.00 PULL P DECOMP MILLING OVER PACKER AT 10,486' AT REPORT TIME, PUMP 1100 PSI, WT ON MILL 5/25 ROTARY RPM 60/70 TORQUE 7100/9500 FT LB UP WT=165K DOWN WT=126K ROTATING WT=145K 12/13/2001 00:00 - 10:00 10.00 PULL P DECOMP MILLED ON PACKER AT 10,486' ( UNABLE TO MAKE HOLE ) 10:00 - 10:30 0.50 PULL P DECOMP PUMPED DRY JOB 10:30 - 15:30 5.00 PULL :) DECOMP POOH WITH BURN SHOE/WASH PIPE BHA ( CLEAND BOOT BASKETS RECOVERED 4 GAL METAL CUTTINGS ) L/D JARS BOOT BASKETS AND WASH PIPE 15:30 - 20:30 5.00 PULL 3 DECOMP RIGGED UP SCHLUMBERGER, RIH WITH JET CUTTER, UNABLE TO ENTER PBR, POOH W/CUTTER RIGGED DOWN SCHLUMBERGER 20:30 - 22:30 2.00 PULL P DECOMP CLEANED FLOOR, MADE UP 6" TAPERED MILL BHA COMPLETE WITH 3 BOOT BASKETS, TOTAL LENGTH=336' 22:30 - 00:00 1.50 PULL P DECOMP RIH WITH TAPERED MILL BHA ON 3 1/2" DRILL PIPE TO Printed: 12/26/2001 8:37:28 AM Legal Well Name: 13-17 Common Well Name: 13-17i Spud Date: 11/15/2001 Event Name: WORKOVER Start: 12/6/2001 End: 12/25/2001 Contractor Name: DOYON Rig Release: 12/25/2001 Rig Name: Doyon 16 Rig Number: ....................... ...................... ....... ;~,%~ii~:~ ~,~;;~.%~i~¢;~i~%i::~:.:~~ 12/13/2001 22:30 - 00:00 1.50 PULL P DECOMP 4723' AT REPORT TIME 12/14/2001 00:00 - 02:00 2.00 PULL P DECOMP RIH WITH 6" TAPERED MILL BH TO 10,448' 02:00 - 03:00 1.00 PULL P DECOMP SLIP AND CUT DRILLING LINE 03:00 - 07:30 4.50 PULL P DECOMP KELLY UP, TAG AT 10,467' MILLED AND WASH DOWN TO 10,483', ( MILLED AT 10,485 ONE HOUR, MADE NO HOLE ) 07:30 - 08:00 0.50 PULL P DECOMP PUMPED DRY JOB, BLOWED KELLY DOWN 08:00 - 11:00 3.00 PULL P DECOMP POOH WITH 3 1/2"DRILL PIPE TO BHA 11:00 - 13:00 2.00 PULL iP DECOMP LAID DOWN MILL BHA, RECOVERED PBRAND" K" ANCHOR WEDGED ON MILL, RECOVERED 5 GAL CUTTINGS FROM BOOT BASKETS 13:00 - 16:00 3.00 PULL P DECOMP MADE UP PACKER MILL BHA COMPLETE WITH 3 BOOT BASKETS, BUMPER SUB, OIL JARS, 9 X 6 1/4" DRILL COLLARS, ACCELERATOR, AND 12 X 4 3/4" DRILL COLLARS 16:00 - 20:00 4.00 PULL :) DECOMP RIH WITH PACKER MILL BHA ON 3 1/2" DRILL PIPE TO 10480' 20:00 - 20:30 0.50 PULL ~ DECOMP TAG UP @ 10480'. WASH JUNK DOWN TO 10485' 20:30- 00:00 3.50 PULL 3 DECOMP MILL ON PACKER. 12/15/2001 00:00 - 06:00 6.00 PULL ~ DECOMP MILLED ON PACKER FROM 10,486' TO 10,488' 06:00 - 09:00 3.00 PULL 3 DECOMP CHASED PACKER TO 10,528' 09:00 - 09:30 0.50 PULL :) DECOMP PUMPED DRY JOB 09:30 - 15:00 5.50 PULL P DECOMP POOH WITH 3 1/2" DRILL PIPE TO BHA 15:00 - 17:00 2.00 PULL P DECOMP LAID DOWN MILL BHA ( RECOVERED PACKER ) LEFT 2 JOINTS 4 1/2" L-80 BUTT WITH COLLAR LOOKING UP,OTIS NO-GO, 4 1/2"X 10' PUP JTAND SHEAR OUT SUB IN HOLE ,17:00- 17:30 0.50 PULL P DECOMP PULLWEAR BUSHING ;17:30 - 22:00 4.50 PULL P DECOMP PRESSURE TEST BOPE. TEST WITNESSED BY JOHN CRISP W/AOGCC. 22:00 - 23:30 1.50 PULL P DECOMP SI WELL & TEST CASING TO 3000 PSI, OK. 23:30 - 00:00 0.50 PULL P DECOMP M/U SPEAR ASSY TO FISH TAIL PIPE. 12/16/2001 00:00 - 03:00 3.00 PULL P DECOMP FINISH MAKE UP SPEAR BHA, TOTAL LENGTH=393' 03:00 - 03:30 0.50 PULL P DECOMP RIH WITH SPEAR BHA TO 10,510° 03:30 - 04:30 1.00 PULL P DECOMP KELLY UP, WASH DOWN TO 10,545' PUMP PRESSURE INCREASED FROM 775 PSI TO 820 PSI 04:30 - 05:00 0.50 PULL P DECOMP PUMPED DRY JOB, BLOW KELLY DOWN 05:00 - 09:30 4.50 PULL P DECOMP POOH WITH 3 1/2" DRILL PIPE TO SPEAR BHA 09:30 - 10:00 0.50 PULL P DECOMP LAID DOWN SPEAR ( NO RECOVERY ) 10:00- 10:30 0.50 PULL :~ DECOMP SERVICED RIG 10:30 - 12:30 2.00 PULL 3 DECOMP !WAIT ON TOOLS FROM BAKER OIL TOOLS 12:30 - 16:00 3.50 PULL ~ DECOMP RIH WITH DOUBLE SPEAR BHA TO 10,531' 16:00 - 17:00 1.00 PULL ~ DECOMP KELLY UP, TAG AT 10,541' STACKED OUT AT 10,546' 17:00 - 21:30 4.50 PULL ~ DECOMP POOH WITH 3 1/2" DRILL PIPE & SPEAR, NO FISH. 21:30 - 00:00 2.50 PULL ~ DECOMP M/U BOX TAP ASSY & RIH. 12/17/2001 00:00 - 01:30 1.50' PULL ~ DECOMP FINISH RIH WITH BOX TAP BHA TO 10,510' 01:30 - 02:30 1.00 PULL 3 DECOMP SLIP AND CUT DRILLING LINE 02:30 - 04:00 1.50 PULL P DECOMP KELLY UP, BROKE CIRCULATION, TAG FISH AT 10, 541', WASH AND ROTATE TO 10, 553', PICKED UP 60, 000 OVER PULL TO 10,535' 04:00 - 09:00 5.00 PULL P DECOMP POOH 3 1/2' DP TO BHA 09:00 - 09:30 0.50 PULL P DECOMP LAID DOWN BHA ( NO RECOVERY ) '09:30- 10:00 0.50 PULL P DECOMP CLEAN FLOOR 10:00 - 11:00 1.00 PULL P DECOMP MADE UP 5 5/8" PILOT MILL BHA 11:00 - 15:00 4.00 PULL .P ~DECOMP RIH WITH MILL TO 10, 553' Printed: 12/26/2001 8:37:28AM Legal Well Name: 13-17 Common Well Name: 13-17i Spud Date: 11/15/2001 Event Name: WORKOVER Start: 12/6/2001 End: 12/25/2001 Contractor Name: DOYON Rig Release: 12/25/2001 Rig Name: Doyon 16 Rig Number: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~:;~::~::~j~ ~?~.::::::::%~.~.;~:~:~:....~.~;~ ~:~.~:~.~.~::~;~.~ ....................................... ;::;~;~.~ ............................................... 12/17/2001 15:00 - 17:30 2.50 PULL P DECOMP MILLED 4 1/2" TBG FISH FROM 10,553' TO 10, 568' ( ~ST 5' TOOK ONE HOUR ) 17:30 - 19:30 2.00 PULL P DECOMP CIRCUITED OUT HI VIS PILL 19:30 - 23:00 3.50 PULL P DECOMP POOH WITH MILL BHA 23:00 - 23:30 0.50 PULL P DECOMP CLEAN BOOT BASKETS, CLEAN FLOOR 23:30 - 00:00 0.50 PULL P DECOMP MAKE UP 5 7/8" OVERSHOT BHA 12/18/2001 00:00 - 03:30 3.50 PULL P DECOMP RIH W/3 112" DP & MILLING BHA. 03:30 - 05:30 2.00 PULL P DECOMP P/U KELLY, ROTATE DP INTO 7" LINER ~ 10,545'. WASH DOWN TO 10,552'. TAG & SEE 200 PSI INCREASE IN ClRC PRESSURE. RIG UP TO REV ClRC & R.C.. DRILL STRING PLUGGED OFF, SWITCH TO ClRC LONG WAY, UNABLE TO CL~R OBSTRUCTION. STAND BACK KELLY. 05:30 - 11:00 5.50 PULL 3 DECOMP POOH, (WET). 11:00 - 11:30 0.50 PULL 3 DECOMP ~D BHA. 11:30 - 12:30 1.00 PULL 3 DECOMP CLEAR RIG FLOOR & SERVICE RIG. 12:30 - 18:00 5.50 PULL 3 DECOMP RIH W/BURNOVER SHOE, WASHPIPE & OVERSHOT. 18:00 - 22:30 4.50 PULL 3 DECOMP CLEAN PITS & TAKE ON MUD. 22:30 - 00:00 1.50 PULL 3 DECOMP DISP~CE HOLE TO MUD. 165K UP ~, 123K DOWN, 140K ROT ~. 12/19/2001 00:00 - 01:30 1.50 PULL ~ DECOMP A~EMPT TO REVERSE ClRCU~TE, PLUGGED OFF SEVE~L TIMES, (VERY SMALL CLEA~NCE BE~EEN SHOE & 7" CASING) OPT TO GO LONG WAY. 01:30 - 03:00 1.50 PULL P DECOMP WASH DOWN FROM 10,552'-10,585'. 10,552'-10,553' TOOK WEIGHT & TORQUEY, MILLED THRU IN 10 MINUTES. ~N THRU SEVE~L TIMES TO SMOOTH OUT. TOP OF FISH AT 10, 568', SWALLOW APPROX 17' TO 10,585'. 03:00 - 04:30 1.50 PULL P DECOMP CBU TO CLEAN UP HOLE & TOP OF FISH. 04:30 - 05:30 1.00 PULL P DECOMP RIH TO ~TCH UP, FISH PUSHING DOWNHOLE TO 10, 589'. MAKE CONNECTION & TAG ~ 10,596'. STACK 25K, 400 PSI PRESSURE INCREASE ~ 22 SPM, FROM 500 PSI TO 900 PSI. PULL UP & MAINTAIN PRESSURE INCR~SE & SLIGHT D~G, (UP TO 10K). PUMP (2) JTS OUT OF HOLE TO CLEAR 7" & GET INTO 9 5/8". 05:30 - 13:00 7.50 PULL P DECOMP PUMP DRY JOB & POOH. (WET) 13:00 - 16:00 3.00 PULL 3 DECOMP UD FISHING BHA & FISH. RETRIEVED METAL & PACKER SLIP SEGMENTS IN TAILPIPE. SAND & METAL CU~INGS IN JUNK SUBS. 16:00 - 17:30 1.50 CLaN 3 DECOMP M/U JET BASKET ASSEMBLY. 17:30-22:00 4.50 CLEAN 3 DECOMP RIH WI3 1/2" DPTO 10,525'. 22:00 - 23:00 1.00 CLaN 3 DECOMP PJSM. SLIP & CUT 57.5' OF DRILLING LINE. 23:00 - 00:00 1.00 CLEAN 3 DECOMP KELLY UP. WASH TO 10,570'. (HAVE TO ROTATE THRU TOP OF 7" LINER ~ 10,545', BUT DID NOT SEE ANYTHING ~ 10,552'). 00:00- 0.00 CLaN P DECOMP 12/20/2001 00:00 - 00:30 0.50 CLEAN P DECOMP CONTINUE TO WASH DOWN TO 10,633', SEEING A BIT OF TORQUE, & TAKING 2-3K IN WEIGHT. 00:30 - 02:00 1.50 CLEAN P DECOMP CBU TO CLEAN UP HOLE. 02:00 - 03:00 1.00 CLEAN P DECOMP DROP 5~8" BALL & ClRCU~TE DOWN ~ 5 BPM/1500 PSI, SEE BALL ON SEAT W/5 BPM/1900 PSI. INCREASE ~TE TO 7 BPM/1900 PSI & WASH DOWN TO 10,646'. TAKING WEIGHT ~ 10,646', WASH/MILL W/3-5K WOB TO 10,648'. 03:00 - 05:00 2.00 CLEAN P DECOMP CIRCU~TE BOSOMS UP TO CLEAN HOLE. 05:00- 05:30 0.50 CLaN P DECOMP PUMP DRY JOB, STAND BACK KELLY. Printed: 12/26/2001 8:37:28AM Legal Well Name: 13-17 Common Well Name: 13-17i Spud Date: 11/15/2001 Event Name: WORKOVER Start: 12/6/2001 End: 12/25/2001 Contractor Name: DOYON Rig Release: 12/25/2001 I Rig Name: Doyon 16 Rig Number: ~i~iiii! ........... :ii!~i~ii:ii ii ........ : ........................................... ~ ~ ~ii!i~i~iii ~!i~ ~':,,~i)¢ ~:~: ~!;:i:i,~'~' ii 12/20/2001 05:30 - 09:30 4.00 CLaN P DECOMP POOH W/CL~NOUTASSEMBLY. 09:30 - 10:30 1.00 CLaN P DECOMP UD JET BASKET ASSEMBLY & EMP~ SAME. EMP~ JUNK SUBS. MOSTLY SAND & METAL CU~INGS. 10:30 - 11:00 0.50 CLaN P DECOMP M/U 6", AT J4 BIT TO CL~NOUT TO PBTD. 11:00 - 15:00 4.00 CLaN P DECOMP RIH W/CLEANOUT ASSEMBLY. 15:00 - 00:00 9.00 CLaN P DECOMP ~KELLY UP, WASH DOWN TO 10,648', TAG TOP OF CEMENT. MILL CEMENT/CEMENT STRINGERS TO 11,835', 3-5K WOB. NO RESISTANCE F/11,835'-11,259'. CEMENT/SAND BACK IN RETURNS. SUSTAIN LOSSES OF UP TO 1BPM ~ 11,250', TREAT W/PILL, LOSS ~TE DOWN TO 25 BPH. 12/21/2001 00:00 - 02:30 2.50 CLaN P DECOMP CONTINUE WASHING/R~MING IN 7" DOWN TO 11,496' DPM. TAG UP HARD, CALL THAT PBTD. LOSS ~TE 25 BPH PUMPING ~ 7.5 BPM/1500 PSI. 02:30 - 05:00 2.50 CLaN P DECOMP PUMP HI VIS SWEEP AROUND & ClRCU~TE B~MS UP. PLEN~ OF OILY SAND BACK, NO METAL. 05:00 - 06:00 1.00 CLaN P DECOMP SHORT TRIP TO TOP OF 7" LINER ~ 10, 540'. 06:00 - 10:30 4.50 CLaN P DECOMP P/U KELLY, BREAK ClRCU~TION & ClRCU~TE ~ 9 BPM/1850 PSI UNTIL HOLE CLANS UP. 10:30 - 11:00 0.50 CLaN P DECOMP RIH & TAG UP ~ 11,496'. 11:00 - 13:00 2.00 CLaN 3 DECOMP ClRCU~TE HI VIS SWEEP AROUND. 13:00 - 14:00 1.00 CLEAN 3 DECOMP POOH TO 10,930'. UD 17 JTS 3 1/2" DP. 14:00 - 14:30 0.50 CLaN 3 DECOMP SPOT25 BBLS, 5~/BBL BA~ CARB PILL ~ 10,930'. 14:30 - 20:00 5.50 CLaN 3 DECOMP POOH, UD 43 JTS 3 112" DP. STAND BACK 96 STDS. 20:00 - 21:00 1.00 CLaN ~ DECOMP UD BHA. CLEAN JUNK SUBS. 21:00-23:30 2.50 CLaN ~ DECOMP ~RIH&UD(9)6"DCs. RIH&UD(12)43/4"DCs. 23:30 - 00:00 0.50 CLaN P DECOMP SERVICE RIG & PREP TO RUN 4 1/2" LINER. 12/22/2001 00:00 - 04:00 4.00 REST P COMP PJSM. BAKER LOK & M/U FLOAT EQUIPMENT. RIH W/4 1/2" 12.6~, L-80 IBT LINER. ~04:00 - 05:00 1.00 REST P COMP M/U SBE & HANGE~PACKER ASSEMBLY. 28K UP ~, 25K DOWN. 05:00 - 06:00 1.00 REST P COMP RIH (1) STAND 3 1/2" DP, CIRCUITED LINER VOLUME & CL~RED FLOOR OF LINER RUNNING EQUIPMENT. 06:00 - 15:00 9.00 REST ~P COMP CONTINUE RUNNING IN HOLE W/3 1/2" DP. TAG UP ~ 11,472', HARD TAG. PICK UP KELLY & A~EMPT TO WASH DOWN, UNABLE TO WASH DOWN. 190K UP ~, 118K DOWN. 15:00 - 16:00 1.00 REST P COMP RIG UP CEMENT LINES, CEMENT H~D & PREP FOR CEMENT JOB. 16:00 - 16:30 0.50 REST 3 COMP W/LINER SHOE ~ 11,470', CIRCUITED ~ 5 1/2 BPM, 1100 PSI 16:30 - 17:00 0.50 REST ~ COMP PUMP 3 BBLS AHEAD, PT LINES ~ 4000 PSI, OK. 17:00 - 18:00 1.00 REST ~ COMP PJSM ON CEMENTING. TOTAL (5) BBLS WATER AH~D. PUMP 35 BBLS PREMIUM CEMENT, .7% HA~D-344, .5% UCS, .3% HR-5, .25 LBS/SK SUPER CBL. W/67 BBLS DISP~CED, SLOW ~TE TO 600 PSI/3BPM, SH~RED PLUG ~ 1800 PSI, W/74 BBLS AWAY. BUMPED PLUG ~ 2BPM/800 PSI, SAW PRESSURE INCR~SE TO 1200 PSI, 91.4 BBLS TOTAL DISP~CEMENT. 18:00 - 18:30 0.50 REST P COMP PRESSURE UP 3500 PSI ON DP, S~CK OFF 20K TO 95K, (SET LINER HANGER). BLEED PRESSURE & CHECK FLOATS, FLOATS HOLDING OK. ROTATE RIGHT (15) Printed: 12/26/2001 8:37:28AM Legal Well Name: 13-17 Common Well Name: 13-17i Spud Date: 11/15/2001 Event Name: WORKOVER Start: 12/6/2001 End: 12/25/2001 Contractor Name: DOYON Rig Release: 12/25/2001 Rig Name: Doyon 16 Rig Number: 12/22/2001 18:00 - 18:30 0.50i REST P COMP TURNS TO RELEASE SETTING TOOL. PRESSURE UP 1000 PSI ON DP, PICK UP TO ESTABLISH CIRCULATION. PUMP 40 BBLS @ 5 BPM/1100 PSI. SLACK OFF 60K ON ROTATING DOG SUB TO SET ZXP PACKER. REPEAT (3) TIMES, SAW PACKER SET. ROTATE W/60K SETTING DOWN TO ENSURE PACKER IS SET. 18:30 - 19:00 0.50 REST P COMP REVERSE CIRCULATE 2 1/2 DP VOLUMES, 7 BPM @1400 PSI, DID NOT SEE CEMENT BACK IN RETURNS. 19:00 - 20:00 1.00 REST P COMP PRESSURE UP ON 9 5/8" & TEST ZXP PACKER @ 3000 PSI/30 MINUTES, CHARTED, ROCK SOLID. BLEED PRESSURE. 20:00 - 22:00 2.00 REST P ~COMP REVERSE CIRCULATE & DISPLACE MUD OUT OF HOLE W/ CLEAN SEAWATER. 22:00 - 00:00 2.00 REST P COMP BREAK OFF & L/D CEMENT HEAD, BREAK KELLY & CLEAR FLOOR. PREP TO LAY DOWN DP. 12/23/2001 00:00 - 01:00 1.00 REST 3 COMP MIX & PUMP DRY JOB 01:00 - 10:00 9.00 REST 3 COMP POOH & LDDP. CLEAN PITS, RACK, TALLY & DRIFT 4 1/2" COMPLETION STRING. 10:00 - 10:30 0.50 REST 3 COMP L/D LINER RUNNING TOOL 10:30 - 11:00 0.50 REST 3 COMP PULL WEAR RING, CLEAR FLOOR 11:00 - 15:30 4.50' REST 3 COMP RACK, TALLY & DRIFT REMAINDER OF COMPLETION STRING. 15:30 - 00:00 8.50 REST P COMP PJSM. RIH W/SEAL ASSEMBLY & 4 1/2" COMPLETION STRING, GATOR HAWKING & TORQUE TURNING EACH CONNECTION. 12/24/2001 00:00 - 14:30 14.50 REST P COMP CONTINUE IN HOLE W/COMPLETION STRING. 203 JTS 4 1/2" 12.6~, L-80, NSCT TUBING. 14:30 - 15:30 1.00 REST P COMP M/U CAMCO SSSV BAL-O W/DUMMY & CONTROL LINES. TEST TO 5000 PSI, OK. 15:30 - 21:00 5.50 REST P COMP CONTINUE IN HOLE W/4 1/2" NSCT TUBING & C-LINES. 260 JTS. 12OK UP, 90K DOWN 21:00 - 22:00 1.00 REST P COMP M/U ClRC HEAD, & RIH W/#260 PUMPING @ 1 BPM. SEE PRESSURE INCREASE W/7-8' OF JOINT IN & HOLD. BLEED PRESSURE & LOCATE OUT W/22.5' IN ON JT. # 260. PICK UP OUT OF SBR. 22:00 - 00:00 2.00 REST 3 COMP DISPLACE TO HOT WATER W/CORROSION INHIBITOR. PUMP 600 BBLS 150 DEGREE SEAWATER W/CORROSION INHIBITOR DOWN TUBING & FOLLOW WITH 150 BBLS SEAWATER FROM PITS. 12/25/2001 00:00 - 00:30 0.50 REST P COMP PJSM W/NEW CREW COMING ON. CONTINUE TO DISPLACE WELL TO HEATED SEAWATER, W/HEATED SEAWATER / CORROSION INHIBITOR IN 9 5/8" x 4 1/2" ANNULUS. 00:30 - 03:30 3.00 REST P COMP RELOCATE OUT IN SBR, 21' IN ON JOINT #260. RKB 19.50'. PULL JT #260, 259, (39.67'), & JT #258. M/U SPACE OUT PUPS, (3.69', 9.52', & 19.81'). M/U JT# 258. M/U TBG HANGER & PUP, (7.05'). M/U LANDING JOINT & GATOR HAWK ALL CONNECTIONS. SPACE OUT WILL PUT SEAL ASSEMBLY APPROXIMATELY 1' UP FROM BEING LOCATED OUT IN SBR. RIG DOWN GATORHAWKS. 03:30 - 04:30 1.00 REST P COMP MAKE UP CONTROL LINES TO TUBING HANGER & TEST, 5000 PSI, OK. 04:30 - 08:00 3.50 REST 3 COMP PJSM. PT LINES, OK. CLOSE BAG. HEAT & PUMP 140 Printed: 12/26/2001 8:37:28AM Legal Well Name: 13-17 Common Well Name: 13-17i Spud Date: 11/15/2001 Event Name: WORKOVER Start: 12/6/2001 End: 12/25/2001 Contractor Name: DOYON Rig Release: 12/25/2001 Rig Name: Doyon 16 Rig Number: ........................................ · ,"..'~~ ~ :;~;~;,~ 12/25/2001 04:30 - 08:00 3.50 REST P COMP BBLS DIESEL @ 100 DEGREES DOWN 9 5/8" x 4 1/2" ANNULUS. ALLOW DIESEL TO U-TUBE BACK INTO 4 1/2" TUBING. 08:00 - 09:00 1.00 REST P COMP OPEN BAG, DRAIN STACK, LAND TUBING HANGER, RUN IN LOCKDOWN SCREWS. 09:00 - 11:00 2.00 REST P COMP PRESSURE TEST TUBING W/IA OPEN, 3000 PSI/30 MINUTES, CHARTED, OK. PRESSURE TEST 9 5~8" x 4 1/2" AGAINST TUBING HANGER & SEALS IN SBR W/TUBING OPEN, 3000 PSI/30 MINUTES, CHARTED, OK. BLEED OFF PRESSURE. 11:00 - 11:30 0.50~ REST P COMP SET BPV. 11:30 - 17:00 5.50 REST P COMP PJSM. PULL BACK STRIP-O-MATIC. RIG DOWN DRAIN HOSES & LINES. N/D BOPE. 17:00 - 20:30 3.50 REST P COMP N/U ADAPTER FLANGE & TREE. 20:30 - 22:30 2.00 REST P COMP PT ADAPTER FLANGE @ 5000 PSI, OK. PT TREE @ 5000 PSI, CHARTED, OK. M/U & PT CONTROL LINES @ 5000 PSI, OK. 22:30 - 00:00 1.50 REST P COMP CLEAN OUT CELLAR, SECURE WELL. RIG RELEASED @ MIDNITE, 12/25/2001. , Printed: 12/26/2001 8:37:28AM ?-",, STATE OF ALASKA ~ ALASK~ OIL AND GAS CONSERVATION COMIv,,$SION 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 Convert to WAG Injector 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface V/ 2703' SNL, 1634' WEL, SEC. 14, T10N, R14E, UM At top of productive interval 2533 NSL, 3052' WEL, SEC. 11, T10N, R14E, UM At effective depth 2181' NSL, 3039' WEL, SEC. 11, T10N, R14E, UM At total depth 2842' NSL, 3046' WEL, SEC. 11, T10N, R14E, UM Type of well: r"l Development [] Exploratory I-I Stratigraphic I~ Service RECEIVED AUG g 9 2001 Alaska Oil & Gas Cons. Commission Anchorage 6. Datum Elevation (DF or KB) RKB = 87' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 13-17 9. Permit Num. b~" 182-026 ~" 10. APl Number 50- 029-20718-00 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 Structural Conductor Surface Intermediate Production Liner 11551 feet 9172 feet Plugs (measured) 10506 feet Junk (measured) 8364 feet Set IBP at 10506' Length Size Cemented 78' 20" 1706# Poleset 2507' 13-3/8" 2450 sx Arcticset III 10848' 9-5/8" 500 sx Class 'G' 997' 7" 365 sx Class 'G' MD TVD 78' 78' 2507' 2507' 10848' 8623' 10551'-11548' 8398'-9170' Perforation depth: measured true vertical 11050'-11105', 11129'-11159', 11166'-11186', 11202'-11272' 8779'-8822', 8841'-8865', 8870'-8886', 8899'-8953' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 10511'; 4-1/2", 12.6#, L-80 10511' to 10587' Packers and SSSV (type and measured depth) Baker '3-H' packer at 10500'; Otis 'RQM' SSSV Nipple at 2158' 13. Attachments [] Description Summary of Proposal I"] Detailed Operations Program [] BOP Sketch 14. Estimated date for commencing operation 115. Status of well classifications as: September 7, 2001 I [] Oil ~ Gas I-1 Suspended 16. If proposal was verbally approved Service Water & Gas Injector Name of approver Date Approved Contact Engineer Name/Number: Archie Po!e~chuk, 564.5620 Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregqing~[ tru.e~J~l corr~c~t to the best of my knowledge Signed ArchiePoleschuk ...~/~~___~ Title Drilling Engineer Date~ ~..~ representative may witness "Z,_~ ~ ~\ '~,L.~'~:> Conditions of Approval: Notify Commission so ,, ...~O__ ,_ .... Plug integrity BOP Test 7',. Location clearance Mechanical Integrity Test -'-'~' Subsequent f°rm required 1 O' ~'~'(~ ~":~ I Approved by order of the Commission ORIGINAL SJ,~I~D, B,,.Y,, , ~ Commissioner Date ~'/¢-~l~/th / Form 10-403 Rev. 06'15'88 D,.,,or ttrb I iq A L Submit Ir~ Tri~3li(~ate ' Scope DS13-17i RWO Well 13-17i is currently a PWI that is being converted to WAG injection. A Kinley survey ran in June 2000 indicated four joints with possible holes and 201 joints in poor condition from 41 to 85% wall loss. Corrosion is present throughout the tubing string. The work scope includes pulling the existing 5 1~,, L-80 completion and re-completing with a 5 1/2" L-80 premium tubing and stacker packer completion with a custom overshot. This workover will take 8 days to complete, not including the rig move. The workover will cost approximately $1.0 MM. Pre-Riq Work 1. Test the 9 5/8" mandrel packoff and tubing hanger (through test port) to 5000 psi. If the packoff tests, completely back out and check each 9 5/8" x 5 1~,, lock down screw for breakage (check one at a time). If tested recently, email or fax in test report. 2. Set slickline plug in 4-1/2" tubing tail in XN nipple at 10,574'MD. Top with sluggit. Test casing and packer to 3500 psi. 3. RU wireline. Punch holes in tubing at approximately 10,445'MD. Circulate well through tubing punch holes. 4. Cut 5-1/2" tubing above packer at 10500'. Cut at approximately 10475'MD. 5. Freeze protect tubing and casing with diesel from 2000' to surface. 6. Set a BPV and remove well house and flowlines. 7. Clear and level pad in preparation of rig move. Assure annuli are freeze protected. Ri.q Workover Procedure (8 davs} 1. MIRU. ND tree, NU and test BOPE. Circulate out freeze protect fluid and circulate well to clean seawater. (1 day) 2. POH with existing 5-1/2" tubing string down to the cut @ 10475'MD. (2 days) 3. RU braided line and make GR/JB run to 10400' MD. (1/2 day) 4. Replace 9-5/8" packoff if necessary. (1/2 day) 5. Run new 5-1/2" L80 stacker packer completion with custom overshot. Land tubing in spool. (2 days) 6. RU slickline. Drift tubing to ensure access through 10,600'MD. (1/2 day) 7. Set 9-5/8" x 5-1/2" packer in 5-1/2" tubing @10450'. (1/2 day) 8. Test tubing to 3500 psi, test annulus to 3500 psi. Freeze protect to below permafrost. (1/2 day) P. Set BPV, ND BOPE, NU and test tree. Tree is carbon steel. RDMO. (1/2 day) Post Ri.q Procedure 1. RU slickline and retrieve RHC sleeve. 2. Pull XN plug. 3. RU coil. Clean out to TD in preparation for Victor Adperfs. 4. Install flowline and reset the well house. Call me at 564-5791 if you have any questions. Barbara M. Holt Workover/Drilling Engineer NiP Tubing-PC Casing Casing PBR PKR XO Tubing-PC 10574' MIN ID= 001" (41/2 Otis XN Nip) NOGO Liner SOSUB TTL Per[ Perf Ped Pert APl: 500292071800 Odg Compitn: 4/14/82 AnCe @ TD: 38 deg @ 11551 SSSV Type: Last wig: 4/8/82 Rev Reason: Tag (kak) Annular Fluid: Diesel/10 6 NaCI Ref Log Date: 4/3/82 Last Update: 2/29/00 Reference Log: BHCS RKB: 87 f~ LastTag: 10500'SLM TD: 11551 ftKB Last Tag Date: 1/16/00 Max Hole 57 de9 ~ 7100 Angle: Well Type: INJ Angle @ TS; 38 de9 @ 11052 Depth An~0tati0r~s Depth Comment 10574 10574' MIN ID= ,001" (4-1/2" OdsXN Nip safety Notes Date Note t 0/5/g6 LDL Indicates Maior Leaks @ 924Z & g318';Smaller Leaks @ -98g0~ & g665' 2/23/00 WAWERED WELL - T x IA Cemm, LDL shows 3 leaks in tbg IA × gA Communication. 8~ T~g P@ck-offs Water i~ cellar when 8gL Ger~eral N0tes Date Note 4/14/62 TTL ELM @ 105~4: ~LM Tubiog Tail/Logged GR 01/23/~6/ othe~ (plugsi equip;i etc;) ~ JEWELR¥ Depth TVD Type Description ID 2158 2158 NiP 5-1/2" Otis RQM SSSV Nipple 4562 10482 8346PBR 5~1/2" BeT PBR Assembly 0000 10500 8359PKR 9-5/8" x 5~I/2" BeT 3-H Packer 0000 10511 8368XO Crossover 5-1/2' x 4~1/2" 4500 10574 8415NOGO 4-1/2" Otis XN Nipple ID=3 725 0001 10586 8424SOSUB 4~112" BeT Shearout Sub 0000 10587 8425]q'L 4-112" Tubin9 Tail 0,000 Size Weight Grade Top Btm Feet Description 7000 2900 L-80 10551 11548 997 Liner 9625 4700 L-80 0 10848 10~8 Casin9 13.37572.00 L~80 0 2507 2507 Casing Size WeightGrade Top Btm Feet Description 5500 1700 L-80 0 10511 10511 Tubing-PC 4.500 12.6d;L-80 10511 '1058776 Tubi~9-PC Perf0rati0~S Interval TVD Zone StatusFeet~PF Date Type Comment 11050~11105 8779-8822ZONE O 55 48/4/82 IPERF 4,GOC 11129-11159 8841-8865ZONE4 O 30 48/4/82 IPERF 11166-11186 8870~8886ZONE4 O 20 48/4/82 IPERF 11202 * 11272 8898 - 8953 ZONE 4 O 70 48/4/82 IPERF DS 13-17 Proposed Completion 13-3/8" 72# L-80 (2507' MD) · 7" 29# L-80 Liner (10551' MD) 9-5/8" 47# L-80 ( 10848' MD) 7" 29# L-80 Liner (TD @ 11548' MD) 5-1/2" SSSV Nipple (-2200' MD) 5-1/2" 17# L-80 tubing 5-1/2" BOT PBR Assembly (-10500' MD) 9-5/8" x 5-1/2" BOT 3-H Pkr (-10520' MD) 5-1/2" x 4-1/2" X-over (-10530' MD) 4-1/2" Otis 'XN' Nipple, ID=3.725" (-10560' MD) 4-1/2" 12.6# L-80 scab liner to bottom Perforations (Isolated with scab liner) 11050-11105' MD 11129-11159' MD 11166-11186' MD 11202-11272' MD ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 \. 19 January, 2000 Mr. David Johnston, Chairman Alaska Oil & Gas Conservation Commision 3001 Porcupine Drive Anchorage, AK 99501 Fax 276-7542 RE: DS 13 MI Expansion Dear Mr. Johnston, The purpose of this letter is to notify you of changes to the injected fluids into wells 13-17, 13- 18 and 13-20. These injectors have been injecting produced water since the 1985. Facility modifications are currently underway to enable these wells to inject miscible injectant (MI) in addition to produced water. The expansion of MI to these patterns is for EOR purposes and offset producers are expected to capture an additional 3 MMBO. Facility work is expected to be completed in March, and the wells are expected to begin their first MI injection cyCles in April. If notification beyond this letter is required, or you need additional information please let me know. I can be reached at 265-1614 with questions. Sincerely, R. Andrew Parker Senior Drillsite Production Engineer Prudhoe Bay Resource Development cc: M. Bill ATO-1530 ,~ Re[: Pmdhoe Bay Unit Well 13-17i Applic .... Form/'~03. Supplemental Information Subject: Re: Prudhoe Bay Unit Well 13-17i Application for Sundry Approvals, Form 10-403. Supplemental Information Date: Fri, 17 Dec 1999 11:39:06 -0900 From: Tom Maunder <tom_maunder~admin. state.ak.us> Internal To: Michael R Niznik <MNIZNIK@mail.aai.arco.com> CC: Blair Wondzell <blair_wondzell~admin. state.ak.us> Mike, You propose to modify the existing approval for 13-17i to only cement approximately the lowest 2500' of the IA. The reason for the change is a delay in changing over to MI. It is planned to continue injecting water for some additional 6 months. As stated in you reply, below, ARCO believes cementing of the lower portion of the well and the holes in the tubing to be prudent at this time. Your modification is approved. Good luck. Tom Maunder Petroleum Engineer AOGCC Michael R Niznik wrote: Tom, We believe that cementing the lower portion of the well at this time will be the most prudent course of action, but we appreciate your note regarding continued water injection under a Commission approved waiver. sincerely, Michael R. Niznik Workover Engineer ARCO Alaska, Inc. 263-4561 Tom Maunder <tom maunderSadmin.state.ak.us> on 12/17/99 10:13:02 AM -- To: Michael R Niznik/AAI/ARCO cc: blair wondzellSadmin.state.ak, us -- Subject: Re: Prudhoe Bay Unit Well 13-17i Application for Sundry Approvals, Form 10-403. Supplemental Information Mike, Thanks for the note. You propose to modify the approved plan due to the delay in getting MI to the well. On further review of the submitted 403 for the original work, I am prompted to ask since you plan to continue injecting water for ~ the next 6 months ... is any cementing really necessary at this time? It is stated in the 403 letter that the well passed MITs. On that basis we could approve continued injection as long as pressures and rates are monitored daily and reported monthly to the Commission. We have given this approval on a number of other wells. Please discuss with your supervisors and get back to us. This may simplify this whole thing. Thanks. Tom Maunder Petroleum Engineer AOGCC Michael R Niznik wrote: 1 of 2 12/20/99 8:44 AM Re: Pmdhoe Bay Unit Well 13-17i Applic .... Form/~'q~03. Supplemental Information ~"-, > > Tom, > > > > Per our discussion regarding 13-17i earlier this morning. We propose an > interim > > step in the Application For Sundry Approvals Form 10-403, approval no'. > 399-238. > > > > This interim step would consist of pumping 15.8 ppg Latex Acid Resistant > Cement > > (Class G) into the inner annulus from the packer at 10,501' MD up to ~8000' >MD. > > The known holes in the tubing are in this region of the tubing. The tubing > > above this region has wall loss that will necessitate bringing cement to > > surface, but after we start injecting Miscible Injectant (MI). The water > > portion of the Water Alternating Gas (WAG) cycle has been extending so we > expect > > the Miscible Injectant (MI) leg to be delayed (6+ months?). > > > > We believe that this is the most prudent course of action to take since our MI > > stage has been delayed. We will perform an MIT on the inner annulus to 2000 > psi > > once we place the cement in the IA. If the IA passes the MIT test we will > place > > it on injection. If the test fails, we have the Sundry approval to bring > cement > > to surface and test it by cement quality log and spinner survey per procedure > > dated 11/17/1999. > > > > Thank you for your time and please call me if you have any questions. > > > > Sincerely, > > > > Michael R. Niznik > > Workover Engineer > > ARCO Alaska, Inc. > > 263-4561 Tom Maunder <tom maunder@admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 12/20/99 8:44 AM [FWd'. Prudh°e Bay Unit Well 13-17i Appl...,Form Y~. Supplemental Information] ,, Subject: [Fwd: Prudhoe Bay Unit Well 13-17i Application for Sundry Approvals,Form 10-403. Supplemental Information] Date: Thu, 09 Dec 1999 14:11:50-0900 From: Blair Wondzell <blair_wondzell@admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: aogcc north slope address <aogcc_prudhoe_bay~admin.state.ak.us> Subject: Re: Prudhoe Bay Unit Well 13-17i Application for Sundry Approvals,Form 10-403. Supplemental Information Date: Thu, 09 Dec 1999 14:11:10-0900 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Michael R Niznik <MNIZNIK~mail.aai.arco.com> CC: Robert Crandall <bob_crandall~admin. state.ak.us>, Stephen F Davies <steve_davies~admin. state.ak.us>, Jack Hartz <jack_hartz~admin. state.ak.us>, Tom Maunder <tom_maunder@admin.state.ak.us> Michael, Thanks for the e-mail. We agree with your proposal and will therefore process the 10-403. Thanks, Blair Wondzell 12/9/99 Michael R Niznik wrote: Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission Per our conversation on 12/08/99 regarding the planned annular isolati©n squeeze of well 13-17i. To demonstrate a competent Inner Annulus (IA) in a well where cement is brought to surface, we propose the following two diagnostic methods. (1) Run an Ultra-Sonic Imaging Tool (USIT) after cement is placed to demonstrate IA fillage. Two cement blends will need to be used in the IA, an arctic set in the permafrost region and a neat cement below. The two cement blends have varying compressive strengths so the threshold settings on the USIT log will be adjusted to compensate for the differences. (2) A spinner survey will be run after the USIT log to demonstrate that all of the flow is out the end of the tubing tail. Repeat spinner surveys will be conducted every four (4) years in lieu of the Inner Annulus MIT. We appreciate the AOGCC working with us on this very new and different approach to repairing injection wells and look forward to working with you on our various projects in the future. Sincerely, Michael R. Niznik Workover Engineer ARCO Alaska, Inc. 1 of 1 12/9/99 2:12 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__ RKB 87 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service __x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2700' FNL, 1633' FEL, Sec. 14, T10N, R14E, UM 13-17i At top of productive interval 9. Permit number / approval number 2534' FSL, 2221' FWL, SEC. 11, T10N, R14E, UM 82-26 At effective depth 10. APl number 50-029-20718 At total depth 11. Field / Pool 2438' FNL, 3047' FEL, Sec. 11, T10N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11551 feet Plugs (measured) PBTD tagged @ 11284' MD (5/20/1999) true vertical 9172 feet Effective depth: measured 11284 feet Junk(measured) ORIGINAL true vertical 8963 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 78' 20" 1706# Poleset 78' 78' Surface 2420' 13-3/8" 2450 sx AS m 2507' 2507' Production 10761' 9-5/8" 50o Sx C~ass G 10848' 8623' Liner 997' 7" 365 Sx C~ass G 11548' 9170' Perforation depth: measured 11050'- 11105'; 11129'- 11159'; 11166'- 11186'; 11202'- 11272'. true vertical 8779'-8822'; 8841'-8865'; 8870'-8886'; 8898'-8953'. RE( EIVEI) Tubing (size, grade, and measured depth 5-1/2", NOV 19 1999 Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BOT 3-H PACKER @ 10501' MD. 5-1/2" OTIS RQM SSSV @ 2159' MD. 13. Attachments Description summary of proposal __X Detailed operations program m BOP sketch __X 14. Estimated date for commencing operation 15. Status of well classification as: December 1, 1999 16. If proposal was verbally apProved Oil __ Gas Name of approver Date approved Service MI Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mil(e Niznil( @ 263.4561. Signed ~~"~/ ~~" ~ ~'~ Title: AAI Wellwork Design & Optimization Supervisor Date Erin Oba Prepared by Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: PlugN°tify Commission so representative may witneSSint6grity __ BOP Test __ Location clearance __ Mechanical Integrity Test Subsequent form required lO- Approved by order of the Commission .-'.m,.'",,.,AB ~l~l~,.r~ m...,' Commissioner Date /C~'''~ Robert N. Christenson Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 13-17iAnnular Isolation Squeeze Primary Ob. iecfive Cement the tubing x inner annulus with 11 ppg LiteCRETE cement from the production packer up to 2500' and 10.7 ppg Arctic Set Lite 3 from 2500' to surface. A Kinley caliper survey was run on 6/4/99 and showed several holes in the tubing below 8500' MD and some wall loss above. The degree of wall loss necessitates bringing cement to surface. The well passed a combination MIT Tubing x Inner- Annulus to 3000 psig and MIT Outer Annulus to 2000 psig on 10/19/99. 1. RU Slickline and drift/tag. 2. RU CTU. Place sand plug over perforations and in tubing up to - 10,500'. 3. RU E-Line. Shoot circulation holes in tubing from 10,440'-10,450'. 4. RU Slickline and drift/tag. . RU cementers (fullbore job). Circulate 110 bbls of 10.7 ppg Arctic Set Lite 3 (ASL3) and 350 bbls of 11 ppg LiteCRETE cement into the inner annulus. The ASL3 will be placed from surface to 2500' and the LiteCRETE will be from 2500' to 10,511'. The tubing will be balanced with weighted drilling mud. 6. Wait on cement 5 days. . RU CTU. Mill out cement to sand interface & pressure test inner annulus. FCO to TD. 8. RU Slickline and run SSSV. 9. Put well on WAG injection. RECEIVED 6 5 4 3 2 COILED 'TUBING UNIT BOP EOU l PMEN7 1. 50C)C) PSI 7" WELLHEAD CONNEC10R FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYD~LC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. ~)00 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX RECEIVED .~.,,vv 19 3999 2 HIREL]NE BOP EOUIPMENT 1. 51:)00 PSI 7" WELLHEN) CONNECIOR fLANGE 5000 PSI WIRELINE RAUS (VARIABLE SIZE) 5000 PS1 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Orr ARCO ALASKA, INC. NIP Tubing-PC Casing Casing PBR PKR XO Tubing-PC 10574' MIN ID= .001" (4-1/2" Otis XN Nip) NOGO Liner SOSUB TTL Perf Perf Perf ,," Prudhoe Bay 13-17 APl: 500292071800 Well Type: INJ Angle @ TS: 38 deg @ 11052 SSSV Type: Orig Compltn: 4/14/82 Angle @ TD: 38 deg @ 11551 Annular Fluid: Diesel/10.6 NaCI Last W/O: 4/8/82 Rev Reason: CORRECT/Visual Reference Log: BHCS Ref Log Date: 4/3/82 Last Update: 6/18/99 LastTag: 11284 ELM TD: 11551 ftKB Last Tag Date: 5/20/99 Max Hole 57 deg @ 7100 Angle: Depth Comment 10574 10574' MIN ID= .001" (4-1/2" Otis XN Nip) Date Note 10/5/96 LDL Indicates Major Leaks @ 9242' & 9318';Smaller Leaks @ -9800' & 9865' Date Note 4/14/82 TTL ELM @ 10564: ELM Tubing Tail (Logged GR 01/23/88) Depth TVD Type Description ID 2158 2158 NIP 5-1/2" Otis RQM SSSV Nipple 4.562 10482 8346 PBR 5-1/2" BOT PBR Assembly 0.000 10500 8359 PKR 9-5/8" x 5-1/2" BOT 3-H Packer 0.000 10511 8368 XO Crossover 5-1/2" x 4-1/2" 4.500 10574 8415 NOGO 4-1/2" Otis XN Nipple ID=3.725 0.001 10586 6424 SOSUB 4-1/2" BOT Shearout Sub 0.000 10587 8425 TTL 4-1/2" Tubing Tail 0.000 Size Weight Grade Top Btm Feet Description 7.000 29.00 L-80 10551 11548 997 Liner 9.625 47.00 L-80 0 10848 10848 Casing 13.375 72.00 L-80 0 2507 2507 Casing Size Weight Grade Top Btm Feet Description 5.500 17.00 L-80 0 10511 10511 Tubing-PC 4.500 12.60 L-80 10511 10587 76 Tubing-PC Interval TVD Zone Status FeetSPF Date Type Comment 11050-11105 8779-8822 ZONE O 55 4 8/4/82 IPERF 4,GOC 11129-11159 8841-8865 ZONE4 O 30 4 8/4/82 IPERF 11168- 11186 8870- 8886 ZONE 4 O 20 4 8/4/82 IPERF 11202 - 11272 8898 - 8953 ZONE 4 O 70 4 8/4/82 IPERF RECEIVED 19 1999 b~ 13-17F Annular Isolation Sque=ze 10.7 ppg ASL3 0' - 2500' MD 5-1/2" SSSV @ 2158' MD. 5-1/2", 17#, L-80, PC Tubing f/ Surface to 10511' MD 11.0 ppg LiteCRETE 2500'- 10511' MD Punch Tubing Holes -10440' - 10450' MD. 9-5/8" X 5-1/2" BOT 3-H Packer @ 10511' MD. 9-5/8" Production Casing, 47#, 0'- 10848" MD 7" Liner 29# @ 10551' - 11548' MD 4-1/2" 12.6# L-80 PC Tubing 10511'- 10587' MD. RECEIVED i,~uV 19 1999 pcr 7/30/1999 ~ [F~d: Prudh'oe Bay Unit Well 13-17i Appl...,Form 1~-403. Supplemental Information] Subject: [Fwd: Prudhoe Bay Unit Well 13-17i Application for Sundry Approvals,Form 10-403. Supplemental Information] Date: Thu, 09 Dec 1999 14:11:50-0900 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: aogcc north slope address <aogcc_prudhoe_bay~admin.state.ak.us> Subject: Re: Prudhoe Bay Unit Well 13-17i Application for Sundry Approvals,Form 10-403. Supplemental Information Date: Thu, 09 Dec 1999 14:11:10-0900 From: Blair Wondzell <blair_wondzell@admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Michael R Niznik <MN]ZNIK@mail.aai.arco.com> CC: Robert Crandall <bob_crandall~admin. state.ak.us>, Stephen F Davies <steve_davies@admin.state.ak.us>, Jack Hartz <jack_hartz~admin.state.ak.us>, Tom Maunder <tom_matmder~admin. state.ak.us> Michael, Thanks for the e-mail. We agree with your proposal and will therefore process the 10-403. Thanks, Blair Wondzell 12/9/99 Michael R Niznik wrote: Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission Per our conversation on 12/08/99 regarding the planned annular isolation squeeze of well 13-17i. To demonstrate a competent Inner Annulus (IA) in a well where cement is brought to surface, we propose the following two diagnostic methods. (1) Run an Ultra-Sonic Imaging Tool (USIT) after cement is placed to demonstrate IA fillage. Two cement blends will need to be used in the IA, an arctic set in the permafrost region and a neat cement below. The two cement blends have varying compressive strengths so the threshold settings on the USIT log will be adjusted to compensate for the differences. (2) A spinner survey will be run after the USIT log to demonstrate that all of the flow is out the end of the tubing tail. Repeat spinner surveys will be conducted every four (4) years in lieu of the Inner Annulus MIT. We appreciate the AOGCC.working with us on this very new and different approach to repairing injection wells and look forward to working with you on our various projects in the future. Sincerely, Michael R. Niznik Workover Engineer ARCO Alaska, Inc. 1 of 1 12/9/99 2:12 PM ) ) ARca Alaska Inc. Attn: Problem Well Specialist, PRB 24 Post Office Box 100360 Anchorage, Alaska 99510-0360 ~~ ~~ October 2, 1999 \<b~OW Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: 03-11 Monthly Pressure Data, Per State Sundry Approval #399-084 "\~ -~~ "..I 11-29 Monthly Pressure Data, Per State Sundry Approval #398-035 ~~-CS '). ~>",,, 13-15 Monthly Pressure Data, Per State Sundry Approval #399-091 ~") -\::) \s~.I 13-17 Monthly Pressure Data, Per State Sundry Approval #298-275 5s~ - ()c)...~./ 13-20 Monthly Pressure Data, Per State Sundry Approval #397-078 ~~ -()~(,)~\ / P1-01 Monthly Pressure Data, Per State Sundry Approval #398-188 ~S -ð~ ~ (..1) J P2-34 Monthly Pressure Data, Per State Sundry Approval #398-243'~() -~C\J. ~ .? Dear Mr. Wondzell: Attached please find daily injection reports on Wells 03-11, 11-29, 13-15, 13-17, 13-20, P1-01 and P2-34 for the month of September 1999. This report is submitted to comply with the State Sundry Approvals listed above. Also attached are MITIA reports conducted on injectors. If you require any additional information, please contact Jerry Dethlefs or me at (907) 659-5102. Sincerely, (u{~ ) Joe Anders Problem Well Specialist SCANNE£.) ~JAN 11 2006 \S k,,'\ " \ - ".' ~ \ -..) '""" Q. ~ -\ ~ ().. ,Q.. CJ...'\,,)\-c:;~"'_c. \- t '-.. .... <-~I\ ~,~s~·~'Cè..~ ~"- ,,-CA~ ~' Ð\:~~~~ h l" ~ L \' _ \o....\-~ ~ ~~~~,,"i... ~ '^ 'c:ë.. \ ~ "" \~~~c..) '")'1 c...c: ... <::'\'- ,:. ö'" <::>" \-...'<- n'0 "- \ \ "> <... ~ 1.. (""",,- \\.. -v.::,ç, -- '--: \ _ _ . , .\ "'-\"'-. \-' . .... ~s'~c..~' a'~ \...), ~ ~<¿ ~c:,~~~ ú.. '-0 N\,ç'o'''',,:>C>~ <oÇ ~~~ \"> ~~~ . a ~ '\. u()..~<¿~ ,,~ .;.~u~<¡_ W\ \-"'-. .~.<-\~Ç... d 1f'-0 ""'~""""\-\'" O-C; c........ c.yU~'\G. c- -t(::) co '4'^-~t..\..\R ~;",) \r\.,y-.....\. ~ ,,,-_~':,.~'~ ~l o.~'\í'~ \'Ù~ ~ ç-c:(_ ~~ù \€.. L Ç. ~~~ ~ \ ~ ·5"00 ~\ o (" \ « ~ ~ ..\..~ '1 \ f\. '0 ~-~ \,~ ~~ ~ . - O~"--.o. ~,---,. <::.L>-"- ---,.ec. \- C). \u.n'" "- 011'- '- "-~\ '0<\'¿) vc>- \ -N" \.. \. \>~.,;<;. '-.) ,r¿",> ~ ,'X~ " ç ~~'{ ~c."I. '" \- \-0 ~'" (:) ;¡,,\ \-0 ~ ~C) \ c<. c.\c::.. ~ Q. \ '4 . / . I ~\ ) \ ~d- -0 d-Co ) ARCO Well 13-17 September 1999 Injection Data Date of Injection 9/1/99 9/2/99 ___ _____._____.....u_" 9/3/99 9/4/99 . '. ~..~."-,_..,. --.......---.. --.... 9/5/99 . -,.. ._._---.----_.._._.~- 9/6/99 "---.. -_..,.._~_._...".__..- 9/7/99 9/8/99 9/9/99 9/10/99 9/11/99 9/12/99 9/13/99 9/14/99 ._.,-_..,....._."_...-.-,.._..,~...'".",..,.,_..,. ,... 9/15/99 ---...----.------- 9/16/99 9/17/99 9/18/99 9/19/99 9/20/99 9/21/99 9/22/99 9/23/99 9/24/99 9/25/99 9/26/99 9/27/99 9/28/99 9/29/99 9/30/99 Joe Anders/Jerry Dethlefs Problem Well Specialists ARGO Alaska, Inc. Volume Injected (BWPD) _?~º~~---- .-.... - --- ?,J_~-º_..____ ...... .. ?2-1_ª-1...___.____.______ 2,296 ______.__.___... ?_!-~-~º--- -..--......-.--.-.. .. .... ?~q-ª-~--_.._---_. - ?,J28 ~ ,~g§-ª_....._... ..... . ?'-º-~'ª'" 2!º~º.._._. . 335 .1.L?.º_ª_...._......_..._._....._._.__ . ~.l-º~Z_._.__.__.._.__. '.__'._ .~ 429 __._____._ __. ._____ ?_,_ª-~ 3.___._._____.____ ....... . ?..'_.ª?~----- ----.. ?..,.?Q1._........ ?,g~º ?,_Q.ªZ___ ?!Q?ª._.. - -.-- 150 . ?!J!.?._.._._.__...__.._......_ 1..!..ª6 t__.n.____ _1,,!_ª1X___._____ ~J_~.º-º-.____... ,,_ ?_,.º4~___.._ ?~qJJ__. 1,965 2,ºº~. 1,996 Tubing Pressure (psi) 330 330 330 330 235 330 330 330 332 332 350 386 320 320 923 302 386 312 312 299 345 345 290 302 300 300 310 290 290 289 9-5/8" Pressure (psi) 690 690 .,-.-. "~._".._.._.._,..-~. "..- 700 .." ~"'----"-- ....- -.---.--.-......-- 700 . . "'~_.."."_._--,..,---_._.._-,--_.__.'-,~ 640 -..,-.-".---...,,,, "... ....-..--... -_..--",-,-,_.- 700 700 650 650 640 640 700 -.'.-.--.--.,-.---..... 600 "" - - ._,---_.~.-......_-._-"._.__."'...._- 600 ._... _" .__._ ....".,,_._ '___"__..__h'__."".""" 600 .. . ....... -..----,..-.--."... .,.--- "., -.-. "'-,,~,.,._._._,. 620 ..-- ,..,._,--,-_..... -' '.-.'-"'.'-'--'-.". -"'- 700 700 700 650 650 650 650 620 . - -.'-."-.'-----..-.-.- -,...... _.~_.....,,-.~ ,-..-- 620 620 --~-------~-~-------~---,.__._- 620 620 600 600 ._.._-~_......~"--- ARCO Alaska Inc. Attn: Problem Well Specialist, PRB 24 Post Office Box 100360 Anchorage, Alaska 99510-0360 May 3,1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: 11-29 Monthly Pressure Data / Per State Sundry Approval #398-035 13-17 Monthly Pressure Data / Per State Sundry Approval #298-275 13-20 Monthly Pressure Data / Per State Sundry Approval #397-078 P1-01 Monthly Pressure Data/Per State Sundry Approval #398-188 P2-34 Monthly Pressure Data / Per State Sundry Approval #398-243 Dear Mr. Wondzell: Attached please find daily injection reports on Wells 11-29, 13-17, 13-20, P1-01 and P2-34 for the month of April 1999. This report is submitted to comply with the State Sundry Approvals listed above. If you require any additional information or clarification, please feel free to contact Jerry Dethlefs or Joe Anders at (907) 659-5102. Sincerely, Anders Problem Well Specialist ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 March 3, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re' 11-29 Monthly Pressure Data / Per State Sundry Approval #398-035 13-17 Monthly Pressure Data / Per State Sundry Approval #298-275 13-20 Monthly Pressure Data / Per State Sundry Approval #397-078 P 1-01 Monthly Pressure Data / Per State Sundry Approval #398-188 P2-34 Monthly Pressure Data / Per State Sundry Approval #398-243 Dear Mr. Wondzell: Attached please find daily injection reports on Wells 11-29, 13-17, 13-20, P 1-01 and P2-34 for the month of January, 1999. This report is submitted to comply with the State Sundry Approvals listed above. If you require any additional information or clarification, please feel free to contact Jerry Dethlefs or Steve Schudel or Jim Styler at (907) 659-5102. Sincerely, Steve Schudel Problem Well Specialist Attachments: 5 pages I8 .9 ARCO Well 13-17 April 1999 Injection Data Volume Injected Tubing Pressure 9-5/8" Pressure Date of Injection (BWPD) (psi) (psi) 4/1/99 5,724 634 925 4/2/99 5,594 627 925 4/3/99 5,647 622 910 4/4/99 5,336 619 1,050 4/5/99 5,762 640 910 4/6/99 10,378 805 990 4/7/99 11,007 848 990 4/8/99 10,790 836 1,050 4/9/99 10,794 830 1,050 4/10/99 11,164 848 1,050 4/11/99 10,640 818 1,050 4/12/99 10,921 826 1,050 4/13/99 10,925 826 1,050 4/14/99 11,295 838 1,050 4/15/99 6,750 598 1,050 4/16/99 3,225 406 750 4/17/99 3,214 421 750 4/18/99 3,062 412 750 4/19/99 2,917 400 750 4/20/99 3,011 407 750 4/21/99 2,821 392 750 4/22/99 2,923 402 750 4/23/99 2,842 391 750 4/24/99 2,996 415 750 4/25/99 3,230 439 750 4/26/99 3,152 433 750 4/27/99 3,137 429 750 4/28/99 3,024 426 750 4/29/99 3,009 426 750 4/30/99 2,867 411 750 Joe Anders/Jerry Dethlefs Problem Well Specialists ARCO Alaska, Inc. ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 February 4, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: 11-29 Monthly Pressure Data / Per State Sundry Approval #398-035 13-17 Monthly Pressure Data / Per State Sundry Approval #298-275 13-20 Monthly Pressure Data / Per State Sundry Approval #397-078 PI-01 Monthly Pressure Data / Per State Sundry Approval #398-188 P2-34 Monthly Pressure Data / Per State Sundry Approval #398-243 Dear Mr. Wondzell: Attached please find daily injection reports on Wells 11-29, 13-17, 13-20, P 1-01 and P2-34 for the month of January, 1999. This report is submitted to comply with the State Sundry Approvals listed above. If you require any additional information or clarification, please feel free to contact Jerry Dethlefs or Steve Schudel or Jim Styler at (907) 659-5102. Sincerely, Steve Schudel Problem Well Specialist Attachments: 5 pages RECEIVED '.Alat3ka Oil & GaS Cons. Anchorage ARCO Well 13-17 February 1999 Injection Data Volume Injected Tubing Pressure Date of Injection (BWPD) (psi) 9-5/8" Pressure (psi) 2/1/99 6,189 557 900 2/2/99 5,902 543 900 2/3/99 5,902 546 900 2/4/99 5,290 493 825 2/5/99 5,205 480 825 2/6/99 5,234 498 825 2/7/99 5,166 510 850 2/8/99 5,239 520 850 2/9/99 5,098 505 800 2/10/99 4,839 482 800 2/11/99 4,699 470 800 2/12/99 4,730 472 800 2/13/99 4,745 480 800 2/14/99 4,696 478 800 2/15/99 4,744 474 840 2/16/99 4,749 469 820 2/17/99 4,737 494 800 2/18/99 4,524 451 800 2/19/99 4,988 487 820 2/20/99 5,159 528 820 2/21/99 4,386 438 760 2/22/99 3,331 347 760 2/23/99 3,535 399 700 2/24/99 3,643 415 700 2/25/99 3,745 431 700 2/26/99 3,597 406 700 2/27/99 3,588 401 750 2/28/99 2,537 286 750 Jerry Dethlefs/Steve Schudel Problem Well Specialists ARCO Alaska, Inc. ARCO Well 13-17 January 1999 Injection Data Volume Injected Tubing Pressure 9-$/8" Pressure (psi) Date of Injection (BWPD) (psi) 1/1/99 3,339 369 750 1/2/99 3,351 378 750 1/3/99 3,383 394 750 1/4/99 3,575 407 750 1/5/99 3,450 398 750 1/6/99 3,577 394 750 1/7/99 3,611 400 700 1/8/99 3,617 403 700 1/9/99 3,089 337 700 1/10/99 2,977 318 740 1/11/99 2,911 307 640 1/12/99 2,914 314 580 1/13/99 3,051 334 650 1/14/99 3,031 326 650 1/15/99 2,890 311 670 1/16/99 2,604 266 670 1/17/99 2,704 296 670 1/18/99 2,628 300 670 1/19/99 2,660 298 620 1/20/99 2,783 295 620 1/21/99 2,703 296 620 1/22/99 2,855 299 620 1/23/99 2,717 269 620 1/24/99 2,365 255 620 1/25/99 6,225 713 620 1/26/99 9,715 773 620 1/27/99 9,160 740 620 1/28/99 6,914 628 900 1/29/99 6,324 599 900 1/30/99 6,164 580 900 1/31/99 6,271 565 900 Jerry Dethlefs/Steve Schudel Problem Well Specialists ARCO Alaska, Inc. ARCO Alaska Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 October 12, 1998 Mr. Blair Wondzell Alaska Oil & Gas Conser~'ation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: 13-17 Sundry Notice and Waiver Request Dear Mr. Wondzell: Attached is a Sundry application for ARCO well 13-17. The application requests waiver approval for resumption of water injection into the well with known tubing x annulus communication. The 9 5/8" casing continues to demonstrate integrity as shown by MIT tests, and we believe control and proper monitoring of PWI injection can be maintained. Details of the proposed monitoring and testing routines to assure isolation are included as attachments to this letter. If you have any questions please contact Jerry Dethlefs or Steve Schudel at 659- 5102. Sincerely, Jerald C. Dethlefs Problem Wells Specialist Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension -- Change approved program Pull tubing Variance X Perforate Stimulate Other Name of Operator ARCO Alaska, Inc Address P.O. Box 100360 Anchorage Ak 99510-0360 Location of well at surface 2703' FNL, 1634' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 2534' FSL, 2221' FWL, Sec. 11, T10N, R14E, UM At effective depth 2843' FSL, 2227' FWL, Sec. 11, T10N, R14E, UM At total depth Type of Well Development Exploratory Stratigraphic. Service X 6. Datum of Elevation (DF OR KB) 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-17 9. Permit number 82-26 10. APl number 50-029-20718 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition Summary Total depth: measured 11,551 feet Plugs (measured) true vertical 9,171 feet Effective depth: measured 11,505 feet true vertical 9,135 feet Junk (measured) Size Cemented {"j I ! N A True veritical Depth Casing Length Conductor 78' 20" 1706~ Poleset 78' 78' Surface 2,507' 13-318" 2,450 Sx AS II 2,507' 2,507' Production 10,848' 9-518" 500 Sx Class G Cmt 10,848 8,624' Liner 997' 7" 365 Sx Class G Cmt 11,548 9,167' Perforation depth: measured 11050'-11105', 11129'-11159', 11166'-11186', 11202'-11272' REC OCT true vertical 8781'-8824', 8842'-8865' 8871'-8886' 8899'-8953' Tubing (size, grade, and measured depth) 5-112" x 17#, L-80, 10,511' MD @ bottom 4-1/2" x 12.6~, L-80, 10587' MD @ bottom Packers and SSSV (type and measured depth) 9-5/8" x 5-112" BOT 3-H Packer @10,500' MD.. 5-1/2" Otis RQY SSSV Nipple @ 2158' MD 13, Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation Approval of Sundry 16. If proposal was verbally approved Name of approver Date approved 15. status of well classification as: OII Gas Service X Water injector only Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Condition of approval: Notify Commission so representative may witness Plug integrity__ echanical Integrity Test Approved by order of the Commissioner Problem Wells Specialist BOP test Location clearance Subsequent form required 10- ,.~rtginal Signed By OaVid W. Johnston Commissioner iVED 1998 ohs. ,ragc~, Form10-403 Rev06/15/88 SUBMIT IN TRIPLICATE J. Dethlefs / S. Schudel - 659-5102 - PRB 24 DS 13-17 SUNDRY NOTICE 10-403 APPLICATION 10/13/98 DISCUSSION Well 13-17 is a PWI injection well that has tubing x 9-5 / 8" annulus communication. In October of 1996 a Leak Detect Log discovered several leaks from 9242-9865' md in the 5-¥2" L-80 tubing above the packer. Based on the number of leaks the tubing is considered to not be a patch candidate. The well has remained shut-in since that time. The importance of this well in the injection pattern has been apparent this last year, with several off-set producers' GORs climbing to point of being non-competitive. This waiver request is to allow continued produced water injection into the well (no MI allowed). The request is supported by the following: · A passing combination MIT (T x IA) was performed on 7/27/98 to 3000 psi against a tubing tail plug showing 9-5/8" casing integrity. · A second passing CMIT T x lA was performed on 10/10/98 to 2500 psi. · The maximum wellhead injection pressure was 1800 psi at 15,000 bwpd rate prior to shut-in. · The wellhead has integrity per packoff testing on 9/30/96. ACTION PLAN 1. Allow well to continue water-only injection. 2. Perform an annual CMIT T x IA to 3000 psi. 3. Record wellhead pressures and rates daily. 4. Submit monthly reports of daily rates and pressures. 5. Shut-in the well should MIT's or injection rates and pressures indicate further problems. RECEIVED O T' 19 8 Oil & I]a$ Co~$, ~om~J~Jo~ Anchorage F' 0 I~ ['i..~ .............. ... ANCHOI;:AGE, AL. ASKA DATE: i 0-25-9i ,, ' "' "" ;- S I.':: D F..~=F:[-'P[.-"NCE ,-,RUd (":A HOLE F:ZNAL_S' ii-26 9-5-9i :[NJ F'ROF:'[LE '~_ RLIN. i , .,.¢'' Cr::'~"I~':L,_ 2-4A 8-26.--9 i F'ROD F'ROFZLE ~ i 7 8--"::'m-c.;'i INJ PF.'f]F/GR/';'F'M."~ - ct, RUN i ~:' CAHCO ............ ,... ¢,g , _. ,.,-...- o.~ RUN i , 5" CAMCO '='- '") "~ 9-i ,.., ':~' -- ....... ..-., ~: o. - t 2 --' o,. l::' i) ~::. ,..:, "~c' ;-": ~-" ," · ?..' Lt ¢'.. 3 :::'/, '7 .... (-5.'- 'i;-:' 'i F;.: iii i L ii: k,.,,,' ? o,~ - ,~--zu 8-28-c;'i LEAK i;,ET[fCQ"..-x-'- ...~:~ ~ · , ,3-28 8-;3~-9~ LEAK Di--TECT ' ~ RUN t, ~.' CAMCO 3;-34 '::'- i,. .."~-oi, F'ROD PROFILE ~, RUN i , ..,-"':: ' CAHCO 4-i8 9-9-9i PROD F'ROFT_LE ~ RUN i, 5' C~f'iL:O "" i... ~. ..... ~_. ~ ,,.. : .~ ,_:' 4 .... i ? 9-i 2-'-9i 5'i, 5, 9-'i4-9i PROD F'ROFILE RUN i, 5' CAMCO b , 1 GR/CC.L RUN i 5 · u,~qMCO 5-21 8-t -~_c~ · , . ...... ,, .. · .:.-., , i C-AS' LF-'AK DEl'ECl' H:I,N i, t' CAf'i[)',.'] /,-- ,.":~ °-:3-9 ..... 6 2 -:'~ ':.;' '::' ,':;---9 i --. ..... '"t ... ......... - ........... D ! STR ]: BUI' I ON · '~' (2 E x~ T I:;.: A L.. :-' 'r; ;::' '-:~ " ,, J ................ ii: -,,-""C H ii.' 'v'R 0 N E X l" [:' N $10 N E. ;.i P t.. rj R ~:~ i' i 0 N E X X' 0 N i"i A F;.: A T i--I !]) :~-. H (i :E.: :r L. F:' i"! i i... i... ! F:' S' F'B WFL. L FiL~ES' R & D BF'X ,'5:."'f'A 'f [:T. (J F A L A S I< ,'.":; "' ..::.. ~'.-'1 ' ARCO ALASKA, INC. P.O~ BOX i00360 ANCHORAGE, ALASKA . 99~f0 DATE' 7-24-89 REFERENCE' ARCO CASED HOLE FINALS 2-5 '7-i6-89 F'FC S-S '7-5-89 "f'Ei4P SURYE"f 5-9 7-5-89 i'EMF' SURVEY 3-~i '7-6-89 TEMF' 4-2 7-8'-89 I'EMF' 4-4 '7-8-89 TEMP i t-3 7-7-89 I'EMP i i-4 7-7-89 TEMF' ti-4 '7-9-89 PITS ii-25 7-i2-89 CNL tS-iT 2-3-89 INJECTION PROFILE F'WDW2-t '7-9-89 TEMF' PWDW2-i 7-9-89 I'EMP RUN i, 5" I;,'Ul'4 i., 5" RUN i R U N i, '5" RUN RUN i, 5 RUN i, RUN t, 2'&5' RUN i , 5 RUN i, 5 RUN i "1 RUN i, RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DA'FA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 AI'LA~ UAmCO CAMCO CANCO CAMUO CAMCO CAMCO $CH CAMCO CAMCO CAMCO 'Il' DISTRiBUIlON CENTRAL FILES CFIEVRON D & M ... EXTENSION EXPLORATION ,,.EX X 0 i~- ::,,.,,..-; ,, MARATHON, .' MO~..' --~d.-- '?'-. · · ! ,. _:... ;- ',- . ;'. ~: ~,: F'HZLL£PS F'B WELL FILES R'& D BF'X STATE OF ALASKA TEXACO ARCO ALA,.~K F'~. O~ BOX ANCHORAC, E , ALA,.~K A DATE ' 4-~.. 6-813 F~'EFE_'REiNCE' ARCO CAGED HOLE F'INAL ~ :? .... '.? 5; 4.-- ~ 5; -- !i~ 8 t'. !::' I kl N t::' F: I:;.' I I t'J "~ 5;" ,.? ... . . ..'.. ~ ~.,:'v _. .,:'-~ ..... F'~ 4 --- ~ F~ - t-~ 8 F' '[ T .~: R' I. I t',J ~ ,. %" ~-'17 4-"t '1 .... 1!!!3 'IN..!I~!'F.:TTCIN F:'I:;'OF:II...E I:;,'I~N~ , 5;" 21 4-17- 88 PITS ~T,~;, RUN !, 5" F'I..['!'A,?F." .t"T.(:;t',t ANO RF.'iT!.~I:;:N 'l, aIi-I.F.'. A'~i.~~ .F..(':..F-'[r-:'T I"~F' ~)A'T,.$.. ~]:Il] I:~'F:tCEIVE'!'* RY .................... i~-~~"' '~"-~ I--IAVI.-.-- Ai',)'I'C.F.-, bA.Y~"~'~'e' "~,i'~i'''~ .... I ", "FFv r,I-'''~r~'~ ~' ' O~l & OaS A'T'O-t ~'F TRAN,~ ~ A F:' P R O V F T) ,S' C FI .'CCH ,\ · ~:1 'T' 'F .~' -~ f.', E:NT R At... F ]: I...E:,.? ~ PIq '[/..I... ! F',~' · ~ CFt.F.-.VRON F'R L,JFI I. F' T I. F',~' D & H R & T) '.~. I~'X'I" .F-'N ~' I lIN F'¥F'I.. Ft~'~ T T I']N ...~- ,~' ~ t:'C ,~' F'.-.~XXC)N '~ ..?TAT['.'. OF AI...AgKA MARATHON :~ M 0 B I I... ARCO Alaska, Inc. Prudhoe Bay L,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 5, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS.~. 13-17i~ Approval No. 7-875 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TPA/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 13-17i)W1-3 STATE OF ALASKA , ALASK,-, ,.)IL AND GAS CONSERVATION COMM~./ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Alter Casing ~ Other ~ Name of Operator ARCO Alaska, Inc. AddresS P.O. Box 100360, Anchorage, AK 99510 Location of well at surface 2703' FNL, 1634' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 2534' FSL, 2221 FWL, Sec. 11, T10N, R14E, UM At effective depth At total depth 2843' FSL, 2227' FWL, Sec. Plugging ~ Perforate ~ Pull tubing 5. Datum elevation (DF or KB) 87' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 13-17i 8. Approval number 7-875 9. APl number 50-- 029-20718 11, T10N, R14E, UM Feet 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective dePth: measured true vertical Casing Length Structural 78' Surface 2507' ProduCtion 10848' Liner 997' 11551 feet 9171 feet 11505 feet 9135 feet Size 20" 13-3/8" 9-5/8" 7" Plugs (measured) Junk (measured) Cemented Measured depth 1706# Poleset 78' 2450 Sx AS III 2507' 500 Sx Class G Cmt 10848' 365 Sx Class G Cmt 11548' Rue Verticaldepth 78' 2507' 8624' 9167' Perforation depth: measured ll050-lll05'; 11129-11159' true vertical ; t1166-11186' ; 11202-11272' 8781-8824'; 8842-8865'; 8871-8886' ~bing(size, grade and measured depth) 5~", 17#, L-80 @ 10511' ; 889908953' Packers and SSSV(type and measured depth) BOT 3-H packer @ 10500'; Otis RQY SSSV nipple @ 2158' 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production o('~jecti°n Dat~ Oil-Bbl Gas-Mcf Water-Bbl ~sure 80OO 16000 Tubing Pressure 1200 1200 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge /~~~~ Title ~ , ,, ~ , Signed ~/~¢.~ ~ ~ Form 10-404 Rev. 12-1-85 WELLS/30 T. P Allen, 263-4837 Date Submit in Duplicate DRILL SITE 13-17i (WATER INJECTOR) SELECTIVE MUD ACID STIMULATION Treatment: Selective mud acid stimulation using the coiled tubing inflatable packer. Date: 3/14/88 Treated Zone: 4 · me Rigged up pump trucks, N2 unit and acid transports. RIH with coiled tubing with inflatable packer and tubing tail locator. 3. Located tail and X-nipple, adjusted depth adding 10'. 4. Set packer at 11117' MD. 5. Rolled all acid compartments. 6. Pumped the following stimulation fluids: a· g. h. i. j. 60 bbls of 2% NH,C1 water with visperse bio-dispersant 59.5 bbls of 15%4HC1 dispersed with 10% xylene w/additives 120 bbls of 12% HCl-3% HF dispersed with 10% xylene w/additives 120 bbls of 2% NH,C1 water 13 bbls of foam d~verter 60 bbls of 2% NH,C1 water with visperse bio-dispersant 83 bbls of 15% H~I dispersed with 10% xylene w/additives 179 bbls of 12% HC1-3% HF with 10% xylene w/additives 139 bbls of 2% NHtC1 water 25 bbls of methangl 7. Released packer and POH with coiled tubing and packer. 8. Immediately place well on injection. 9. RD CTU and release equipment. WELLS2/30 ARCO AI_A~KA, Po Oo BOX ANCHORAGE, Al. ASEA DATE' 2-~4-RR REFERENCE: A RCO CASED HOL~ PR , PRFI...E/FM/TP/FD/W FI OWMF.. TER PRO., PRFLE/FM/TP/FO/W RI.IN PRO., PRFI. E/HPFM/TFMF'/DFN RilN PRO, PRFL. E/HPFM/TEMP/DEN/WHI IT RUN PIT.~/TFMP RIIN PITS/(.,R/TEMP RI.IN RI.IN RI IN CAMnn CAMCO C~MCn CAMCO CAMCO PITS PIT~/TEMP PITS FI_OWMETER PIT~/TEMP PRD.P~FL_E/HPFM/WHLII~Oij&GasCoDs. Com~gg~RIJN i F'RD PRFL.E/HF'FM/WH[~R ~chorage REIN t GAMMA RAY RUN t RUN RUN RUN RI.IN RLIN RUN RLIN RUN RUN CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO PLEASE SIGN AND RFTURN THE ATTACHED COPY A~ RECEI RECEIVED BY HAVE A NICE DA PEGGY BENNE1 AT0-i529 TRAN~ ¢88i~5 ~ APPROVED DISTRIBll' ION ~~ CENTRAl_ FILES *. CHEVRON D & M * EXTENSION EXPLORATION ~ EXXON MARATHON .' MOBIL c, O ---- OWL 'T' ARCO Alaska, In/ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 13-17 Permit No. 82-26 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/PVL/jp "Vt " ' ' Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 13-17)W1-3 to be RECEIVED NOV 0 ? i987 AI=ska 0il & Gas Cons. Commissior~ Anchorage WELLS2/30 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ~ ALA_ ~A OIL AND GAS CONSERVATION CO, ,tlSSlON 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 [] Perforate [] Other [] 2. Name of Operator ARCO Alaska. Inc. 3. Address ;P. O. :Box 100360, Anchorage~ AK 99510 4. Location of well at surface 2703' FNL, 1634' YEL, Sec. 14, T10N, R14E, UM At top of productive interval 2534' FSL, 2221 FWL, Sec. 11, T10N, R14E, UM At effective depth At total depth 2843' FSL, 2227' FWL, Sec.. 11~ T10N~ R14E~ UM 11. Present well condition summary Total depth: measured 11551 feet true vertical 9171 feet Plugs (measured) 5. Datum elevation (DF or KB) 87 ' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 13-17 8. Permit number 8?-?.6 9. APl number 50-- 029-2C)71R 10. Pool Prudhoe Bay Oil Pool feet Effective depth: measured 11505 true vertical 9135 . Casing Length Size Structural 78' 20" Surface 2507 ' 13-3/8" Production 10848 ' 9-5/8" Liner 997 ' 7" feet feet Junk (measured) Cemented Measured depth 1706# Poleset 2450 Sx AS III 500 Sx Class G Cmt 365 Sx Class G Cmt True Vertical depth 78' 78' 2507' 2507' 10848' 8624' 11548' 9167' Perforation depth: measured 11050-11105'; 11129-11159'; 11166-11186'; 11202-11272' true vertical 8781-88,24'; 8842-8865': 8871-8886' ' Tubing ts~ze, grade andmea§ured depth) ; 889908953 5½", 17#, L-80 @ 10511' Packers and SSSV (type and measured depth) BOT 3-H packer @ 10500'' Otis ROY SSSV n~le 0 2158' 12.Attachments Description summary of proposal '"7 NOV o 9 &L~sk~ Oil & Gas Cons. C0tztCSS~(~f~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation November 1987 14. If proposal was verbally'approved Name of approver Date approved 15. I hereby/-pertify th.a,t the foregoing is true and correct to the best of my knowledge Commission Use Only Conditions of approval Approved by ~/~, Form 10-403 Rev 12-1-85 U[T.T.S/30 Date ~-"-/~'~ Notify commission so representative may witness I Approval No. [] Plug integrity ~ BOP Test [] Location clearanceI ,.~; ,., O.~¢?, by order of commissioner the commission Date P. V. Lantero, 263-4312 Submit in triplicate¢ Drill Site 13-17 Selective Stimulation Procedure . MIRU wireline unit. Perform a correlative log run (CCL/GR) through the packer and perforated interval. Make a gauge ring run (3.60" gauge ring should be run on the end of a 20' foot dummy gun) and record PBTD. If PBTD is not below 11272' MD, perform a FCO. 2. MIRU pump trucks, CTU, N2 unit, and transports. . . Before running in hole with CTU, pump the 'set ball' through the CTU to make sure the unit is free of restrictions. RIH with tubing tail locater, Baker 7" inflatable packer, and hydraulic disconnect. Using the log run in Step No. 1 as the correlative log, set the packer at 11117' MD. 5. Load 6000 gals of 15% HCI and 12000 gals of 12% HCI-3% HF acid. 6. Roll all acid compartments before pumping fluids downhole. 7. Stimulate the well as follows: , A. B. C. D. E. 2500 gals of 15% HCI dispersed with 10% xylene w/additives 5000 gals of 12% HCI-3% HF dispersed with 10% xylene w/additives 5000 gals of 2% NH4CI water w/additives 750 gals of 2% NH4CI water gelled with 40 lbs/1000 gal CMHEC at 2750 SCF/BBL of nitrogen (plus foaming agent) 3500 gals of 15% HCI dispersed with 10% xylene w/additives 7000 gals of 12% HCI-3 % HF dispersed with 10% xylene w/additives 7500 gals of 2% NH4CI water w/additives Displace with 25 bbls (CTU volume) of methanol Release inflatable packer; pull packer above PBR assembly before bringing well back on injection. POH with CTU packer. 9. Put well back on injection immediately following the treatment. 10. RD and release CTU, pump truck and transports. RECEIVED NOV 0 9 I987 Oil & Gas Cons. Commlss!o~ Anchorage 6 5 4 2 1. S000 PSI ?" Wl;LLHF. AD ¢~ONN£CTOR 2.SO00PSI 41/1~" PIPE: RAIDS 4. ~ P~ 4 1/S" ~ ~S 8. ~ P~ 4 1/18" S~FFIK BOX RECEIVEI) Oil & Gas Oons. Commi~ Anchorage CO I LEO. TUB 1 NO UN,I t,,, BOP, E{~, ! PHENT -- ARCO ALaska, Inc. F:'~O, Bo× t00~.6(~ A n c: h o r a g e, ,~:~ L a :i~' I-:: a DATE: REFERENCE: ARCO Cased Hole 9-t:3 ?-t 5-87 F'roduction Profi[e tt-24 7-8-87 F'ump in Temp, Survey t 3-t 7 7-t 8-87 Inj, Prof i Le t~-t8 7-t 8-87 Inj. Profi[e t6-t5 7-5-87 Pump in Temp, Log RL~n Run I , Run t, Run t , 5" Run i, Camco Camco Camco Camco Camco Please sign and ret,~i-n the attached COPy a.$ receipt of data. Rece i red By ~ ATO-i 529 I'RAN$ ~873~;4 ~ Appl-oved ...................... DISTRIBUTION · ~ Phi llips ~ Central Fi les ~ · .~ Chevron F'B Well Fi les D & M R & D " $oh i o ~'"' E x t e n :s i o n E x p [ o r a t i o n ..- .,+ · '".Exxon ~ ~.ate of Alaska Hare{hon ~- T~.x~co ~: Mob i l DATE: ,Juky t4, t987 REF:'ERENCE: ARC(] Pressure Data tS--t7 5--.t-8'? $'urfac:e Pres'sure F:'attoff tS-20 .5-2-87 ,~'urfmce Pres.s'ure F'~[toff i:3-22 5-S-87 Surface Pressure Fa t toff Al' C: 0 Arco Arco PI. ease sign and return 't'he a't"t'ached copy as receip't' of d;~1'a~ F.'.ece i red By ........................................................................ HAVE A NICE DAY! Rosanne Peek ATO-t 529 TRANS ~:87S6~i ~ Ap p roved .................. _~ Alaska Oil & Gas Cons. Commission Anchorage D .l: Z, T R I B U T I 0 N Central. F'i Les Chevron · "- T) & lq · ..'~' E x x o n :~ Mob i L ARCO A[a,s~ka, Inc. Anchorage, A L a.s'l<., a DATE:' November t 7, t986 REF'E:F~FNCI'Z' ARCO Ca-.s'ed I--lo Le F ina L ,-9 · ~ ' F' I. o p e t r o t 2--'? 8-.,.7-.86 Sl:.>inne¥' Su¥'vey Ru.n i , 2- t 5 8- ''~ 7 ..-86 ~;' '~" F L o p e '~ r o t .: ,p inner Survey Run 1, ,. . 2-" 1 8 8-- t,,'z _. 86 T e m p . S u r v e y R u n i , ~~--4 ,.,°-")~-°z..:.~ ,~,, Spinner Survey/Temp. Survey Run t, 2'. FLol)e'[¥'oL ~ ,.~ ._,~, nne¥' Survey Run i, '~" F [opefro I. S--i~) p_,.~o..oz., ,..~. ,~,~ Spinner Survey (Mutfi-ra~e) Run t, ~,~"'-t.,. '> 8-27-.86 Spinner Survey/Temp. Survey Run 1, 6--9 8-t -86 Temp. Survey (F'ump in) - Run t, 2" Flope'~rol '"'" F' [op et'r o 9-.-.Si 8-4-86 Spinner Run i, .,. 9-~2 8-6-86 F'BU/Ypinner Survey Run i, 2" FLope'[roL ,. "~" F L o p e t' r o t t~-t7 8-~i-86 Spinner S~rvey Run i, i3--2~ 8-2i~86 Spinner Survey Run i, 2" FLopei'rol. i"z.,--'~..8-2~.-.86 Spinner Survey Run i, 2". FLopetrol. F'[eam'e ~ign and ret'urn fhe aft'ached copy a.s' receipt of dafa, Received By HAVE A NICE DAY! Ro~'anne Peel< ATO-i 529 TRANS ~:867S6 DISTRIBUTION · .-'"' Cen'fra L Fi ,,- Chevron D & M ~.' Fxt'en.~ion Exp~oratio'n ~ Ex xon Ma r a ~ h on ~~ Hob i / Phi PB WeLL Fi Le_~ R & D · .-.~ Sob i o ~ ,, ',,',?.?-~ $ t~' .t.'e-.o f' A.[ a.'.; k a -.-'"' Texaco ARCO Alaska, inc. Pos! Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Date- October 3, 1985 Reference' ARCO CH Finals 3-3v Spinner 9-14-85 Run 1 5" Camco 3-7~/ Spinner 9-25-85 1 5" Camco 3-12v/Spinner 9-14-85 i 5" Camco 3-16 O/Spinner 2-24-85 1 5" Camco 6-2 ~/ Temp 9-22-85 1 5" Camco 3-30 ~/Spinner 9-24-85 1 5" Camco 6-2w/ Spinner 9-12-85 1 5" Camco 9-32 w~CBL 8-7-85 1 5" GO ~ '-- 9-33~/ CBL 8-6 -85 1 5" GO ~ -- 13-17L/Spinner 8-7-85 1 5" Otis Please sign Received by Pam Lambert as receipt of dat ~aska 0~ ~ u~s Cons. Commission Anchorage ATO 1429C Chevrod Trans 340 D & M Expl. Services' Ext~ Exploration, Exxon . Marathon Mobil~ Phillips PB Well Files R&D Sohi& State~of~A,l. aska.~ Texaco ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Ataska 99510 Telephone 907 '276 1215 DATE: MAY 14, 1985 REFERENCE: ARCO PRESSURE DATA /6-2 STATIC GRADIENT 4-28-85 CAMCO /6-7 'STATIC GRADIENT 4-28-85 CAMCO / 7-7A STATIC GRADIENT '4-27-85 CAMCO · //7-13 STATIC GRADIENT 4-27-85 CAMCO ~-7-14 STATIC GRADIENT 4-27-85 CAMCO 7-16 STATIC GRADIENT 4-29-85 CAMCO 7-25 STATIC GRADIENT 4-27-85 CAMCO /13-3 STATIC GRADIENT 4-25-85 CAMCO /13-4 STATIC GRADIENT 4-25-85 CAMCO /'13-13 STATIC GRADIENT 4-25-85 CAMCO j13-14 STATIC GRADIENT 4-25-85 CAMCO /13-17:~PF0 w/LISTING 10-29-84 SCH j13-23A FLOWING PRESSURE GRADIENT SURVEY 13-27 STATIC f13-29 STATIC 14-9B STAT I C 14-19 STATIC GRADIENT 4-25-85 CAMCO GRADIENT 4-25-85 CAMCO GRADIENT 4-26-85 CAMCO GRADIENT 4-26-85 CAMCO 4-26-85 .CAMCO F DATA. / 1~-26 STATIC GRADIENT J/~LEASE SIGN AS RECEIPT 0 W/LI STING 10-27-84 SCH RECEIVED BY PAM LAMBERT AT0 1429C TRANS #10~hevron D& M Expl. Services Ext. Exploration Exxon Marathon Mobi 1 '~sk~ C.. & (Sas Cons. .... ~ Anchorage -_ ~o~ ~ & ~ Phillips PB Well Files R&D Sohio State of Alaska Texaco ARCO Atasl<a, Inc F:'.O~ Box ~00360 Ancho¥'age, ALa_~ka 99< 1 0 DATE' Ap'r i L REFERENCE ' 8 , L o 8 < ARCO Cas'ed HoLe F inaL.s' Co L tat-/F'e'r f Log Col LaF/F'e¥'f I_og CCL/F'e~-f l:;:eco¥'d EPL 1:: F:'L CH CNI_ CET Tempe'r,.a+.Lt're 1_o9 C C L./' f:'e 'r' 1'- R e c c:, ~- d 5 ' (; 0 5" :~: c: h _, ,!..7 c h 5" Sc h ./~" };'(:h _,c:'"Sc:fi _; b C Ih 5'" 5; c: h .. tea i n z' .' ~ ::SE'-.' .-~: cj ,::: ,::.', F) ¥ a .5' 'r ,::-.'. ,::: c, i p '!' .... ' ....................... : ...... ~' '~' ~4~" ~ ..... HAVE A NICE DAY! A?F,/1 ....-~/-.._, // m Ke t I.y Mc:FaF I. and"='~asaa Oii& 6as Cons. (:'ornm~;:s;or~ A T O- 1 4 '2 9 F' /'~::::: .:; ;: ::5 - D I ,:? T R I B IJ 'T' 71:0 N. C h e v i" o 'n I) ,_*, M Exp [o~-a%ion SeFvices' Extension Exp l. oFa't:ion Ex xon Mai-a'tho'n Mob i t Hob i I. E ,*.-: F:' Phi 1. L i ps; F:"ru(Jhoe Bay Wel. I. R & D $ohio State of ALaska Texaco F- i l e 5_: ARCO Alaska, Inc~"~' Prudhoe Bas .~ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 29, 1984 Mr. C. V. Chatterton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 13-6 Permit No. 81-121 DS 13-9 Permit No. 81-158 DS 13-15 Permit No. 82-157 DS 13-16 Permit No. 82-148 ~!1.3-17' Permit No 82-26 DS 13-18 Permit No. 82-35 DS 13-19 Permit No. 81-180 DS 13-20 Permit No. 82-9 DS 13-21 Permit No. 82-53 DS 13-22 Permit No. 82-77 DS 13-23A Permit No. 82-23 DS 13-24 Permit No. 82-65 DS 13-25 Permit No. 82-91 DS 13-32 Permit No.' 82-123 In 1983, several Prudhoe Bay Unit producing wells were converted to injection as part of the Flow Station 3 Injection Project. By review of our records, we have found that intent sundry notices for these conversions were submitted, but no subsequent sundry notices were filed to confirm the conversions. Attached are subsequent sundry notices wh.ich provide formal notification of the completed injection well conversions. The dates of the first injection included for each well correspond with data previously submitted in the semiannual progress reports for the Flow Station 3 Injection Project. Very truly yours, D. F. Scheve DFS/RSS/STATE/lmi cc: Sohio petroleum Company File 100.0 RECE] ARCO Alaska, }nc. t$ a Sub$1dlary o! AtlantlcRichfieldCompany ,.,, STATE OF ALASKA ALASKi IL AND. GAS CONSERVATION C~")IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL'IX] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-26 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 2703' FNL, 1634' FEL, Sec. 14, T10N, R14E, OM (su'rf) 2534' FSL, 2221' FWL, Sec. 11, T10N, R14E, UM (top prod) 2843' FSL, 2227' FWL, Sec. 11, T10N, R14E, UM (TD) 5'Elevati°ninfeet(indicateKB'DF'etc').87' RKB I 6. LeaseDesignationandSerialNO.ADL 28311 8. APl Number 50- 029-20718 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-17 11. FieldandPool 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: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plan~ [] RePairs Made [] Other ~X Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form i0-407 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. has converted DS 13-17 to a Water Injection well. The date of first injection was 11/23/82. RECEIVED 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 2F'F'~ ~2~ Title Regional Engineer The space below for Commission use Conditions of APproval, if any: By Order of Approved bYl COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc./"% Post Office B,.,,~ 360 Anchorage. Alaska 99510 Telephone 907.277 5637 April 14, 1983 Reference: Arco Cased Hole Finals / D.S. 2-11/ 12-27-82. · D.S. 13-7 / 3-20-83 ~13-17~ 2-17-83 2-19'83 C.A.T. Spinner Log EPL EPL Run 1 5" DA 5" Camco Run 1 5" Sch Run 2 5" Sch D.S. 14-9B~ 3-31-83 / D.S. 14-18/ 3-30-83 Spinner Spinner 5"'Camco 5" Camco D.S. 14-29 Spinner 5" ' Camco D.$. 18-1/ 2-16-83 D.S. 18-3// 3-28-83 2-16-83 D.S. 18-6~/ 2-16-83 CPL/Volan w/Listing . ~. CPL/Producibility w/Listing CPL/Volan w/Listing CPL/Volan w/Listing 5" Sch Sch 5" Sch 5" Sch D.S. 18-7 ~/2-17-83 CPL/Volan w/Listing D.S. 18-10~ ~'~125-83' CPL/Prod~cibility w/Listing 6-83 CPL/Volan w/Listing ~./~21. ease sign 'and return the attached, copy as receipt of 5" Sch Sch 5" Sch data. Kelly McFarland AFA-403 T~ans. # 273 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON. EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS . ARCO Alaska, inc. ~,~, Post Office ~. 360 Anchorage. Alaska 99510 Telephone-gO7 277 5637 March 17, 1983 Reference: Arco Pressure Data D.S. 9-4 2-23-83 2-23-83 D.S. 9-1'2/ 2-24-83 2-24-83 D.S.~i'3-I77 2-17-83 D.S. i4-22 1-24-83 D.S. 14-28~" 1-23-83 'D. S. i-5-11 9-17-82 9-17-83 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 Fall-Off. Survey Sch Static Survey GO Static Survey Camco Pressure Build-up Otis 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..# 219 DISTRIBUTION R & D MOBIL "~ J ~.5~3-~~. DR ILL I NG GE~Y Alaska Oil PHILLIPS D & M SOHIO STATE OF ALASKA MARATHON DALLAS CHEVRON CAROLINE SMITH Anchorage, Alaska 99510 Telephone;~"~ 277 5637 December 3, 1982 RE- ARCO Directional Surveys D.S., 1-21 /~.S. 6-24 10-22-82 /D,S. 7-15 10-28-82 ~/D.S. 12-4A 11-15-82 --D.S. 12-7A 11-15-82 ~D~S. 12-8B 11-15-82 /D.S. 12-14.' '11-15-82 -'O.S. 13-14 11-15-82 fD.S. 13-15 11-22-82 -B.S. 13-16 11-15-82 ~D.S..~13-17 11-15-82 10-22-82 Single .Shot Single Shot Single Shot Single Shot S.ingl e Shot Single Shot Single Shot Single Shot Single Shot Single Shot Single Shot ~D.S. 13-18 11-15-82 . Single Shot ~-~D.S. 13-23 11-15-82 Single Shot ~q~.S. 13-23A 11-22-82 Single Shot /D.S. 13-24 11-15-82 Single Shot · /D"~S. 13-25 11-15-82 Single Shot ~d).S. 13-26 11-15-82 Single Shot ~D.S. 13730 11-15-82 S.ingle ~ot /D.S. ~3-32 11-15-82 Single Shot / ~./13,34/ 11'15-82 Single Shot .' ' a e sign and return the attached copy as receipt of data. E/W E/W E/W E/W E/W E/W E/H E/W E/W E/W E/W E/W E/W E/W E/W E/W E/k~ EIW E/W BeCky Benedi ct AFA- 403 Trans. #638 ' DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON GETTY D&M STATE OF ALASKA DALLAS ARCO AlasAa. inc is a Subsidia~f of AtlamicRichfieldCompany November 8, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Re: D. S. 13-18 - Permit No. 82-35 D. S. 13-20- Permit No. 82-9 D. S. 13-17 - Permit No. 82-26 D. S. 13-24- Permit No. 82-65 D. S. 13-25- Permit No. 82-91 'D. S. 13-9 - Permit No. 81-158 D. S. 13-21 - Permit No. 82-53 Attached are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Sc heve Regional Engineer DFS-MAM:mlc Attachments cc' Sohio Petroleum Co. ARCO Ala~,ka. Inc is R stJbsidiary o! AtlanticRichfieldCompany STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLZ] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-26 3. Address 8. APl Number P.O. Box 360; Anchoraqe, AK 99510 5o-029-20718 4. Location of Well 2703' FNL, 1634' FEL, Sec. 2534' FSL, 2221' FWL, Sec. 2843' FSL, 2227' FWL, Sec. 14, TION, R14E, UM (surf) ll, TION, R14E, UM (top prod) 5. Elevation in feet (indicate KB, DF, etc.) RKB 87' 12. 11, TION, R14E, UM (TD) I 6 . Lease Designation and Serial No. ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 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 IX] 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 convert this well to produced water injection service. The well is presently completed and perforated in the Sadlerochit; no rig work or additional perforating is required to make the conversion. The choke and check valve direction will be reversed and the necessary instru- mentation changes will be made at the surface. A downhole safety valve will remain in service in this well following conversion to injection. A non-freezing fluid was left in all uncemented annuli within the permafrost interval. gnbsequent Work Reportecl RECEIVED NOV 0 9 ]982 Alaska 0il & Gas Cons. Commission Anchorage 14..I hereby c~rtify that the foregoing is true and correct to the best of my knowledge. Signed ....... Title Regional Operations Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by Form 10~,03 COMMISSIONER Approved ~opy Returned By Order of the Commission Rev. 7-1-80 Submit "Intentions,' in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 360 Anchorag~"--'taska 99510 Telephone =o7 277 5637 October 22, 1982 Reference: ARCO Cased Hole Finals D.S. 7-6 9-17-82 D.S. 12-4A 9-6-82 D.S. 13-17 · 8-3-82 D ~ 10-2-82 D.S. 13-20 9-26'82 D.S. 13-23A 9-30-82 Completion Record 5" Collar and Perf. Log 5" Collar and Perf. Log 5" Completion Record 5" Spinner 5" Completion Record 5" Run 1 Run 1 Run 1 Run 2 Run 1 Run I SCH Gearhart Gearhart SCH Gearhart SCH //~s.e sign and return the attached copy as receipt of data. Becky-Bendict AFA - 403 Trans. #573 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE Ala,ska Oil & Gas Cons. An:borage. ARCO Alaska, inc. Post Office Box 360 Anchoragef'"~ska 99510 Telephone _ , 277 5637 October 15, 1982 Reference: ARCO Case Hole Finals D.S. 6-21/9-9-82 CCL/Perforating Record D.S. 6-21f 9-12-82 CBL/VD D.S. 6-21./ 9-9-82 CBL/VD Run 1 SCH Run 1 SCH Run 1 SCH D.S. 13-1~/ 6-20-82 Differential Temp. Survey 'D.S. 12-2 /6-21-82 Differential Temp. Survey D.S. 4-14~/ 10-7-82 Spinner Survey D.S. 13-17~9-26-82 Spinner' Survey D.S. 3-6~/ 9-13-82 Engineered Production Log Run 1,2,&3 CAMCO Run' 1,2,&3 CAMCO Run 1 OTIS Run 1 OTIS · Run 1 SCH /~ease sign and return the attached copy as receipt of data. Becky Benedict AFA - 4.03 Trans. 9550 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING PHILLIPS SOHIO MARATHON CHEVRON September 23, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Re' D.S. 13-17 - Permit No. 82-26 D.S. 13-18 - Permit No. 82-35 Enclosed are Completion Reports for work done on the above- mentioned well s. Very truly yours, D. F. Sc heve Regional Engineer DFS.TKKW- skh Enclosures cc' Sohio Petroleum Co. ARCO Alaska $nc is ~ subsidiary ot AllanlicRJ(hfieidCon;~tny · , ~, STATEOF ALASKA - ALASKa., .~L AND GAS CONSERVATION C,~?MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well : : Classification of Service Well OIL DO GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-26 3. Address 8. APl Number P. O. Box 360; Anchorage, AK 99510 50-029-20718 4. Location of well at surface 9. Unit or Lease Name 2703'FNL, 1634'FEL, Sec. 14, TION, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2534'FSL, 2221'FWL, Sec. 11, TiON, R14E, UM U.S. 13-17 At Total Depth 11. Field and Pool 2843'FSL, 2227'FWL, Sec. 11, TION, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 87' RKB A)I 2g311 12. Date Spudded 13. Date m.D. Reached 14. Date Comp., Susp. or Aband. [ 15. Water Depth, if offshore I16. No. of Completions 3113182 413/82 z~/14/R2I -- feetMSLI 1 17, Totai Depth (MD+TVD) 18,Plug'Back Depth (MD+I-VD} 19. Di~c~ic;na~urvey I 20. Depth where SSSV set 21. Thickness of Permafrost 11551'MD 9171'TV) 11505'MD 9135'TV)YES~] NO[]I 2157 feetMD 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/SP/GR, DIL/BHCS/GR, FDC/CNL/GR/Cal, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40- Surf 7R' ' 30" . 1706~ Pole~et 13-3/8" 72.0# L-80 · Surf 2507' 17-1/2" 2450 sx AS III 9-5/8" 47.0# L-80 & Surf 10848' 12-1/4" 500 sx Class G S00-95 7" 29.0# L-80 10551' 11548' 8-1/2'' 365 sx Class G _)4. 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) .q-1/2" 105R7 ' l Re/: CNL 4/13/82. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11050'11105'MD ~ 8781-8953 'TVD DEPTH INTERVAL (MD) AMOUNT &KIND OF MATERIAL USED 11129-11159'MD 11166-11186'MD ' D 11202-11272'MD "~- P ODUCT,ON TEST i982 Date First Production I Method of OperatiOn (FlOWing, gas lift, etc.) 8/5/82I F1 Dwi ng Alaska 011 Date of Test Hours Tested PRODUCTION FOR~ PI L-BBL GAsiMcF WATER-BBL CHOKE SIZE G-~S'-~IL ~ATIO 8/30./82,, 12 .~_1. TEST PERIOD ~ ~.8 8 6_' ' 1843,__'93_ 28_ 12~6~7 FIDTM Tubing Casing Pressure CALCULATED OIL]BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) PresS. 1964 N/A 24-HOURRATEI~' 3285 4~6l :189 27 0 28. CDR E DATA Brief description of lithology, porosity, fraCtUres, apparent dipS and presence of oil, gas or water. Submit core chips. , N/A 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 Sadl erochit 11052' 8780' Oil/water Contact 11460' 9100' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · · . Signed 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. Post Office Box 360 Anchorage. A~ska 99510 Telephone g~77 5637 September 14, 1982 Reference: ARCO Pressure Data \ D.S. 13-7 j 8-15-82 D.S. 13-12/8-20-82 D.S. 13-20/ 8-9-82 D.S. 13-1~ 8-16-82 D.S. 13-8 ~'/8-15-82 8-82 D.S.. 13-18 / 8-3-8.2 Pressure Survey Pressure Survey Pressure Survey ~ressure Survey ~ressure Survey Pressure Survey Pressure Survey Gearhart CAMCO D/A Gearhart Gearhart CAMCO CAMCO ease sign and return the attached copy as receip= of data. Becky Benedict AFA- 403 Trans. # 465 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOB~z~ DRILLING GET SOHIO G LOGY CH~0N DALES September 3, 1982 Mr. Co V. Chat Chatterton State of Alaska Division of 051 and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re' D.S. 12-14 - Permit NO. 81-138 D.S,' 13-'17~- Permit No. 82.-26' D.S. 13-18 - Permit No. 82-35 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Operations Engineer DFS :TKKW- skh Enclosures cc' Sohio Petroleum Co. ARCO Ala'~k,~. Int. i~ a .,,ub..idiar¥ of AllanlicRi(:hlieldC. ompa~y STATE OF ALASKA ~"~ ALASKA ~,~L AND GAS CONSERVATION CL,,,aMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I-X] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-26 3. Address 8. APl Number P. O. Box; Anchorage, AK 99510 5o_029-20718 4. Location of Well 2703' FNL, 1634'FEL, Sec. 14, T10N, R14E, UM (Surf) 2534'FSL, 2221'FWL, Sec. 11, TION, R14E, UM (Top Prod) 2843'FSL, 2227'FWL, Sec 11, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) . RKB 87' 6. Lease Designation and Serial No. ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-17 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made SUBSEQUENT REPORT OF' (Submit in Dup~i)r~ ~ ~n~E ~) [] [] Abandonment [] [] 0 9 1982 [] Pull Tubing [] Other [] Pulling Tubing [] · (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) ~,~ 0il & Gas Co/is. 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including est'~t~t~l/'~l~ (~[)mrn~,..,.,,,o of start~)~ny proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 8/1/82. Rig up perforating unit, pressure tested surface equipment. RIH with gun #1, shot 11252'-11272'MD (20' ref. CNL 4/13/82) 4 spf. 1200 phasing, POH- all shots fired. Flowed well to tank for clean-up, monitored rate and took shake outs. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 2r~. ~~ Title Reg. 0prs. Engineer The space below for Commission use RIH with gun #2, shot 1,1'232'-11252'MD (20' ref. CNL 4/13/82) 4 spf 120© phasing, flowed to separator for clean-up POH - all shots fired. RIH with gun #3, shot 11212'-11232'MD (20' ref. CNL 4/13/82) 4 spf 120© phasing, flowed to separator for clean-up POH - all shots fired. RIH with gun #4, shot 11166'-11186'MD (20' ref. CNL 4/13/82) 4 spf 1200 phasing, flowed to separator for clean-up POH - all shots fired. RIH with gun #5, shot 11202'-11212'MD, 11149'-11159'MD (10' and 10' ref CNL 4/13/82), flowed to separator for clean-up. POH - all shots fired. RIH with gun. #6, shot 11129'-11149'MD (20' ref. CNL 4/13/82) 4spf 1200 phasing, flowed to separator for clean-up. POH - all shots fired. RIH with gun #7, shot 11085'-11105'MD (20' ref. CNL 4/13/82) 4 spf 1200 phasing, flowed to separator for clean-up. POH - all shots fired. RIH with gun.#8, shot 11065'-11085'MD (20' ref. CNL 4/13/82) 4spf 1200 phasing, flowed to separator for clean-up. POH - all shots fired. RIH with gun #9, shot 11050'-11065'MD (15' ref. CNL 4/13/82) 4spf 1200 phasing, flowed to separator for clean-up. POH - all shots fi red. Run static pressure survey after 24-hour shut-in, RanSSSV, Secure well 8/5/82. 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 July 21, 1982 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: RE: D.S. 13-18 D.S. 13-20 Permit No. 82-26 Permit No. 82-35 Permit No. 82-9 Enclosed are the "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Eng-ineer DFS:TKKW Enclosures Distribution: Sohio Petroleum Company ARCO Alaska, Inc. is a ~_~ubsidiary ol AtlanticRichfieldCompany ,'"~, STATE OF ALASKA ~ ALASKA ~,L AND GAS CONSERVATION CC,,,MlSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-26 3. Address P.O. Box 360 Anchorage, AK 99510 4. Location of Well 2703'FNL, 1634'FEL, Sec 14, T10N, R14E, UM (surf) 2534'FSL, 2221'FWL, Sec 11, T10N, R14E, UM (tpp producing interval) 2843'FSL, 2227'FWL, Sec 11, T10N, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 87 ' I ADL 28311 12. 8. APl Number 50-029-20718 9. Unit or Lease Name 10. Well Number D ~ S. 13-17 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 perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station 'for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work will be dOne through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. RECEIVED JUL 2 ~ 1982 Alaska Oil & (~as Cons Comn~ission Anchorag'~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Engineer Date Conditions of Approval, if any: ORIGInAl' 'SlfflIEI~ Approved by J~Y LOtlTtlE C. SMITH COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate AHt,;U AlaSKa, Inc. Post Office Box 360 Anchorage, ~ka 99510 Telephone 9F ~77 5637 June 18, 1982 Reference: ARCO OPEN HOLE FINAL LOGS D.S~13-17 D.So13,17 DOS.13-17 D.S.13-17 D.S.13-17 D.S.13-17 4/3/82 FDC Run 2 5" 4/3/82 FDC/CNL Run 2 5" 4/3/82 BHCS Run 2 5" 3/30/82 & 4/3/82 DIL/SFL Run 1 & 2 2" & 5" 4/3/82 Profile Caliper Run 2 5" 4/4/82 Cyberlook Run 2 5" easesign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 243 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO ". MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY Alas~ 0it & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRIchfieldCompany May 18, 1982 Mr. C. V. Chattezton Commissioner StaLe oF Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr~ve Anchorage, AK 99501 SUBJECT: State Repozts - Prudhoe Bay Dear Mr. Chatterton: Enclosed a£e Wei1 Completion Reports For the Following drill sites: 12-7A 14-28 13-17 14-30 '13-23A 15-3 14-9B 15-12 Also enclosed ace monthly reports For April on these d~ill sites: 2-19 14-17 2-20 15-4 2-21 15-5 13-18 Eileen #1 13-21 West Sak 24 Surveys For 2-19, 2-20, Eileen Itl, and West Sal< 24 are being reran; completion reports For these wells will be submitted when the corrected surveys ar.e.received. The zeports on Eileen Ill and West Sak 24 are oF a confi~dential natuze. We would appreciate it if you could sLoze this information in a secuze area. Sincezely, P. A. Van Dusen District D~illing Engineez PAV:JG/llm Enclosures GRU6/A9 STATE OF ALASKA ,,,~'-~ ALASK~ .LAND GAS CONSERVATION C( ~._,SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, ]:nc. ~ 82-26 3. Address 8. APl Number P, 0,'Box 360 Anchorage, AK 99510 50-029-20718 4. Location of well at surfaceI' [OC'ATJ--Ns~O 9. Unit or Lease Name Prudhoe Bay Unit 2703'FNL, 163Z;'FEL, Sec 14, T10N, R1/4E, UN ~ VERiFiED ' At Top Producing Interval 10, Well Number 2534'FSL, 2221'F~/L, Sec 11, T10N, RlZ;E, UM At Total Depth J~'J~[~ 11. Field and Pool 2843'FSL~ 2227'F~/L, Sec. 11, T10N, RlZtE, UM Pz'udhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0il Poo~ 87' RKBI ADL 28311 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. t 15. Water Depth, if offshore 16. No. of Completions 3/13/82 4/3/8?- 4/14/82I N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11551'MD 9171'TVD llS05'MD 9135'TVD YES~] NO[] 2157' feetMD 1900' (Approx) 22. Type Electric or Other Logs Run DIL/SP/GR. DIL/BHCS/GR, FDC/CNL/GR/Cai, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ?R" 91.5# H-AR Surf 78' ~g" 17R(~# Polese[ griN-95 7" 29.N# L-Rg 1055]' 115Z~8' 8-1/2" ~65sx 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) N/A 5-1/?,, 1nSnT' lnsnn' · 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production MethOd of Operation {Flowing, gas lift, etc.) N/A · Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE GAS-OIL RATIO TEST PERIOD OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HouR ·RATE I~. 28. CORE DATA MAY 1 9 1982 A!aska 0il & Gas Cons. Com~is$ior~ Anchorago Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GRUS/A28/29/30 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 11052' 8780' N/A O/.W Contact 11460' 9100' 31. LIST OF ATTACHMENTS Drilling Hist:ory, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observatiOn, injection for in-situ combustion. Item 5: Indicate which elevation is .used as reference (where not otherwise shown) for depth measurements given in other spaces 0q 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' 'lndi(~ate whether from ground level (G L) or other elevation (DF, KB, etc.). I'(em 23: Attached supplemental records for this Well should show the detai'ls 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. i-.:¢;~"n 28: If no cores taken, indicate "none,'. Form DS 15-17 Drilling History NU 20" Hydril & diverter. Spudded well ~ 1430 hfs, 03/13/.82. Drld 17-1/2" hole to 2520'. Ran 60 its 1'3-3/8" 72#/ft, L-80, BTC csg w/shoe ~ 2507'. Cmtd 13-3/8" csg w/2450 sx AS III. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.0 ppg EMW - ok. Drld 12-1/4" hole to 10,881'. Ran DIL/SP/GR. Ran 256 its 9-5/8" 47#/ft, L-80/500-95, BTC csg w/shoe ~ 10848'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 11551' TD. Ran DIL/BHCS/GR, FDC/CNL/GR/Cal. Arctic packed 9-5/8" x 13-3/8" annulus. Ran 24 its 7" 29#/Ft, L-80, BTC csg f/10551'-11548'. Cmtd 7" lnr w/365 sx Class G cmt. Drld cmt to 11505' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL. Ran 5-1/2" completion assy w/tail ~ 10587' & pkr ~ 10500'. Tstd tbg hanger & packoFf to 5000 psi - ok. ND 8OPE. NU tree & tstd to 5000 psi - ok. Displaced tbg to diesel. Dropped ball & set pkr. Tstd tbg to 3000 psi & annl to 200 psi - ok. Tstd tbg to 200 psi & annl to 3500 psi - ok. Closed SSSV ~ 2157'. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig ~ 1900 hfs, 04/08/82. 3G:llm 05/13/82 GRU3/B22 MAY 1 9 1982 l!aska Oil & Gas Cons. Commission / ,nchorage Eastman ~~ Whipstock 1)) A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TI ONA L SURVEY ARCO ALASKA, INC. COMPANY DS 13, Well Number: 17 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER TYPE OF SURVEY Directional Single Shot DATE P~C 0 7 ]982 SURVEY BY OFFICE ,amter:Lcan D:Lrectiona'l Dr:Lll-tng' (G. 'Z'h-Jbodeat.~ ) ARCO ALASKA, INC. DS 13, WELL NO: 17 DSS (AMERICAN DIRECTIONAL DRILLING) PRUDHOE BAY, ~]~!RT~ SLOPE, ALASKA DSS, 0-11551 MD, ASSUMED VERTICAL TO 2700 MB. SURVEY F'ROVIDED BY AMERICAN DIRECTIONAL DRILLING RECORD OF SURVEY ,AR_.L ALA.:.I-:.A ~ I NL.. COMF'LI'I'f-'~T I ON F'AGE I",IR. 1 :, "' 'i " - ,c/. 4.2: '= F """' F" R JDHUE BAY, NORTH SLOF'E, ALASKA (,; · 0'.~ 1 ._,-hi JV-o..-..'. 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'~. 1 .-7.,. 9'. · 'p6 ._ 712 . .=,._, 911 ;Z. .. _ __._. ,.,:.....=,. 7.,:._- W =' "" . N 1:2: G: W .......... · ,::- -. z- · Pi ."5 · D I ._,TANL. E · '._ 71 !57 FEE]' I : : ' I i ' ' ' : i : l Ill }!! ' ' i ~ i [ ] ~ i I : i I Ill I il i I ! I t [ i I t t [ ['i ! [l~ I i i [ t I I i i [ i ~ I ] I I i I t I ! I i [ ~ i ~ [ ] ~ ~ [~ [ {t! ~ I !ti [tII iti! fltl~i I ~ l[[l ! I i II iiil i I i~ iii: il [il[l i i [ [ l [ [ LIi[ ill~ lii[ t' ~l I -iTl Il I ~ I I,' il lll~ '~ ~i-'lli I~ _ I i i .... 4. ~-i ~ [ -, ~;" L.':~ ~ : .] [ ' ~1 I I t. : . t-~ : I ' I I .I I i . , · :~ ,lilt ~ ~" I f'[' ' - : i Ii i lJi: .'1.1_1. I ,J il [ I [ I ~I [ ] - [ ~ Jl J : I I I i j II I I i J I1~ :: l'J }' t [ ~ [' [. · l I J i ~ .[ I ! J I !., J I i [.t I I J t I ' I I J . . t I j~ .- -J J J t It -FFF I-I' I.l. I'FF- F--t I~ t J l I i I I il J i j i t j [ !J ti J I J j j lJ 'J- jj : I J t il I Ii J J t i J J J I I j j i J [ ' ' Jilt J I lJJJl JJ .ti i [ till Jl[l i ! i I l l! I I }II: i!i~ {j j ~ j j J j~ j/ Iii! I i I' Ii i J [ [[ i. i i l.l llll I I j J J ! i II I -' '' ~ J J J jT' : J I J t lj l It i !JJ ti '[ f t I [[{ ','l I I1 [ t I [J J j ~I }i j . I lllf I t{i [ {Ii [ [ It i J J J J I J J J J J J ~ J J [~ JJJJ lJJJ J JJJ JJ J J [ . JJJJ J 'J J J~ J J J J J J , ~ ..... , , , : , : i ILl _ i i i i t I I I i I J J J i J I I I I i J JlJ 1 _ spe -sun April 16, 1982 Mr. Bob Hines ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. Boss-16004 Well: 13-17 (SECl4 T10N R14E) Prudhoe Bay Field North Slope, Alaska Survey Date: April 14, 1982 Operator: Blaine Baertsch Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss 'Gyroscopic Multishot Direc%ional Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager KB/pr Enclosures RECEIVED M~y o 61982 Alaska Oil & Gas Cons. 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()0 2073.31 N 75:B,, 60 W 800. ,/~-,:::"?,F:;9 ::'"""" .... {")(") 5'~:'("~(') (")(') 2207 ~:;':::' N 79':; 7i, W 872 ....... ......... ::., :, / .......................... ...._, :::() 72 62 :~:::::::~::: ::::::::::::::::::::::: :.~:~::,~::::i :?: ~: : <::, ~ ,=, Z :, ~,~, ::: :::::: :~. :c~ i(J:C~ ~ :~ JL): ~: .:~:~::~z:~:~ ~.;~, J::.:::N:¥: :::::, ~:: ~::~ ¥:.:,:',:,~,~ .:'6~:::: ~ ?::::::': ::::: ~:::: ::~ ~ )~-,:~ ~+::~ ?: t~: ~::~:~ ~:~ ~ ~:::: :;t~ ,;:~,,::~t~: ::::::?~::~!~ :~ ~:: ?::::~:5:~ ::~ ::~:? ::~ :: ~ :~: :~: : :::~:~: ~J)~:~:~ : ~ ~'~:~ :':~ ~: ~:~ ~{~5'~4;.~ ~:::;~ 'H: :~ :: :~. :~ ::::::::: : :: ::::: :: ::::: :: ' ~::' ~t:'~ '77.:1-i <~: 4~:~7 ~ 0() 6400. ()0 2'703.44 N 1 ()01.61 W ' ~ 254~ :3'? 6!?. '?7 '7'?()6 AS:~:: .... 7 ,, ()0 6500. ()() :]~:0::?, ~. ()0 N ]. 0:'::::: ........ 52 W ' ~ :3 ~ '::~.- . :-, ...... ::~ (: ..... 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". ..' / ': · ."] .'", [::' [-7 -~ ' ,'"~ ................. ~.~ ................. ~ ........ =4. ~-~ ............ ~ ~' ~-~. ~'~ ..... .= ....... :-.~o-i-~,~-44 ~ F~---,'.--',=.=~-:~::~.,=, .~:-::~ t "W :":': ...... = =='-i': ~, ~ "-" ::. ~. :~'?:: · ..... t :.- m : : ..... :~ "~ '~ · . : ::: · ' . . . ....: .: .. ,.~ .~ ::.~::~. ~ : ::': ~:~:?~.;~.: :: : : :?:7 4'::":?: ~:~'~ ~':~ r~r~; ~"~:P :: : 4-~):"D :: : : ::: ~53:~ :: .'..~,. --.:'.~ : · / ~..? :~:~: ',~'~,..'::' ~: :, ~.,, ',,~ ,~. ,,~ ' ~ ,. ',~ ~'~' ~'-~ :: ~. · :'. :: a:~: ~ ~ - ~'~ .~ ~ ~.-? ,' ~ .~ : : ' I'::'F: n"i 1..-IC E B/.'~V AF'R II ....1 ~:i, 1 ';?82 I:)[ii]::;:.'[V[i:~O I...l:.-];II:~l(]i [)il .... Biiii]:::"f"HF!: ANi] SF:'ERF~:Y ~i;I..fl\l F{;I..iRVI:"~Y I]ATA .. 0.00 2000.00 4000.00 6000.00 8000.00 i0000.00~ ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. Boss-16004 · Well: 13-17 (SECl4 T10N R14E) Prudhoe Bay Field North Slope, Alaska Survey Date: April 14, 1982 Operator: Blaine Baertsch Scale: 1" = 2000' ~o~o. oo ~o~o. oo 6000. oo VERTICf4L PROJECTION 155i -2oho. oo -~ oho. oo TRUE NORTH -5000.00 -4000.00 -3000.00 . ~000.00 · . -1000.00 Surface Location (2703FNL 1634FEL) 0.00 ~ --1000.00 ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. Boss-16004 Well: 13-17 (SECl4 T10N R14E) Prudhoe Bay Field North Slope, Alaska Survey Date: April 14, 1982 Operator: Blaine Baertsch Scale: 1" = 1000' HORIZONTRL PROJECTION Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ~.R(~ £B ~ 13- / 7 ' '~ '0~erat6r,' Wel-1 Name and Nun~ber Reports and Materials to be received by: ~~__L~__~~- Date Required Date Received Remarks ~, , Completion Report Yes ~.~/~_ ~,.~ ~_~,~ Well History Yes ~---__/~__Z ~,_- ~./~. .ua. ,,o~ .... Core Chips - .... /v'~ '~e. -~', ~A'~' ' Core, Description Registered Survey Plat Inclination Survey ~/~_ . ~~ ,,. Directional Survey Vel--P/ ~.__.} * ,..- ~~/ ~..-~.x_....~.. ,,,, Drill Stem Test Reports , . Production Test Reports Anchorage. Alaska 99'51'3 ., ' Telephone 30- "77 5637 ~iay 10, 1982 Reference: ARCO MAGNETIC TAPES & LISTS D.S.14-28/ 3/19/82 D.S.ll-7-~f' 2/26/82 D.S.13-17~/4/13/82 D.S.14-9B~-~ 4/10/82 D.S.15-14// 12/25/82 DS..14-9BL/ 4/21/82 Tape # ECC 1252 Tape # ECC 1238 Tape # ECC 1243 Tape # ECC 1275 Tape # ECC 1192 Tape # ECC 1283 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 148 DISTRIBUTION NORTH GEOLOGY. R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON D&M GEOLOGY STATE OF ALASKA Post fOtllce ~ox 360 Anchorage. Alaska 99510 Teieghone 9'.' 77 5637 April 30, i982 Reference: ARCO DIRECTIONAL SURVEY DATA D.S. 13-17 D.S. 13-23A D.S. 14-30 D.S. 14-28 D.S. 1t-6 D. S. 12-7A 4/14/82 Gyroscopic Job No. Boss-16004 4/12/82 Gyroscopic Job No. Boss-16003 4/7/82 Gyroscopic Job No. 1307 3/19/82 Single-Shot Job No. A0382D0302 1/30/82 Gyroscopic Job No 5300 1/2/82 Gyroscopic Job No 3291 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 136 DISTRIBUTION DRILLING .,~~ ~ GEOLOGY 0 61982 Oil & Gas Cons. Commission Post Office Box 360 Anchorac~. ':'--.ko 93513 Telephone 9L 77 5637 April 29, 1982 Reference: ARCO CASED HOLE FINALS .. D.S.14-9B /10/82 D.S.2-20 ~t 4/12/82 D.S.13-1? ~-~4/7/82 ,D.S.1.3-17j 4/13/82 D.S.2-20 ~ 4/19/82 D.S.7-11'-'"' 3/31/82 DS..15-3 ~ 4/2/82 D.S.15-3 j 4/2/82 D,S.7-14t 4/1/82 D.S,14-28~'' 3/28/82 D,S.17-10~' 3/15/82 D,S,14-29~'-3/1i/82 D.S.13-23Ax-/3/17/82 D.S.14-29J3/ll/82 D.S.14-29 ~ 3/11/82 D,S.11-2Y .4/10/82 D.S 2-13/ 4/i9/82 CNL Run 1 2" & 5" ACBL/VDL/GR Run'l 5" ACBL/VDL/GR Run 1 5" CNL Run 1 5" CNL Run i 5" CNL Run 1 5" ACBL/VDL/GR Run 2 5" CNL Run 1 5" CNL Run 1 5" CNL Run 1 5" Perf Record Run 1 5" Pipe Analysis Log Run 1 5" CNL Run 2 5" CNL Run 1 5" CBL/VD Tun 1 5" Collar & Perf Log Run 5 5" Collar & Perf Log Run 1 5" ~se sign and return the attached copy as receipt of data. . ~ Mary Kellis N~rlt t~ Engineering TransmitOal # 134 DISTRIBUTION R&D ~,..~B~,. Y,~ D&M ~ GEOLOGY MARATHON . .,.~.~ · ARCO Alaska, Inc. . ...*~ ~;~; ·, .-~ . ,' April 30, 1982 Hr.~.C.V. Chatterton SLate of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: StaLe Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports For the Following drill sites: 11-6 11-7 14-29 15-2 1A-15 (Revised) Also enclosed ate monthly reports For March on these drill sites: 2-19 15-4 2-20 Eileen 13-17' West Sak 24 13-23A 1A-16A (Sidetrack) 14-9B IE-9 14-28 Oliktok Pt. ~tl 14-30 West Sak 25 15 -3 We ate also including plug and abandonment subsequent sundry reports on Eileen ~/1 and 1A-16. The reports on Eileen //1, Oliktok Pt. ~/1, and th~ two West Sak Wells ate oF a confidential nature. We would appreciate it iF you could store information concerning these wells in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG:pb · , STATE OF ALASKA ALASKA AND GAS CONSERVATION CO MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-26 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50-029-20718 4. Location of Well at surface 2703' FNL, 1634' FEL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 87' RKB 14, TION, R14E, UM 6. Lease Designation and Serial No. ADI ?R31 1 9. Unit or Lease Name Prudhoe Ba~v Unit 10. Well No. 13-17 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool For the Month of March ,19.~___ · 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1430 hrs on 03/13/82· Drilled 17-1/2" hole to 2520'; ran & cmtd 13-3/8" · csg. Drlg 12-1/4" hole to 10,822'. Ran DIL/SP/GR as of 03/31/82. See Drillinq Hi story· 13~ Casing or liner run and quantities of cement, results of pressur9 tests 20" 91.5#/Ft H-40 conductor @ 78' Cemented with 1706# Poleset 13-3/8" 72#/ft L-80 BTC casing with shoe @ 2507' Cemented w/2450 sx AS III See Drilling Hi story. .-14. Coring resume and brief description N/A. 15. Logs run and depth where run 'DIL/SP/GR. .1 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. SIGNED . _ TITLE. Area Drilling Engineer 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 GRU3/B20/21 Submit in duplicate Rev. 7-1-80 DS 13-17 Drilling Hi story NU 20" Hydril & diverter. Spudded well @ 1430 hrs, 03/13/82. Drld 17-1/2" hole to 2520'. Ran 60 its 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2507'. Cmtd 13-3/8" csg w/2450 sx AS III. ND 20" Hydril & diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.0 ppg EMW - ok. Drld 12-1/4" hole to 10,822'. Ran DIL/SP/GR as of 03/31/82.. JG:hrl 04/17/82 GRU3/B22 ARCO Alaska, lnco Pos! @ ffi,,' ~, April 22, 1982 Reference: ARCO MAGNETIC TAPES & LISTINGS D.S.15-3 3/21/82 Tape #62717 : ' D'S.13-17 4/3/82 Tape #62744 D.S.2-19 3/19/82 Tape #62666 ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #124 DISTRIBUTION NORTH GEOLOGY R&D MOBIL DRILLING GETTY PHILLIPS D&M o SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Alaska. I~C. is a SuCsto,ary of Allan.¢~chf~e..~Cor'npan¥ ALASKA OIL AND GAS CONSERVATION COMMISSION Thru: Cha~e~rton Commissioner Harold R. Hawkins March 23, 1982 108/M Witness Leakoff Test ARCO ~ill Site 13-17 Prudhoe Bay Field M~arch 18, 1982 - I left ARCO's Kuparuk Field, .subject of another ~e~rt~~ ~0-ARCOes Dril! Site 13 location to witness a leakoff test. The mud weight after circulating warm fluid for 22 hours was 8.6 ppg with hydrosatic head of 1151 psiS. The shoe of the 13 3/8~lwas drilled out to 2530 feet. The shoe was at 2507 feet. I witnessed the leakoff test of 316 pounds at the surface, with appr~imately 14.47 pounds of bottomhole pressure, for five minutes with no leakof f. In summary, I witnessed the leakoff test for ARCO on Drill Site 13, on well No. 17. Tests were performed satisfactorily. ALASKA OIL AND GAS CONSER~ATION COMMISSION Thru z Chatterton Ch~i~nw/ . Lonnie C. Smith~~ Commissioner Petroleum Inspector March 22, 1982 108/C Witness BOPE Test on ARCO~s D~ 13-17 Sec. 14, T10N, R14E, UM Permit %82-26 W_e~n__es~ay_,.._M_a~h_..~8~___1~982 - The BOPE test began at 7500 p.m. and was con'clu~-at-9-t-'o~o-~om. As the attache~ BOPE report shows, there were no failures. In summary,. I wi~nesse~ the 8OPE test on ARCO~s DS 13-17. /'~ STA'£E OF A1,ASKA ALASFJk O_ & GAS CONSERVATION COblMISSION B.O.P.E. Inspection Report Drilling Contractor ~,OL.~_J ~cation, General ~.-. ,~ Well Sign General Housekeeping ..~..,.(.".' . , Reserve pit . Rig BOPE Stack Tee t Pres snare Date .... ?;el l'D Y' /-~- / Representative Permit ~ . .Casing Set @ ft. Repre sen ts t ive ~-/~J" ' /~/j ~'~'' ACCUMULATOR SYSTEM Full Charge Pressure ~ ~ ~'~o psis Pressure after Closure /3~O psig 200 psis Above Precharge Attained: Full Charge Pressure Attained: N 2 Z/ ~ c3/~n ps ig Controls: Master ~- -~ Remote~/~ .~ Blinds switch cover ~.I Kelly and Floor Safety Valves Annular Preventer Pipe Rams Blind Rams Choke Line Valves Upper Kelly. Lower KellM Ball Type. Inside BOP / Test Pressure ! / Test Pressure . / Test Pressure ,~--', -~' · / Test Pres sure ~."/' H.C.R. Valve / Kill Lin~ Valves ~__. Check Valve / Test Results: Failures ~{3 Repair or Replacement of failed equipment to be made within Choke blanifold ~:C-'J~ Test Pressure No. Valves / ~,. NO. flanges ~ ~ Adjustable Chokes /3 . Hydrauically operated choke Test Time ~-- hrs .., days and min~ sec mi;l~2 '~' sec Inspector/Commission office notified. Remarks: Distribution orig.' - AO&GCC ....... . ....... //' t cc - Operator [ .-) cc - Supervisor Inspector ":~"//~" ("~ ,, Area ~ril I tn~ '~ineer. ARCO Al'aska, "'Ins, P. O. Box 360 Anchorage, Ala8~ 99S!0 prudhoe Bay Unit DS 13-17 ARCO' Alaska, Ins, Permit' No. 8S'-36 Sur,-Lees S.?03f~, t654'FJ~, See 14, TION, R14E, Bot-t.omhole ..Lee= 3355'~.L, .--2693'FBL, Sec 11, TION, RI4E, 'Dear ~r. Ma ~ or: l~nclosed is the approved appileation for permit to drill the above referenced wel I., . Well smples and a mud log. are not required. A continuous direet~ional survey is required as per l0 AAC 15.050(b):(~'). If available, a tape oontaint~ng the digitized log information oh. all be submitted on all logs for co~ing except e~erimental logs, velocity surveys and dieter su~eys, Many rivers in-Alaska and their drainage systems have been classified as_ important for the spaWning or migration of anadromous fish, Operations in these areas are subject to A.$ I6-0~'870 and 'the re~lations promul~ted thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator*8 Office, Department of Fish and Game. Pollution of' any waters of the- State 'is prohibited by AS 46, Chapter ~,. Article ? and the r'e~lattons promulgated thereunder (Title. 18'.Alaska Administrative Code, ~apteF ~0) and by.'the Fe~ral~-~ter:PollUtion ~ntrol Act, as a~nded. Prior to e~nein~ operations you may ~ contacted ~ a representative of the ~part~nt of Envi~o~ntal ~nse~atton. in sehedulingtfteldw work, we would appreetate your notifyi~ ibis thi 48 houFs slier the well We ~utd also like to ~ no-tiffed so that a -repFesentative of the ~TtSSlOn m~ ~ p~eOent tO witness teat t~ of bio. ut p~eventer ~i~nt ~'fo~e surface o~'st~ shoe i8 d~illed. In the event~of ~openoion oF abando~nt~ please give this offt~ adequate ~~e notifioation ~o that ~ my have a witness pFesent. VeFy t~'iy ~aiman of ~' V~ O~ ~ -Alaska .Oil and Oas ~nse~ation ~isston svFe ~partment offish & Game, Habtt&t Section w/o ansi. Department of ~vtr~ntal Conservation w/o enol. ARCO Alaska, Inc.?'~. Post Office ~ ,360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 11, 1982 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject- DS 13-17 Permit to Drill Dear Sir' Enclosed please find our application for Permit to Drill DS 13-17 and the required $100 filing fee. Attachments to the application include an as-built drawing, a plat detailing the section and plan views of the proposed wellbore, a proximity plat showing the subject wellbore's position to the nearest well drilled, and a sketch and description of the BOP equipment and testing procedure, including anticipated pressures. A surface hole diverter system will be used on this well. This well should spud approximately March 6, 1982. Your early consideration will be appreciated. Area Drilling Engineer MAM'cm Attachments RECEIVED. FEB 1 6 ]982 Alaska 0il & Gas Cons. C0mrnJssio~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA t.,L AND GAS CONSERVATION CG..,MISSION I ERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL ~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHI(~ [] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [] .. ~, DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2.' Name of operator ............. ARCO Alaska, Inc. , 3. Address .......... P.0. Box 360 Anchorage, Alaska 99510 4. Location of well at surface .... 9. unit'or lease name · 2703' FNL, 163.4' FEL, Sec 14, TiON, R14E, UM Prudhoe Bay Unit At top of proposed producing interval 10~ Well ·number ...... ' 2370' FSL, 2568' FEL, Sec 11, TiON, R14E, UM DS 13-17 · At total depth ' 11, Field and pool 3355' FSL, 2693' FEL, Sec 11, TiON, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF etc.) -. i.- 6. Lease designat'ion'and serial' no.' .- . Prudhoe 0i 1 Pool 87' RKB I ADL 28311 12. Bond information (see 20 AAC 25,025i - ....... Type Statewide Surety and/or number Fed Ins Co. #8088-26-27 Amount $500,000 i3. Distance and direction from'nearest'town 14. Distance ~0 nearest Property or lease line - ' 15. Distance to nearest driil'ing or completed NE Deadhorse, AK 6 re,es 2370 feet we, +1460 f,et 16. Proposed depth (MD & TVD) 17.' Number of acres in lease ..... 18. Approximate spud date ......... 11,787'MD 9397' TVD feet 2560 3/5/82 · -19. If deviated (see 20 AAC 25.050) 120. Anticipated p~essures ' ~ 37 ~ 7 psig@ SurfaCe ,' KICK OFF POINT 2700 feet. MAXIMUM HOLE ANGLE 45 °l(see 20 AAC 25.035 (c) (2) 4573' psig@ 9397ft. TD (TVD) 21 ......... - Proposed Casing, Liner and Cementing Program SIZE CASING AND ii'HER .... SETTING DEP;FH .... QUANTITY OF CEMENT ' Hole Casing Weight Grade Coupling ' length"' . MD TOP TVD MD BOTTOM TvD (include stage data) 30 20 94 H-40 Welded 86. 35 I 35 ' 1'21 I," 121' 275 Arcticset to'surf 17 1/2 13 3/8! 72 N-80 Butt' 2966? ' 34 ' 34" 2500 ~ 2500 ~00 sx Fondu.& 400'Sx 12 1/2 9 5/8 47 L-80 Butt" 10679' ' 33 ,' 33 10712 I 8648' St9'1 -"250 sx 'Class'' S0095 'BUtt ~ ~ I Stg '2 300 sX PF 1 ..... i 9397 400 ~x Class "G" ~' .... ,8 1/2, 7 29 L-80 Butt 1165 .10412 ~8440 1.1787 ~ 22. Describe proposed program: .............. ARCO Alaska, Inc. proposed to'directionally drill this well to 11,287' MD (9397' TVD) to. }roduce the Sadlerochit zone. Logs will be run across selected intervals. A 13 5/8" 5000 psi RSRRA BOP stack will be installed and tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5 1/2" 17#, L-80 tubing, packer and necessary provisions for subsurface safety equipment wi. ll be. run. A non-freezing fluid will be left in all uncemented annuli within the permafrost n erva . ,ac er a ove ,o ce be submitted when the well is to be perforated. KELC/V EU FEB 1 6 ]982 ~3. I hereby certify that the foregoing is true and correct to'the best of my knowledgeAJ:~ska Oil & Gas 00ns. Commission ~~ Anch0rag0 S~GNED T~TLEArea Drilling. Engineer DATE 2,/1!/82~ . The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log reqUired ' ' Directional Survey required i APl number []YES ~NO []]YES ,~NO ~-Y E S []NOI 50- Permit number Approval date ~---,--..,,~"~ J~'~/N-~./~9, .,,~ I SEE COVER LETTER FOR OTHER REQUIREMENTS / ............ APPROVED BY [ ~r///~ ~, ~~)'J,a~ ,COMMISSIONER DATE Ma~'~'h _~_ 1 ~ '# ~- {' ..... ~' by order of the Commission " ' · ,. 'Form 10~,01 Submit in triplicate Rev. 7-1-80 Gl, · iii '*%=-- .................. - ....... - ................ - ':-,. ~. ...... : ,~ 7~:; ... . . .' . :...-~` ~. .... '-'- ......... . . . ...- .- '.~ - . "... .-- ? ..-._ ..- 7._.'.=./~- ~: :... :: ..... 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'--'":':" :- ' -:~' .... -'" '"-': '- "' :"'-'-':' .... - - - D I e~ ¥1~!~6E$ I~It~E 'St.I~'F~¢_:E ' .~...%- :. o ,-- . · '- - .'- Zz2_ -:!" ® _ :' """" --:',=' . ?-. ,. :-i.-;::;:::.-':-L :..X._ ..," - ,," ...... -· . ::!-... · .:-.:: ';~:'-'- ' ° '/ --'----~ ................. ,.' ._ -Z" '.' ' . .--,- . -- ;'-: .... ?' . . . :::':,-:-.--., -' -- ' '-"' :::-~-::".- _.-.-....'--.. ~:"- ...... ----- .... ' .... --. -" .... "-" '. .. ...... _..:. :""'-"...FE.e i?*'i.~,~':' · .i':~:~''. ...... - --'.-. .... "'-'-~. "--"--;'!:.'--"-::":'.." ?-:'-::~ - ':::: - ~aska'0iI a 6-o -' · ~..=:=-' .... _ ..... .- ~o.pons, _. :,-,-....: ' ........=- ------ ............. -~:. .... _: _. ' ;::%~:..-C-i-.:'-/.-::-.-...w.:-:-_:-,._-.- ~6~.a~e_. - '-".. .......... ........ :--.....---.._-."-' --~---- '': ...... ":-! HEREBY C, EFITIF¥ THAT I AM = ..... , :: --:- . -_- ----?.-..:::. .- _.: · .~_.~ - . ~__.. .-_.-.: RROPER~-Y I::iF~GISTF~REO AND . - __----~-_ - -:' ":-~ .i- -:~;'..._ ==-.- ...... r--- - ........ LIGENSED-.'fO" PFIAGTIOE:: LAND _.- .:~-.:.-.:_- _~¢'-i':)~-%.::3_ -.----::;~i-::$URVEYtNG ~N:"-THF,- ,STATE. OF .... .L:::.~.':-?.:??'~-::? ..... : -" .... .., ........ >- .... _ .... :,?:...:~:_. ~ --~--::'.'.-:':--.~.-:-:~:: ---":-'~-L--_-:~ALASKA:' AND i.::.THAT .'iHl$' PLAT... -. ..:,.._.--?:. ........... ~ ....'.~ :~-_,..L.'-~-: :-,'-.~-~._::'--?~4::-~'- :: .... :":~:-~iMEN$1ON8 AND OTHER D~I'AIL$--' . -~-:i7_-7.:(:-'.-{.::..:._.. _._. _-_--:._. ~F.-::..- - :': :--:- --.: "c??ARE OOFIRF_OT;'A$ OF:/. /?,~- -'.':"- .. ' - .-:.-:L:!.: .'::/'-'~: ?-_:_~-- ......................... :-"'-?--'::::-;-"--:---.--.--:~:.... -.---...-.--~_-[~. ~. I%/~B:~ !'7-Ex:)N~L.IC~'TO~"' ~%-~.L~[LT-'-~:?-~---'--:'' ~.... ARCO Oil and Gas Company _.. -' - NORTH ~,ASK~ ~DISTRI¢,T. I~RUDHOE BAY ...... . . . . SURFACE DIVERTER SYSTEM L Note: Valves on diverte~ lines open automatically when the annular preventer is closed. E£EiVED FEB 1 6 1982 · Alaska Oi~ & Gas Cons, Commissior~ Anchorage i. 20" BRADE. I',~HEAD 2. 213' 2000 PSI DR/I.I.LNG · o · SPOOL 3. 20" 2000 PSI ANNUL. A,R PREVENTER. 4. 10' BALL VALVES ~ _.. 5.- RIG DRILLt,'tG RISER . 6. 10' LINES TO SUMP AN;;UL~R PREVE:~TER _ BLIND RAMS PIPE RAMS - -RECEIVED . . -. -FE.-B.I'6 19.82' . · '- ~aska.0il & Gas ConS~'Commission Anchorage · . . _ . . . . ~ . . 13-5/8' SOP STACX DIAGRAM Acc~.~ulator Caoacit,.v Test 1. Check and fill accumulator reservoir to proper level with h~draulic fluid. 2. Assure that accumulator pressure is 3000 psi with !500 psi downstream of the regulator. 3. Obser~;e ti~, then close all units simultane-. ously and record the time znd pressure re~aining after a11 units are closed ~ith charging pump off, 4. Record on IAOC report. (The acceptable lower l i=it is 4S seconds closing time and 1200 psi r~aining pressure, ...... . . · , .: · 13-5/B' BOP Stack Test · . 1.~' Fill SOP stack and manifold with a non-freezing 1 iquid. .. . 2. Check°that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhea~m. Run in lock - d~.screws. . ' 3. Clo~e 'annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a.250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. 5. Increase presure to 3000 .osi and hold for a mini:u~ of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and clo~e top set of pipe rams. Increase press~mre to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure '~' .. to zero, 8, Open top.set of pipe rares' tb, e~ close b°ttom set of pipe rams. '. Increase pressure to 5000 psi below the bottom set of pipe ra~s and hold for at least 3 minutes. . ~. Test remaining untested manifold valves (if any) with' 5000 psi ups.treaa of valve and zero pressure downstream. - 10. Bleed pressure to zero. Ope~ bottom set of pipe ra~s. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all eq.uip~ent. Open blind rz~s. Make sure ~anifold and lines are full of non-freezing liquid and all ~alves are set in drilling position. 13. Test standpipe valves to 5000 ps). 14. Test I(elly cocks and inside BOP to 5000 psi with Koo:ey pump. .. 15.Check operation of Degasser. ' _ 15. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. · .- . 17. Perform co=olete BOPE test' once a week and functionally operate BOPE ' Rev. ' - dO _~00 ............. _50o~.~ i ~ i ~ i ........ L..:J ...... 4~_0.: ................ j ........... ! ........... i ...... : ............ m I3,__I~ELL NO, ..1, .iPROPO'. ' '~ - -j -:I-- i..'i ~ ~ ! P~OHOE BAY, "aRT" ,LOPE, '- · i ....... i... '._ _'T __: : : ~ i E~THRN m'IPSIOCK, ~NC. .... .' .... '. ..... j./.._ ..~ ............ - ...... ~ ........ - ............... ~ ...................... ., - i ' '~779 I · , . ., I ..... . . ' t ' , , . j__ ~ ........... , ...... . .. ~ . . I_ ~ . I , . _~ _ J '- ~ I ! ' ' ii . ~ . . i ~ I ' I · 3749 356et · ! i I ' i ' i ........ gOO._- ............. , .......... ,. ......... . ~ ! . I i .qi[']n- -! ~ ~ -' ' ~£D RLR5K 6894 i 6655i CHECK LIST EOR NEW WELL PERMITS Company Lease & Well No. ITeM APPROVE DATE (1) Fee ,/ (2) Loc 8) (3) Admin (4) (5) (~ thru 11) 10. 11. YES NO 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ............................ 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included .............. 7. Is operator the only affected party ........................... ..... 8. Can permit be approved before ten-day wait ......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Casg ~/ ~,-./~,~-~ 12. ~2 thru 20) 13. 14. 15. 16.- 17. 18. 19. 20. REMARKS 21. 22. 23. 24. ~21 thru 24) Is conductor string provided ...................................... Is enough cement used to circulate on conductor and surface ....... Will cement tie in surface and intermediate or production strings . Will cement cover all known productive horizons ................... Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ............. ~ Is old wellbore abandonment procedure included on 10-403 ............ ~ ~~ Is adequate well bOre separation proposed ........................... ~ Is a diverter system required ......................... .~~~_7/ ~- ~/ Are necessary diagrams of divertgr ~d B~'equlp~en~ ~ttac~e~ : Does BOPE have sufficient pressure rating - Test to ~O psi g Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. ~tf~/~x'~z~MM~ (6) Add: z~~'~ ~-/'~ ~--~'~25. Additional requirements ............................................. Additional Remarks: Geology: Engin~B~.' WVA ~ JKT~AD JAL ~TM ~ ,~ ~ rev': 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ .. NO 'special'effort has been made to chronologically organize this category of information. PAGE I ARCO ALASKA [NC, NEUTRON NEUTRON NE TRON RAY PAGE 2 ARCO ALASKA INC, NEUTRON NEUTRON NEUTRON RAY ::1.0890,0 '368,2 ....... 347.1 ~,09 83,3 -0,07 I0 0,0 376.§ ................... '~ ~:-4.";";'/-' ......... ~5,~ ............. ~?'"; 9 0,03 10~50,0 331.8 326'6 50,69 82,8 z 0 ~ 5 0.0 6 ~ 8. o ........... ~ 93'2 ~' ......... ~7~-6' ................. PAGE ARCO ALASKA INCo -17 ,----SCHLUMBERGER .... * LiS TAPE YEI~IFIO~TION LIS~i] LYP O09'.HO~ VERL[IC&TIO~ L:ISTIN~'~ -Pm, GE 1 ## REEL ;HEADER ## SERV1:3E NAME : SERVI DATE ~,82/04/14 REEL ;NAME· :REEL ID C~gN~I~UATION ~ :01 PREVIOUS BEE[ COMMENTS ** TAPE HEADER ** SERv 1:3.E: NAMEI:SER V I ~,~"~ A ' '8.2/04/14 D TE · ORIGIN ::1070 TAPE NAME ~:~ 62~44 CONTINUATION # :01 PREVIOUS TAgE : COMMENTS :TIPE~ COMMENTS *~' FILE HEADER ** FILE 'NAME :SERVIO. OC 1 SERVICE NAME : VERSION # .. DATE : MAXIMUM LENGTH : 1024 FILE TYPE~ { PREVIOUS FILE : ** INFORM:~ZlON RECORDS *# MNEM iCONTEN~S CN : :ARCO :ALAS.~A INC WN : DRILL SITE 13-1~ FN : PRUDHOE RANG: IO~N: iON SEC~ 14 CO~N: NORTB SLOPE STAT: ALASKA CTRY: USA MNEM CONTENTS' PRES: DlbgO1F *~ RECORD TYPE 047 ** ** RECORD tYPE 047 ** UNIT .) TYPE 000 000 000 000 000 000 000 000 000 TYPE 000 CATE 0~0 000 000 000 000 000 000 000 000 CATE 003 SIZE 016 016 Oli 0O4 0 4 00~ SIZE{ 007 065 065 065 065 065 065 065 065 065 CODE 065 LVP C09,HQ.2, VERIFICATION LISTING PAGE 2 RECORD '[~PE 047 ** *# COMMENTS ** \ SCHLUMBERGER \ \ ALASKA COMPUTING CENTER \ COMPANY = ARCO ALASKA INC. WELL ;.=' R '~ .~ ,XIJX. :.SITE 1~-X7 FI EL0t -- PR. UDROE B~' COUNTY : ~RORTH SLOPE. ST:~E = ALASKA JOB # 1)707,A52744 RUN N2, LOGGED 03-APR-82 BOTTOM [,OS~ LNTERYAL TOP LOG ~'INT~RYAL C ~5. IN G-LO $~G ~R CA~;I NG-LO.GGER BIT $1Zgl BIT SIZE TYPE HOLE FD~ID DEN SI TY = 11526 FT. -: 10819~[.T, = 13 3/8 IN, {. 2503 FT. := 9 5/8 ~IN, ~ 10~ FT, = 17.25 I~.. 72 00 LB/!Fi2515 FT. :"- 12.24 !.IN }47~00 LBIF 10822 FT, : 8.5 INi. {155, FT.- c~IIGNtStU~ONATE = 9.8 LB/G LVP 009.;1-03 VE~IF~CATI'~N II]S~[G VISCOSITY = 38.0 $ PH := 10.5 FLUID LOSS -= 4.8 C3 R~ @ MB~$, TEMP, :: 1.700 RMF ~ M..RS, TEMP, = I 480 RM B~ = .600 65 0 65i0 65 0 197.0 MATRIX LIMESTONE #* D.9~ ;.fORMAl RECORD #* ENTRY BbDCKS TY'.FE :~ IZE REPR OCDE 4 I 66 8 4 73 9 4 65 0 I 66 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT AP1 API AP1 API FILE 1D ORDER # ,LOG TYPE CLASS MOD NO. DEPT FT 0 t( 0 0 0 SFLO DIL OHMM 7 0 0 0 0 IbM DIL OHMM 7 0 0 0 0 ILD DIL OHMM 7 12 46 0 0 SP DIL NV 7 1 0 0 0 GR DIL GAPI 7 31 32 0 0 DT ,IBC US/F 60 52 32 0 0 GR BHC GAPI 60 31 32 0 0 NPHI FDN PU 42 ~ 2 0 0 RHO3~ F)N G/C3 42 35 1 0 0 DRBO .[DN 'G~C3 42 44 0 0 0 CibI FDN IN 42 28 3 0 0 GR FDN '~API 42 31 32 0 0 FCNL FDN 42 34 93 0 0 NCNb FDN 42 3~ t~ 2 0 0 NRAT FDN 42 42 1 0 0 1 6O ,lIN 0 SIZE 4 4 4 4 4 4 4 4 ¢ 4 4 4 4 4 PROCESS LEVEL 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SAMPLE 1 1 1 1 1 1 I 1 1 1 1 PEPR CODE 6~ 68 68 68 ** DATA ** bVP DEPT SP NPH! DEPT SP NPHI GR DEPT NPHI OR DE:PT SP NPH! GR DEPT GR DEPT SP NPHI GR DEPT NPH! GR DEPT NPH! GR DEPT SP NPH! GR. DEPT NPH! GR DEPT SP NPH! GR 009.H03 VERIFICA.T ION 11562,000 -999,250 -999,3510 25O SFLU RHOB FCNL 11560.0(0 -90 24.391 SELU GR RHOB 11.400.0 0 87,8~3 24.219 23.984 SFLU GR RHOB FCNL 1~300 0(0 114:688 ~4.3e5 26.891 SFLU GR RHOB FCNL 11.200,000 -113,938 29,346 51.656 SFLU GR RHOB FCNL 111C0.0(0 =111.750 24.8{'5 36.125 SFLU GR RHGB :FCNb 40,820 102.~63 SFLU GR RHOB FCNL 10900.000 -25.516 41.748 101.125 SFLD GR RHOB FCNL 1086 0.0( 0 -24.578 :5~.5(3 4 , 300 SFLU GR RHOB FCNL 10700,000 .~25.312 99.250 '999.250 SFLU GR RHOB FCNL 106¢0.0(0 -23 125 -)99. 250 SFLU RHOB FCNL LISTINg3 -999 -999 -999 -999 3 24 2 987 9 23 2 1336 '30 26 2 1462 19 985 36 2 1248 1.5 102 2 554 I 101 2 487 250 i250 25O 253 .623 .39~L .234 .500 438 984 3~ 1 000 :391 891 .305 ,000 .922 ,656 -336 .000 .781 ~125 312 .0.00 563 063 684 000 .570 ,125 ,422 .500 2 108; 2 106: -999. -999. . 120 {, -999' -999' 158 438 229 000 168 000 250 250 8O8 125 250 259 IbM DT DRHO NCNb ILM DT DRHO NCNL iILP~ NCNb ILM DT DRHO NCNb ~ILM NCNL IbM DT DRHO NCNb D~ DRHO NCNL ilL~ DT NCNb ILM DT DRHO NCNL DT NCNb .ILM DT DRHO NCNb -999.250 . 89,750 GR 999,250 ~ALI -999.250 'RA~ . 935 ILD 8 ,563 GR 0.031 CALI 3226,000 NRAT 8,984 ilLD 89,37.5 0,055 {CALI 3'410,000 NRA~ 25,828 ILD 90.563 GR 0.011 CALI 3.718,000 NRAT 22 906 IiLD 88,188 GA; 0,039 K, ALI 304B,000 NRA~ 16.609 ILD 92,563 GR 0 011 CALI 3288:000 NRAT 8,688 (ILD 91,188 GR 0,001 CALl 2150,000 NRAT 1 230 [ILD 116:563 0,038 ~C. ALI 1942,000 NRAI 1.701 ILD 58.188 GR 14~0.581 CALl 6,000 NRAT 1.870 (ILD 57,188 GR, '9!9.250 iCALI '999.250 NRAT 1 446 ILD -999~250 GR -999,250 CALl -999,250 NRA~ PIGE' -999.250 . 19,047 :999,250 999,250 1.782 281 2.955 10 273 22:688 8,5t6 2.357 37.!25 20,734 8.547 2~369 22,6~9 32,656 8.625 2.404 8.930 108.312 9.445 3.430 9~.168 ,625 11.070 3,.594 1.574 52.656 9.086 3.998 1.860 47.688 -999.250 =999.250 ~,396 "999.250 -999.250 -999.250 LVP O0~,H03 VER:flCATION LISTING DEP~ 10500.000 SF. LU SP -27.344 GR NPH! -999.~50 RHOB OR -999.250 f'CNL DEPOt 10400.000 SFLU SP e30,312 GR NPHI -)99.250 RHOB OR -999.250 FCNL DEPT 10300'300 SFLU SP NPHI -~99,250 RHOB GR '999.250 FCN~ DEPT 10203,300 SFLU SP ~35 i 4e9 GR NPH! -)99,250 RHOB GR -999.250 FCNL DEPT 10103.300 SFLU NPHI -199.250 RHOB GR -999.250 FCNL DEPT 10303.}00 SFLU SP e35,68:8 GR NPHI -)99.250 RHOB GR -999.250 ;FCNL DEPT 9)00,000 SFbU SP -28.375 GR NPHI -999.250 RHOB OR -999.250 FCNL DEPT 9gO0.O00 SFLU SP -21.125 OR NPH[. -999.250 RHOB GR -999.250 FCNL DEPT 9700.000 SFLU SP -30.906 GR NPH! -999.250 RHOB GR -999.250 ~CNL DEPT 9600.000 $FLU SP -29.078 GR NPHi. -999.250 RHOB GR -999.250 FCNL DEPT 9500.000 SFLU SP -33.344 GR NPHI -999.250 RHOB GR -999.250 ~CNL 1.652 102 ~38 -999; 50 -999.250 1.630 0 75O 999 25.0 1.681 X(5,875 - g99.253 -999,250 ILM 4.417 ILD DT -99 . 250 GR DRHO '999. 250 CALl NCNL -999. 250 NR~:T .427 ILD ILM -99~.250 GR DT DRBO '999.2~0 C:AL'I NCNL -999.2~0 NR~T 1,906 181 750 DT 999.2~0 NCNL 3 469 ILM 2(9.375 DT -~9~.253 DRHO -999.250 NCN.L 3 965 ILM $641875 DT -999 150 DBHO -999 250 NCNL I08,000 '999,250 DRHO -999.250 NCNL 1.869 ILM 138.500 -999.250 DRH3) -999.250 NCNL 2.~75 166.000 :999.250 DRHO 999.250 NCNL 1.636 154.000 iET -999.250 DRH3i -999.250 NCNL 1.289 1,56.625 :ET -999.250 DRHO -999.250 NCNL 1..816 ILD -999.250 GR -999,250 CALl -999.2~'0 NR/.T 2,832 ILD -999.250 GR -999.250 CALl -999.250 NR~T 3312 ILD 225o -999, ~50 CALl -999.250 NRAT -999.250 GR -999,250 CALl '999.250 NRAT 1,652 ILD -9~9,250 '~R -999.250 CALl -999.250 NRAT 2.611 1LD -959.250 'iR -99).250 C~LI -999.250 NRAT 1,631 .~ILD -9~9.250 R -999.250 CALl -999.250 NRA~ 1,346 -9c. 9.250 -)9~,250 -999.250 ILD 'ER CALl NRAI PAGE . 1,364 999.250 999.250 . .1,386 ,999,250 '999,250 -9~:9.250 1.455 -999,250 -999.35:0 -9~9.250 1.800 -999.250 '999,t50 -9!9,.50 . 2,887 999.250 959,250 . 3[ 24 .999 50 999 50 -999 250 2.357 -9c. 9.250 -999,250 -999.250 t.565 -999.250 -999.250 '999.250 2,578 -999,250 -999.250 -999,250 1.547 -999,250 '999.250 '999.250 1.350 '999,250 '999,250 -999.250 LVP 009,H03 VEREflCA~IGN LISTINC,~ DEPT 9400.000 SFLU SP ~ ~1.39! GR NPHI '~ 9,350 RHGB GR -999,250 FCNL 2 736 ILM 163,625 DT -999,250 DR. HO -999,25) NCNL DEPT 93C0,0(0 SFLU '~$P 35,594 GR. ' NPHI -~99.250 RHGB GR -'399,250 ,FCNL 2 635 123.063 DT -999,250 DRHO -999,250 NCNL DEPT 92(0,000 SFLO 'rSP ' 37.563 GR NPHI -999'250 RHOB ' GR -999,250 .FCNL 2 979 ILM 99:759 DT -999,250 -999,~50 NCNL DEPT 91C0.0(0 SELO SP -33,906 GR NPH! -999,350 RHOB GR -999,250 FCNL 3,, 184 801'938 DT :999 250 999:25~)' NCNL DEPT 90(~ 0 , 0(0 ,SFLU SP -31.53.1 GR N PHi .-9991350 RHOB GR '999~2.50 .FCNL 2 ~06 I. LN 97!. 50 DT · 999 250 DRHO -999,253 NCNL DEPT 89¢0.0(0 $FLO SP o31 766 GR NPHI -999:350 RHOB GR -999,250 FCNL 2,219 ILM 85,188 DT -999,250 DRHO '999,253 NCNL DEPT 88C0,0L0 SFLU SP -29,39! GR NPH! -999.350 RHOB GR -~99,250 FCNL 2,512 8~688 DT -999.250 DRHO -999,25) NCNL DEPT 8790.0( 0 SFLU BP -31,672 GR NPHI -999.3.~0 RHOB GR -~99.250 FCNL 2,445 83,063 DT -999,250 DRHO -999.25~ NCNL DEPT 86C0.0(0 SFLO SP 31,953 GR NPH! -~99,3~0 RHOB GR -99~,250 FCNL 2.662 ILM 85,750 DT .-999,250 DBHO -)99.25) NCNL DEPT 85(0. O( 0 SFLU $P -36,625 GR NPH! o999.25 0 RH~B GR -~99,250 FCNL 3,754 76,250 DT -999.250 DRHO -999.25) NCNL DEPT 84(0. O( 0 SFLU SP -45,844 GR ND~I -999,350 RHOO GR -~99,250 FCNL 5.129 75,312 DT -999.250 DRHO -999,25~ NCNL 2.312 '999,~50 -999.2 91,962 '9 ~,250 .2so -999,,250 g561 -99 : ~50 -9~ 250 2 768 250 '999 250 .. 2,098 999,250 -999,250 -999,~50 2 50 :999:22.62 999 250 -999:250 582 -999 250 -999;250 2 445 999 250 -999.250 2.744 999,250 999,250 999,250 3 947 '999,250 '999,250 '999,~50 .691 -99 ,250 -999,250 -999,250 GR ILD GR~ CALl NRA~ GR K AI_I NRA~' ILD GR CALl NRAI ;LD R fALI ILD GR CALI NRA~ ILD GR CALl NRA~ ILD GR CALl NRA~ ILD GR CNALI ILD GR CALI NRA~ ILD GR CALl NRA~ P 2.338 -999,250 :999.250 999~250 ~.912 -999.250 -999.250 -999,250 2,604 -999,250 -1999,250 -999'250 2.717 -999,250 999,250 -999, 0 2.240 -999 250 -999:250 -999.250 2.670 -999,250 -999,250 -999,250 2.432 -999.250 -999.250 -999.250 2.746 -999,250 -999,250 -999,250 3.922 :999,250 999,~50 -999.250 4.563 -999,250 -999.250 -999.250 _) LVP 009,H03 VfR~flCATION LI$~ING DEPT 8300.000 SFLU Si> -109 438 GR NP. HI '999:250 RHO8 GR -999'250 ,FCNL DEPT 8200,000 SFLU SP -52,438 GR NPHI -999.250 RHOB GR -999.250 .FCNL DEPT 8100.000 SFLU SP -31,031 GR NPHI -999,250 RHOB' OR -999,250 FCNL DEPT 8000,000 SFLU SP -18,219 GR NPH! -999,250 RBOB GR -999,250 FCNL DEPT 7-:)00.000 SFLU SP -21 125 GR NPH[, -999~250 R,OB OR -999.250 FCNL DEPT 7~00 000 SFLU SP - 24:250 GR NPHI -999,250 RHOB OR -999.250 FCNL DEPT 77'00.000 SF. LU SP -98 188 GR NPH! -999."250 RH0S GR -999,250 FCNL DEPT 7600.000 SF~U SP -106.500 GR NPH[. -999.250 RHOB GR -999.250 FCNL DEPT 7500.000 SFLU SP -94.375 GR NPH! -999.250 RHOB GR -999,250 FCNL DEPT 7400.000 SFLU SP -105.688 GR NPH! -999,250 RHOB GR -999.250 FCNL DEPT 7300.000 SFLU SP - 86,563 GR NPH[~ '999, 250 EHOB GE -999.250 FCNL 1.~75 128 875 -999!25O -999 25O 3 1O1!5O0 -999 250 -999.250 3 986 87:625 -999,250 -999,250 3 355 -'999 250 -999:250 4.816 84 188 '999!250 '999 250 DRHO NCNL 1LM :ET DEHO NCNb ~T DRHO NCNb IbM ~DT DRHO NCNb 1LM DRN NCNb 3 477 IL~ . 91,875 ~£T '999,250 DERO -999.250 NCNL 9,344 57 312 -999.250 6,379 55,750 -999,250 -999.250 6.793 64,438 999.250 6.551 54 906 -.999:250 999,250 4 273 82,563 -999,250 -999,250 ILM lit DRHO NCNb 'ET NCNb IbM 'ET DRHO NCNb ILM DRHO NCNb IbM DRH3} NCNb 2,613 ~9 · 250 999,250 · 2,746 :9S9.250 '~9 ~, 250 -999.250 4!. 008 -9c. 9,250 -999,250 -9~9,250 3,293 -9S9,250 -99:{.250 -999,250 . ~%910 .gcJ 9.250 999,,250 -999.250 · 3.412 -9S9o250 6 688 -9~9~250 -~9~,250 -999.250 i:, 461 i9S9.250 .999.250 999.250 4,672 -9S9.250 -999.250 -9S9.250 3,896 -,9~'9,250 ~9.3. 250 -999.250 5 523 -9c. 9i250 -999 150 -999, 50 ILD C ~,LI NEAT ILD C ILl ILD C ill NEAT ILD C ~LI NRAT ILD CALI NRAT ILD 'iR C ~LI NRAT ILD C.lbI NRAT ILD CALl NRAT ILD '6R C ~LI NRAT ILD C iLl NRAT ILD CALl NRAT I>AGE 2.701 -999.250 -999,~50 -999. 50 2.801 -999 250 -999.250 -999,250 '999.250 -999.250 3. ~53 999.'250 -999.250 %% 965 -999,250 -999,250 -999.250 3.602 -999.250 -~99,250 -999,250 5.675 -999.250 -999.250 -999.250 3,842 -999.250 -999.250 -999,250 3.'918 -999.250 -999.250 -999.250 3,137 -999.250 -999.250 -999.250 5~.t53 -999.250 '999,150 '999. 50 LVP SP NPHI GR DEPT SP NPH! DEPT SP NPH! GR DEPT SP NPHI GR DEPT SP NPHI DEPT SP NPHI ~GR O09,HO~ V F,R [FICATION 7200.000 =~SFLU ;990 000 GR - 9:250 -999,250 FCNL lf£OiO00 SFLU 101. 813 GR -999 250 RBOB -999.250 ,FCNL ?00 0¢0 SFLU =999.250 FCN~ 69(0,0(0 SELU -72.438 GR -999.350 RHGB -999.250 FCN/ 68C0.0(0 SFLU .,,66,5~0 GE 999, ~ 0 RHGB -'~99. ~0 FCNL 67(,0. O( 0 SFL'U "98 500 GR -999;150 RHOB -999,250 FCNL DEPT 96C0 0(0 SFLU SP -112:563 GR NPH! -999,2~0 RHGB GR -)99,250 FCN. L DEPT SP NPHI DEPT SP NPH! GR DEPT SP NPHI GR OEPT SP NPBI GR 65¢ O. O( 0 SFLU -101,125 GR -999 350 RHOB -)99;250 FCNL 6400.0(0 SFLU -111. 625 GR -999,250 RHOB -;)99.250 FCN. L 63(0,0(0 SFLU -110,688 GR -999,350 RHOB -)9~.250 FCNL 62(,- 0. O( 0 SFLU -76.3~5 GR -999.35~0 RHOB -:~99.250 FCN, L LIST IN g~ 3.191 ILN 73 875 DT .~999!250 DRBO 999 25,3 NCNL 5 941 ILN · 48i844 DT -999 250 t£REO -999.250 NCNL 4 070 ILN · -999,250 it)RI-lO -999.25 3 NCNL 3 879 IL~ 67:250 DT · -999,250 DRHO -~99.253 NCNL 7]i:512 188 DT · ~999'250 DRHO 999. 253 NCNL 4 238 68.938 DT -999.250 DRHO -999.253 NCNL 4 672 ILM 48:094 DT -999 250 DRHO -999:253 NCNL 4.715 46.875 DT .-999,250 DRHO -999.25). NCNL 4.430 ILN 38.531 DT -999.250 DRHO -999.259 NCNL 5.059 ILM 401.438 DT -999.250 DRHO -999.253 NCNL 3,500 ..ILN 54,688 DT -999.250 DRHO -999.25) NCNL , 383 ;99 . 250 .999,250 999. 250 3.588 :999 250 9 250 -999 250 393 -999,250 -999. 250 3 854 -999:250 -999,250 -999,250 3.758 999. -999. 50 3 088 '.999i250 99 250 99,250 -999.250 =999.250 3.045 -999 250 -999i250 -999 ~50 2.189 -999.250 -999.250 -999.250 2.465 -.~99.250 99.250 -999,250 3.180 -99 ,250 '999.250 '999.250 ILD GR CALI NRA~ ILD GR ~C AL I NRA~[ ILD GR CALl NRA~ ILD GR CALl NRA2' ILD GE CALl NRA~ ILD GR CALI NRA~ ~LD R CALI N. RA~ ILD GR CALI NRAT ILD GR CALl NRA2 ILD GR CALl NRA2 ILD GR ALI RA,'I PAGE 3.648 -999.250 -999.250 -999.250 2.939 5O '999.~56 -999. -99~.250 250 -999.250 -999,250 3,709 -999,250 '999,250 '999,~50 3,863 -999,250 -999,250 -999,250 . 2,580 .-999,250 -.999,250 999,250 I~ 730 -999.250 -999,250 2.666 -999.250 -999.250 -999.250 1.718 -999.250 -999.250 -999,250 ~.957 -999.250 -999.250 -999.250 2.695 -999.250 -999.250 -999.~50 009.H03 VERIFICATION LISTING DEPT 6100.000 SFLU sP -67:o63 oR NP.I, -~99 ~5o R~oe GR - . 50 FCNL D£PT 6000.000 SFLU SP ' .9e, 5 188 eR 99;250 RHOB. NPHI GR -999.250 FCN{~ DEPT 5~100 000 8FLU sp -58'.3'/5 NPH! -999.250 RHOB Ot~ -999.250 DEPT 5800 000 SFLU SP '45:28.! GR NPHI '999.250 RHOB GR '999,250 'FCNL DEPT 5700.000 SFLU SP -50,594 OR NPH! -999.250 RHOB GR -999.250 .FCNL DEPT 5600.000 SFLU SP -65;563 GR NPH[, -999.250 EHOB GR -999.250 FCNL DEPT 5500.000 SFLU SP -61.344 GR NPHI -999,250 RHOB OR -999.250 FCNL DEPT 5400.000 SFLU SP '76 312 GR NPH! -999:250 RHOB OR -999,250 :FCNL DEPT 5300.000 SFLU SP 91 RHOB GR -999.250 :FCNL DEPT 5200.000 SFLU SP -52.938 GR NPH[. -999.250 RHOB GR -999.250 FCNL DEPT 5100.000 SFLU SP -67.312 Gl:{ NPHI -999.250 RHOB GR -999.250 .FCNL ) 4,297 58,594 '999.~50 -999. 50 5.270 68.375 :999,250 999.250 2,603 54,156 '999.250 '999.250 2,88i 79,750 -999 250 -999:250 3.~06 81,250 -999,250 -999.250 4 .-99 250 999.250 3 445 551125 -999 250 -999 25O PAGE 9 ILM 4 840 ILD 5.488 ~C:T :9~9:250~ '~;R -999.250 DRHO 99~ 250 C~LI -999,250 NCNL -999.250 NRAT '999"250 IbM 2 537 ILD 2.2~25~ 'ET -9$9:250 '~R -999..50 DRHO -99),250 C~LI -999.250 NCNb -999,250 NRAT -999.250 ILN . 3,.068 ILD .3.338 :£T 9f9.250 'C,.R -999.250 DRHO -999.250 CA, bi -999 150 NCNL -9~9.250 N. RAT -999; 50 I. LM 3.080 .ILD :CT -9~'9,250 DRHO -.99~.250" C~LI NCNb -999.250 .NRAT IbM 3,1~I :iLT ~9~9.250 R DRH3} 999.250 CALl NCNb 999,250 NRAT IbM 2.934 ,~LD '~T -9S~,250 R DRHO -99 ,250 CILI NCNb -999.250 NRAT 3.503 I. LM 81,750 .:CT -999.250 DRHO -999.250 NCNb 5.902. lbM 36.063 :~99,250 DRHO 99. 250 NCNL 3.799 65 312 -999:250 DRH-3i -999.250 NCNb . 2,840 ILD 9S9.250 '~R -{)99.250 C~.LI -999.250 NRA~ 5,160 ILD -9c~9.250 'iR 99~ 250 C ILI :9, 9:25o 3-771 ILD -9S9!250 -999 250 CALl -999 250 NRAT 3,695 -9~9,250 -99~),250 -999.250 } ILD C~LI NRAT 4.016 ILN 64.250 :CT '999.250 DRHO '999.250 NCNb -99~ 383 250 -999 ~ . 3,~52 999.250 -999.250 -999.250 2,648 -999.250. -999.250 -999.250 2.578~ -999.250 -999.250 -999.250 ~"820 -999.250 -999.~50 -999. 50 3-.~61 -999.250 -999.250 -999.250 3 -999,250 bVP DEPT SP NPHI GR DEPT SP NPHI GR DEPT SP NPH! GR DEPT SP NPH! GR DEPT PHI GR DEPT SP NPHI GR DEPT SP NPHI DEPT SP NPH! DEPT SP NPHI GR DEPT SP NPHI GR DEPT SP NPHI 009. H03 VERIFICATION 5000.000 SFLU -63 813 GR -999."m~0 RHOB 363 GR -999.250 RHGB -999.250 FCNL -999 -~99 0(0 SFLU 394 GR ~0 RHOB .250 FCNL !7(~00C-O 99.350 -999.250 SF. LU FCNL 46C0. O( 0 999. 350 -999,250 GR FCNrL =70 -999 -799 .0(0 .250 SFLU GR RHOB FCNL 44C0 -71 -999 .0(.,0 ,750 .3~'0 ,250 GR FCNL 43C0 -63 -999 .OCO .156 .250 .250 SFLU GR RHGB FCNL 4200 '74 =999 -~99 ,0(0 .438 .250 .250 SFLU GR RHOB FCNL 4ICO -69 =999 -999 .000 .063 .250 .250 SFLU GB RHOB FCNL 40(0 -95 -999 -~99 .0(0 .250 ~50 :250 SFLU GR FCNL LIST IN 4 -999 -999 ,999, -999. 3 72 ~-999 -999 ~17 999 3 26 ,,999 -999 5 ,~-999 -999 6 58 -999 -999 5 64 --999 -999 5 58 -999 -999 855 031 250 253 387 531 250 25 3 777 125 25O 253 :406 312 .250 .660 ~406 25O .253 523 . .312 ,250 .253 .332 .875 ,250 °253 ,086 ,938 .250 .253' 957 ,531 ,250 25'3 6 69. -999, -999. 1 44. -999, -999. 980 753 250 250 863 938 250 253 I:LM DT DRMO NCNL ILM DT DRBO NCNL ILl~ DT DRHO NCNL ILM DT DRHO NCNL ILM DT DRHO NCNL ILP DT DRHO NCNL DT DRHO NCNL ILM DT DRHO NCNL ILM DT DRHO NCNL ILM DT NCNL DT DBHO NCNL 4. 066 ILD .2so -99~. 250 CALI -999. 250 NRAT 3 213 ILD -9'999!250 GR -99 250 CALX -999,250 NRA~ :99 ,250 999,250 CALI -999,250 NRA~ .._99!{.352 ILD ,250 GR ,250 CALl -999,250 NRA~ . 2,182 ILD 999,250 GR '999,250 CALl '999.250 NRA1 ILD ,250 CALl -999. 250 NRAT , 988 ILD -99 ,250 GR -999,250 CALl -999,250 NRAT 5,406 ILD -999,250 GR -999.250 CALl -999.250 NRAT 5 617 ILD . -999,250 GR '999,250 CALl -999.250 NRA~ 7,078 ILD 250 '999. 250 NRA~ 5.059 ILD -999,250 GR -999,~50 CALl -999. 50 NRA~ P~GE 10 '4,I09 999. 250 -999.250 2.809 -999.250 -999 250 -999 25O . ,2 85O .999~250 999.250 -999.250 11.85 999,2~v- -999.~ :50 -999, 150 1,~..972 ,250 99.250 4,844 '999,250 '999,250 '999.250 so -999,~50 -999. 50 5.316 -999.250 -999.250 -999,250 5.559 -999.250 -999.250 -999.250 7.797 -999,~50 -999, 50 -993.250 4,770 -999.250 -999.250 -999,250 _) LVP 'C'09.H03 VERIFICATION LISTING PAGE 11 DEPT 3900.000 SFLU 5.766 ILM 5.250 .ILD 5.801 SP -65 31':2 GR 55 094 ~[:.T -9~'9.250 CR .999.250 DZPT o -9 ,9.250 'ca :999.25o SP -7 63 GR 71 500 NPHI 99 250 RHOB. -999 250 DRHO --~9~.250 CALl. -999.250 GR 999.250 ~FCNL -999 50 NCNL -999.250 NRAT 999.250 063 GR 59 44 :ET =9~9 250 R 999,250 250 RHOB -999 250 DRRO -~9'~'250 C~hl -999.250 .250 :FCNL -999.250 NCNb -999.250 NRAT -999.250 DEPT 3100 SP .-83 NPHI. 999 -999 3600.000 -Si,000 -999,250 -999,250 SFLU 6. 359 ILM OR 61.875 ~.ET -959 250 'C~R -999 250 FCNL -999.250 NCNb 999. NRAT -999 ~50 DEPT SP GR 3500.000 -64 688 -999 0 563 IbM 5.461 lbD 6.387 IET 9,250 R -999.250 GR 7, 3 -9~ 'C RHOB -.999,250 DRHO -99{,250 CtLI, 999,25~ FCNL 999.250 NCNb -999.250 NRAT -999.25 DEPT SP NPH! GR 3400.000 -68 18.8 -999. 50 DEPT SP NPHI GR 3~00,000 93.688 -999.250 -999.250 FCNL '999.250 NCNL -999.250 NRAT '999.250 DEPT SP NPHI GR 3200.000 -71,563 -999.250 -999.250 SFLU 4 42~ IbM 3,838 .6ILD 3.734 GR .75:875 :£.T -959.250 R -999.250 RHOB -999 250 DRH3'} -999.250 CALl -999.250 FCNL -999:250 NCNL -999.250 NRAT -999.250 DEPT SP NPH[. GR 32.00,000 9.250 '999'250 SFLU 3.184 :~iLM 952.850 ILD 3.223 GR 75.125 T - 9.250 'f.R -999.250 RHO, 999.250 DRHO -,9,.250 C~L! -999.22558 FCNL :999.250 ,CN~ -999.250 NR~, -999. DEPT SP NPH! GR !00.000 · 77.375 999.250 -999.250 SFLU 3.635 ILM ~.887 ILD 2.7~7: GR 65.813 DT -999,250 GR °959.250 RHOB -999.250 DRHO -~9~,250 CILI- ~999.250 .FCNL -999.250 NCNb -999.250 NRAT 999,250 DEPT SP NPHI GR 2 )00 000 -84'.875 -999.250 -999.250 SFLU 3.781' ILM ~.803 ILD 2.505 GR 64.0t3 DT -999.250 GR '959.250 RHOB '999.250 DRRO '~9),250 CALl '999.250 :[;CNL '999.250 NCNb -999.250 NRA~ '999.250 DEPT SP NPHI GR LVP 009.H03 VERIFICATION LISTIN~ DEPT 2800,000 SFLU ~.465 SP ~-97,750 GR 48 938 NPHI 999,350 RHOB -999:250 GR ~9~.250 FCNL ~'999.253 IL~ DT DRHO NCNL oco sr u Si) -95,125 GR 3.1: NPH! '999. 250 RHOB -.999 GR -~99.250 FC.NL 999 023 03! 250 25 ) ILM DT DRHO _ NCNL DEPT ~600.0C0 SFL'U 71: SP -53.688 GR NPHI 999,350 =RHOB --999, GR -399,250 FCNL -999, 426 312 250 253 DT DRHO NCNL DEPT 2500.0C0 SFLU 2000. SP -72.363 GR . 28, NPH! -999,3~0 R.HO8 . .999, GR -)99,250 .FCN. L -999, 000 422 250 253 DT DRHO NCNL DEPT 2478.5~-0 SFLU 2'0(}.0. 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