Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
183-087
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, August 20, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Y-05 KUPARUK RIV UNIT 1Y-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/20/2025 1Y-05 50-029-20966-00-00 183-087-0 W SPT 5804 1830870 1500 2650 2650 2650 2650 204 204 204 204 4YRTST P Austin McLeod 7/12/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1Y-05 Inspection Date: Tubing OA Packer Depth 980 1815 1760 1750IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250713140046 BBL Pumped:0.5 BBL Returned:0.5 Wednesday, August 20, 2025 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor V f Zt97� FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. I Y-05 KUPARUK RIV UNIT I Y-05 Src: Inspector Reviewed B� P.I. Supry Vt'__ Comm Well Name KUPARUK RIV UNIT 1Y-05 API Well Number 50-029-20966-00-00 Inspector Name: Matt Herrera Permit Number: 183-087-0 Inspection Date: 7/5/2021 Insp Num: mitMFH210706135316 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - — Well IY-05 'Type jp� W TVD 5853 2 � Tubing 2650 2650 - 2650 2650 _. - -- PTD Is3oa�o Type Test sPT Test st -- yp - ' - psi -- 1500 — IA 1430 -- - 2000 - 1970 - - 1960 - BBL Pumped: 1 0.4 - BBL Returned: 0.4 OA 0 0 0 0 Interval 4YRTST F'/F - Notes: MIT -IA performed to 2000 PSI Per Operator Wednesday, July 14, 2021 Page I of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg T DATE: Tuesday,July 11,2017 P.I.Supervisor 71/e1(7SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1Y-05 FROM: Adam Earl KUPARUK RIV UNIT 1Y-05 Petroleum Inspector Src: Inspector Reviewed By:� . i P.I.Supry c — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-05 API Well Number 50-029-20966-00-00 Inspector Name: Adam Earl Permit Number: 183-087-0 Inspection Date: 7/7/2017 Insp Num: mitAGE170708061257 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y-05 Type Inj W' TVD 5853 Tubing 2550 2550 2560 2565 - PTD 1830870 . Type Test SPT Test psi 1500 IA 935 1 2010 - 1970 - 1960 BBL Pumped: 1.3 - BBL Returned: 13 OA--1 13 _--L 13 13 14 Interval 4YRTST P/F P I Notes: SUNNED SEP 252017. Tuesday,July 11,2017 Page 1 of 1 • MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim DATE: Wednesday,December 28,2016 Regg P.I.Supervisor -erct 1 zIt(l(0 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IY-05 FROM: Bob Noble KUPARUK RIV UNIT IY-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry-1 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-05 API Well Number 50-029-20966-00-00 Inspector Name: Bob Noble Permit Number: 183-087-0 Inspection Date: 12/27/2016 Insp Num: mitRCN161227142358 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y-05 - Type Inj W'TVD � 5853 Tubing 2775 . 2775 2775- 2775. PTD I 1830870 Type Test SPT Test psi 1500 , IA 980 2000 ' 1960 ` 196)- Interval INITAL P/F j P V I OA 73 74 _ 73 - 74 '( Notes: Post rig work over. V SCANNED APP j 520)7 Wednesday,December 28,2016 Page 1 of 1 STATE OF ALASKA Alt OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Plug Perforations r Fracture Stimulate nPull Tubing F Operations Shutdown Performed: Suspend Perforate[ Other Stimulate E Alter Casing 17 Change Approved Program Plug for Redrill E Perforate New Pool .... Repair Well F Re-enter Susp Well " Other: Scab Liner 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory 1- 183-087 3.Address: 6.API Number: Stratigraphic I— Service F P. O. Box 100360,Anchorage,Alaska 99510 50-029-20966-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25646 KRU 1Y-05 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7266 feet Plugs(measured) None true vertical 6688 feet Junk(measured) 6785 Effective Depth measured 7236 feet Packer(measured) 5502 true vertical 6664 feet (true vertical) 5183 Casing Length Size MD TVD Burst Collapse CONDUCTOR 42 16 73 73 SURFACE 2174 9.625 2205 2205 PRODUCTION 1693 7 1721 1721 PRODUCTION 5520 7 7236 6664 Perforation depth: Measured depth: 6381-6472,6603-6607, 6618-6638,6657-6670 RECEIVED True Vertical Depth: 5968-6047,6157-6161, 6170-6187,6203-6213 DEC 20 2016 Tubing(size,grade,MD,and TVD) 3.5, L-80/J-55,6551,6114 " ° ) C C Packers&SSSV(type,MD,and TVD) PACKER-HD LINER TOP PACKER @ 5502 MD and 5183 TVD PACKER-HD LINER TOP PACKER©6195 MD and 5804 TVD PACKER-FB-1 PACKER @ 6522 MD and 6090 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): None SCANNED a A E ',)01- Treatment 0 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation Shut-in - - - - Subsequent to operation Shut-in - - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory 1— Development E Service F Stratigraphic 1- Copies of Logs and Surveys Run E 16.Well Status after work: Oil fl Gas I WDSPL Printed and Electronic Fracture Stimulation Data " GSTOR r WINJ I- WAG 17 GINJ r SUSP SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-487 Contact Andrew Beat @ 265-6341 Email Andrew.T.Beateconocobhillips.com Printed Name Andrew Beat Title Sr. Wells Engineer Signature A Phone:265-6341 Date a/Z(4 16 Form 10-404 Revised 5/2015 V TL 3/z0//7Submit Original Only RBDIWIS \/../\/../DEC, 2 2 2010 l/1,9,' • 0 ,rwOperations Summary (with Timelog Depths) 1Y-05 ccsnocoPh flips r4"rxr.A.� Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/29/2016 10/29/2016 2.00 MIRU MOVE RURD P PJSM,Blow down steam lines, 14:00 16:00 disconnect interconnect in preparation for rig move. 10/29/2016 10/29/2016 2.50 MIRU MOVE MOB P PJSM-Move pipeshed,complexes, 16:00 18:30 RW,and stage on pad.Load camp and show and stage on pad. 10/29/2016 10/29/2016 1.00 MIRU MOVE MOB P Move sub off well 1E-21 18:30 19:30 10/29/2016 10/29/2016 3.00 MIRU MOVE MOB P PJSM-Move sub,complexes,pipe 19:30 22:30 sheds,shop,and camp from 1E-pad to 1Y-pad. 10/29/2016 10/30/2016 1.50 MIRU MOVE MOB P PJSM-Spot sub over well 1Y-05 22:30 00:00 10/30/2016 10/30/2016 8.30 MIRU MOVE MOB P Move rig from 1E-1Y and MIRU. Rig 00:00 08:18 accepted at 0830 hrs. Load pits with 580 BBLS SW. RU kill tank PT same. Change out leaking chicksan. Re-PT good. Prep for Well kill. 10/30/2016 10/30/2016 3.70 MIRU WELCTL RURD P 08:18 12:00 10/30/2016 10/30/2016 2.50 MIRU WELCTL MPSP P PJSM-RU lubricator,test to 1500 psi. 12:00 14:30 Pull BPV.RD lubricator. 10/30/2016 10/30/2016 1.50 MIRU WELCTL KLWL P RU Circ.lines.T/IA=250/500 psi. 14:30 16:00 Attempted to establish circulation to kill well.Stage up to 1000 psi.Unable to establish circulation through the GLM#4 open pocket at 6,186'or the tbg chem cut at 6,210'only able to pump 3 bbls and IA pressure increased to 1000 psi.Shut in well and bleed off. 10/30/2016 10/30/2016 1.00 MIRU WELCTL WAIT T Discuss plan forward with town 16:00 17:00 engineer. Decision made to call for Slickline to pull GLV#5 @ 5,687' above possible casing leak @—6,060' and attempt to establish circulation. SL notified at 17:30,crew rigged up on another well.Wait on SL while line, pull,tubing spool and tree into cellar. 10/30/2016 10/30/2016 2.50 MIRU WELCTL WAIT T PJSM-change out bottom rams to 3- 17:00 19:30 1/2"x 6".Adjust draworks break, calibrate, MP stks,TD TQ, PVT Vol. Block height as per Quadco rep. 10/30/2016 10/30/2016 1.00 MIRU WELCTL SLKL T SL crew arrives to location @ 19:20. 19:30 20:30 Begin staging equipment. 10/30/2016 10/30/2016 1.00 MIRU WELCTL SLKL T PJSM with Slickline.Begin loading the 20:30 21:30 20'riser in the pipe shed and stuffing box. 10/30/2016 10/31/2016 2.50 MIRU WELCTL SLKL T Begin SL RU. Install 20'riser on tree. 21:30 00:00 PU rest of SL tools. LRS PT lubricator. PT all systems and RIH. Page 1/22 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) 0 4.i.,: , 1 Y-05 ConocoPhiillps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/31/2016 10/31/2016 4.00 MIRU WELCTL SLKL T Begin SL RU. Install 20'riser on tree. 00:00 04:00 PU rest of SL tools. LRS PT lubricator. PT all systems and RIH. Tag top of SSSV. Pressure up control line on Al injection valve watch open at 4,500 PSI control line pressure. Drift to top of first cut to ensure no obstructions.@ 6341'. Install SSSV saver sleeve to hold open flapper.Rig down SL and have LRS inject 40 BBLS into IA to prove injection rates prior to release. 10/31/2016 10/31/2016 1.00 MIRU WELCTL SLKL T Rig slick line down. Line LRS up to IA 04:00 05:00 and bullhead at 1BPM at 1,050 PSI bullheading into formation. Rig down LRS. PT rig surface equip to flowback tank post tank/choke/iron move downwind of rig. Prep to Bullhead. 10/31/2016 10/31/2016 7.00 MIRU WELCTL KLWL P Bullhead 180 BBLS 8.4 PPG 05:00 12:00 SWdown IA/110 BBLS 8.8 PPG SW down tubing for well kill.Bleed down to pits 20 BBLS total over an hour. SI IA=0 PSI.Tubing=10PSI. Line pumps up for surface to surface irculation. After circulation well on vac. Install BPV, Injection PT at 2 BPM 100 PSIG rolling test. RD circulation equipment ND tree install test plug Prep to install BOP. 10/31/2016 10/31/2016 8.50 MIRU WELCTL NUND P Pull production tree. NU BOPE.install 12:00 20:30 crossover flanges. CO rams to 3 1/2" X 6". PUII strre to center for effect. Subsidence evident with—15 deg lean. 10/31/2016 11/1/2016 3.50 MIRU WELCTL BOPE P Perform standard 250 low 3000 high. 20:30 00:00 BOP test chart same. 11/1/2016 11/1/2016 3.50 MIRU WHDBOP BOPE P Continue to perform BOPE test. 00:00 03:30 11/1/2016 11/1/2016 0.50 MIRU WHDBOP BOPE T Order out new 5.5"seal ring for test 03:30 04:00 joint from warehouse. 11/1/2016 11/1/2016 1.50 MIRU WHDBOP BOPE P Continue with BOP test after installing 04:00 05:30 new seal ring in 5 1/2"test joint. 11/1/2016 11/1/2016 0.75 MIRU WHDBOP RURD P RD testing equipment,BD choke, 05:30 06:15 manifold,chock line and kill line. 11/1/2016 11/1/2016 0.50 MIRU WHDBOP MPSP P Remove blanking plug and pull BPV 06:15 06:45 11/1/2016 11/1/2016 0.75 COMPZN RPCOMP RURD P Bring up SLB spooling unit,tools and 06:45 07:30 GBR casing equipment to the rig floor.RU spooling unit and casing equipment to pull tubing. 11/1/2016 11/1/2016 1.25 COMPZN RPCOMP PULL P PU landing jt,make up to hanger.BO 6,210.0 6,185.0 07:30 08:45 LDS on hanger and pull hanger.PU= 90K lbs.Release E-line from standby. 11/1/2016 11/1/2016 1.75 COMPZN RPCOMP CIRC P Cilculate Btms up(1.5 hole volume) 6,185.0 6,185.0 08:45 10:30 staging pumps up to 5 BPM,550 psi. Pump rate was reduced to 4 BPM due to losses,4 BPM,330 psi.Total strokes=3572. Page 2/22 Report Printed: 11/28/2016 0 0Operations Summary (with Timelog Depths) 1Y-05 Cor oce thitliips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB). 11/1/2016 11/1/2016 1.50 COMPZN RPCOMP OWFF P Finished circulating 1.5 hole volume. 6,185.0 6,185.0 10:30 12:00 Pull tbg hanger above rig floor,rig up control line to spooler.Wait on DHD to shoot fluid levels(fluid level needs to be static for 1 hr before shooting level). 11/1/2016 11/1/2016 8.30 COMPZN RPCOMP PULL P POOH with production tubing to first 0.0 0.0 12:00 20:18 cut at joint 197. Cut looks good 3 5/8" OD. 11/1/2016 11/1/2016 1.00 COMPZN RPCOMP RURD P Prep lay down GBR equip.Prep to 0.0 0.0 20:18 21:18 RIH with Baker GLock setplug. 11/1/2016 11/1/2016 1.70 COMPZN WELLPR PULD P RIH with Baker Glockset plug assy. 0.0 0.0 21:18 23:00 PU 9 drill collars on top followed by 169 singles of 4"DP. RIH. 11/1/2016 11/2/2016 1.00 COMPZN WELLPR PULD T Tag up at 284'. Pick up lay down 0.0 284.0 23:00 00:00 three singles DC,stand back two stands DC. UPI'Baker packer above rotary and inspect. Prep to attempt RIH with drill pipe and Baker assmy only. Crew CO. 11/2/2016 11/2/2016 5.50 PROD1 WELLPR TRIP P Trip in hole with 4"DP and Baker G 0.0 5,600.0 00:00 05:30 Lockset plug. 11/2/2016 11/2/2016 0.50 PROD1 WELLPR MPSP P Test Plug to 1000 psi/10 mins-good 5,600.0 5,600.0 05:30 06:00 test. 11/2/2016 11/2/2016 0.50 PROD1 WELLPR CIRC P Clrc B/U @ 9 bpm 950 psi. 5,600.0 5,600.0 06:00 06:30 11/2/2016 11/2/2016 0.50 PROD1 WELLPR OWFF P OWFF-no flow 5,600.0 5,600.0 06:30 07:00 11/2/2016 11/2/2016 1.50 PROD1 WELLPR TRIP P TOOH to 1500 standing back DP 5,600.0 1,500.0 07:00 08:30 11/2/2016 11/2/2016 0.50 PROD1 WELLPR PULD X Prepare to P/U storm packer-decided 1,500.0 1,500.0 08:30 09:00 to run back into 3500 ft with DP to hang extra weight to assist with Casing growth due to old style Hanger. 11/2/2016 11/2/2016 1.00 PROD1 WELLPR TRIP X TIH to 3500' 1,500.0 3,500.0 09:00 10:00 11/2/2016 11/2/2016 1.00 PROD1 WELLPR PACK X P/U storm packer&set COE @ 100ft. 3,500.0 100.0 10:00 11:00 Pressure test to 1000 psi/10 mins- good test. 11/2/2016 11/2/2016 8.75 PROD1 WELLPR NUND X ND BOPE-Grow casing.Back out 100.0 0.0 11:00 19:45 casing spool bolts with BOPE stack weight 55K,growth pushing up BOPE stack.PU 2 jts 8"DCs.MU test plug, RIH set down collar+10k block weight grow casing maxed out casing bolts. 11/2/2016 11/3/2016 4.25 PROD1 WELLPR NUND X Discuss options with town engineer. 0.0 0.0 19:45 00:00 Decision made to cut casing and perform subsidence style repair.Wait on MOC.Lay down DCs.Change BOP upper rams to 7". Re-install BOP test 7"along with body test. 11/3/2016 11/3/2016 3.75 COMPZN RPCOMP NUND X Lay down DCs.Change BOP upper 0.0 00:00 03:45 rams to 7". Re-install BOP test 7" along with body test. 11/3/2016 11/3/2016 4.30 PROD1 WELLPR NUND X NUND BOPE prep for test of 7"joint 00:00 04:18 and body test breaks. Prepare to RIH for storm packer retrieval. Page 3/22 Report Printed: 11/28/2016 • • 0 Operations Summary (with Timelog Depths) 1Y-05 ConocoPtsimps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/3/2016 11/3/2016 1.00 PROD1 WELLPR BHAH X Pick up BHA and RIH to retrieve storm 3,500.0 04:18 05:18 packer. 11/3/2016 11/3/2016 1.00 PROD1 WELLPR TRIP X TOOH to 1500ft 3,500.0 1,500.0 05:18 06:18 11/3/2016 11/3/2016 0.50 PROD1 WELLPR CIRC X Circulate 4 times B/U to ensure warm 1,500.0 1,500.0 06:18 06:48 SW to surface. 11/3/2016 11/3/2016 0.70 PROD1 WELLPR TRIP X TOOH standing back DP 1,500.0 0.0 06:48 07:30 11/3/2016 11/3/2016 0.80 PROD1 WELLPR RURD X Prep rig floor and wait on E-line to 0.0 07:30 08:18 arrive 11/3/2016 11/3/2016 2.70 PROD1 WELLPR ELNE X Eline Arrived @ 08:30-redress the 08:18 11:00 head prior to R/U.// PJSM 11/3/2016 11/3/2016 8.00 PROD1 WELLPR ELNE X RIH and log SCMT from 5,100'to 11:00 19:00 surface. Software failure caused -2hours of stby.Perform repeat pass from 2,300'-1,800'for effect. 11/3/2016 11/3/2016 1.15 PROD1 WELLPR ELNE X Change out tools from SCMT to 19:00 20:09 Caliper. Calibrate same. 11/3/2016 11/4/2016 3.85 PROD1 WELLPR ELNE X Perform caliper log. 20:09 00:00 11/4/2016 11/4/2016 0.75 PROD1 WELLPR ELNE X OOH with eline caliper run. Begin rig 00:00 00:45 down. 11/4/2016 11/4/2016 1.45 PROD1 WELLPR BHAH X Clean rig floor and lay down SWS 00:45 02:12 eline gear. Pick up Baker G-plug Prep to RIH. 11/4/2016 11/4/2016 1.25 PROD1 WELLPR TRIP X RIH with BAker G-plug and set at 2,350.0 02:12 03:27 -2,350'MD. 11/4/2016 11/4/2016 0.25 PROD1 WELLPR MPSP X Set G-plug and pressure test to 1,000 2,350.0 2,350.0 03:27 03:42 PSI for 10 min as per amendend proceedure signed on 11/3/16. Prepare to PUH release from plug and dump 100'of 16/30 frac sand. 11/4/2016 11/4/2016 2.30 PROD1 WELLPR CIRC X Dumped 2100 lbs of sand for 100 ft 2,261.0 2,261.0 03:42 06:00 sand top. Pump 5 bbls following sand dump to ensure DP is clear. Tag top of Sand @ 2261' 11/4/2016 11/4/2016 2.00 PROD1 WELLPR TRIP X TOOH and lay down packer setting 2,261.0 0.0 06:00 08:00 tool. R/U hard line in the cellar to kill tank and rock washer.Pressure test. 11/4/2016 11/4/2016 2.00 PROD1 -CSGRCY TRIP X P/U Baker Multi string cutter and TIH 0.0 1,713.0 08:00 10:00 to estimated cut depth of 1715' Page 4/22 Report Printed: 11/28/2016 • • Operations Summary (with Timelog Depths) 1 Y-05 acoPhillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/4/2016 11/4/2016 2.50 PROD1 CSGRCY CPBO X Located collar @ 1707'&1746'. P/U 1,713.0 1,713.0 10:00 12:30 and stand back 1 stand, P/U 10ft pup. Being cutting @ 1713'.Line up and pump 100 degree fresh water.Set paremeters: RPM 80/Pump 55 SPM/870 psi/TQ 3K/,weight 1-2K down.Pressure dropped about 8 minutes into cut down to 360 psi.Continue cutting-no pressure or fluid noticed on OA. continue with cutting for a total of 15 mins.Stop.Attempt to pump around casing-no luck. Make second attempt at cutting for 15 mins same results,pressure never increased past 410 psi.Attempt to to break circulation again with OA no luck,wiht max pressure of 1000 psi. 11/4/2016 11/4/2016 1.00 PROD1 CSGRCY TRIP X WHen cutter is free-pressure only 1,713.0 0.0 12:30 13:30 increased to 400 psi-should be around 800-900 psi.Decision made to TOOH and inspect cutter. 11/4/2016 11/4/2016 1.00 PROD1 CSGRCY BHAH X Inspect cutter-all three cutters are 0.0 0.0 13:30 14:30 worn down but looks like it may have made cut. Redress with new cutters. 11/4/2016 11/4/2016 1.00 PROD1 CSGRCY TRIP X TIH down to 1399'to make second 0.0 1,399.0 14:30 15:30 cut. 11/4/2016 11/4/2016 0.50 PROD1 CSGRCY CPBO X Find collar @ 1393'-cut depth 1399'- 1,399.0 1,399.0 15:30 16:00 Set paremeters for cutting: 55 spm/850psi/80 rpm/TQ 3K/ string weight 50K,down weight 2K. Attempt to cut,good indication of cut 7 minutes into.Stop and attempt to circulate aroiund 7"-No luck. 11/4/2016 11/4/2016 0.75 PROD1 CSGRCY CPBO X TOOH to next cut depth of 854'- 1,399.0 854.0 16:00 16:45 locate collar @ 848'-move to cut position of 854'-set paremeters: Attempt to make cut-no luck blades are possibly worn down. 11/4/2016 11/4/2016 0.75 PROD1 CSGRCY BHAH X TOOH to C/O blades 854.0 0.0 16:45 17:30 11/4/2016 11/4/2016 0.50 PROD1 CSGRCY TRIP X Inspect cutter-all three cutter blades 0.0 0.0 17:30 18:00 are worn down but looks like it may have made cut.Redress cutter with new blades.TIH down to 854'to reattempt cut. 11/4/2016 11/4/2016 0.75 PROD1 CSGRCY BHAH X Locate cutting depth @ 854'and set 0.0 854.0 18:00 18:45 parameters.Begin cutting @ 854' Rotate at 80 RPM/Pump 62 SPM/ 1000 psi.Pressure dropped about 10 minutes into cut down to 480 psi. Continue cut casing and stage up pump to 7.5 bpm and 600 psi.Shut down pump and bleed off pressure. 11/4/2016 11/4/2016 1.50 PROD1 CSGRCY CPBO X Break circulation.Circulate Arctic pack 854.0 854.0 18:45 20:15 up OA. Pump 150 bbls at 4 BPM and 675 psi.Let set for 15 minutes and pump 10 more bbls.Shut down open annular and circulate 25 bbls long way at 4 BPM and 500 psi.Shut down pump. Page 5/22 Report Printed: 11/28/2016 • • Operations Summary (with Timelog Depths) *If: 1Y-05 ConocoPhilliips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/4/2016 11/4/2016 0.50 PROD1 CSGRCY CIRC X POOH PU=49K lbs. 854.0 0.0 20:15 20:45 11/4/2016 11/4/2016 0.25 PROD1 CSGRCY TRIP X L/D Multi string cutter and clean rig 0.0 0.0 20:45 21:00 floor 11/4/2016 11/4/2016 1.30 PROD1 CSGRCY BHAH X PJSM-N/D BOPE.Csg still growing 0.0 0.0 21:00 22:18 with stack weight.MU 6-3/4"collars for extra weight. 11/4/2016 11/5/2016 1.70 PROD1 CSGRCY CUTP X BOLDS attempt to pull BOP and allow 0.0 22:18 00:00 casing to grow. Set drill collars on plug in WH to asist in compression. 7" Casing still growing. Prep to RIH for another cut. 11/5/2016 11/5/2016 0.30 PROD1 CSGRCY BHAH X Prepare BHA for re-run of casing 737.0 00:00 00:18 cutter.TIH to 737' 11/5/2016 11/5/2016 2.00 PROD1 CSGRCY CPBO X Make another cut @ 737'ROP 80,6.2 737.0 659.0 00:18 02:18 bpm @ 1110 psi,good cut. POOH to 659'Make another cut 80 RPM,7.5 bpm @ 650 psi. 11/5/2016 11/5/2016 1.00 PROD1 CSGRCY TRIP X TOOH&lay down multi cutter. 659.0 0.0 02:18 03:18 11/5/2016 11/5/2016 2.00 PROD1 CSGRCY CUTP X P/U 2 joints of DC and blanking plug, 0.0 0.0 03:18 05:18 set down weight with TD and break out lower tubing head bolts.Install safety bolts and couplers. 11/5/2016 11/5/2016 1.50 PROD1 CSGRCY CUTP X LD DC and ND adapter spools and 0.0 05:18 06:48 BOPE 11/5/2016 11/5/2016 1.50 PROD1 CSGRCY CUTP X P/U DC and test plug,squat weight 0.0 06:48 08:18 down and back out bolt extentions total growth=11"of casing.LD drill collars and test plug. Remove rusted bolts from casing head in WH. 11/5/2016 11/5/2016 1.50 PROD1 CSGRCY PULL X M/U spear attempt to pull casing to 0.0 08:18 09:48 remove slips-tally was only supposed to be 4'but pulled 36'for slips to come up with collar.Attmepted to pull slips after 6ft but too tight to remove from Hanger. Pull slips,attempt to go back down- no luck. 11/5/2016 11/5/2016 2.00 PROD1 CSGRCY CUTP X R/U Wachs cutter and cut the 7" 0.0 09:48 11:48 casing. 11/5/2016 11/5/2016 1.50 PROD1 CSGRCY BHAH X LD spear-lay down cut joint of 7" 0.0 11:48 13:18 casing. 11/5/2016 11/5/2016 4.00 PROD1 CSGRCY NUND X NU X over, 13 5/8"Flow X and BOPE. 13:18 17:18 11/5/2016 11/5/2016 1.15 PROD1 CSGRCY BOPE X Fill stack and test BOP. Chart same. 17:18 18:27 11/5/2016 11/5/2016 0.70 PROD1 CSGRCY PULL X Spear 7"casing fish and pull casing to 632.2 0.0 18:27 19:09 rig floor. Sporatic weight swings. 15- 20K WT stutter swings. 11/5/2016 11/5/2016 2.00 PROD1 CSGRCY PULL X OOH with 7"casing from joint 16 to 19:09 21:09 surface. 241.72'measured pipe. Joint three has severe bend. Joint twelve somewhat of a bend. Seeing excessive external wear due to casing head and possible 9 5/8"casing damage. Page 6/22 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) 1Y-05 oc ehilliips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr). Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 11/5/2016 11/6/2016 2.85 COMPZN CSGRCY BHAH X Clean rig floor.Perform derick 21:09 00:00 inspection from heavy vibrations during 7"pull. Pick up 7"BHA fishing assym for effect. Prepare to RIH. 11/6/2016 11/6/2016 1.00 PROD1 CSGRCY BHAH XT Tour change over. PJSM,BHA make 00:00 01:00 up prepare to RIH. 11/6/2016 11/6/2016 0.30 PROD1 CSGRCY BHAH XT RIH with BHA#7 to grab second cut. 01:00 01:18 11/6/2016 11/6/2016 0.70 PROD1 CSGRCY BHAH XT Tag up at—253'with drill collars. 01:18 02:00 POOH to drop collars and attempt to RIH with DP only. 11/6/2016 11/6/2016 0.15 PROD1 CSGRCY TRIP XT RBIH with fissing assy#11 to latch 7" 02:00 02:09 fish. at 210'-280'had to screw in and push with TD 5-8K DWN WT. Latch into fish and POOH note extreme OP again at 250'area.Time log compressed due to DLST. 11/6/2016 11/6/2016 2.20 PROD1 CSGRCY BHAH XT OOH with fish. Clean rig floor. 02:09 04:21 Change out pulling equipment. Clean rig floor. Pull 7"fish out of overshot. Prepare grapple for re-run. 11/6/2016 11/6/2016 1.00 PROD1 CSGRCY TRIP XT RIH to TOF. Circulate 15 BBLs to 04:21 05:21 clean out Arctic Pak residue. Sting into fish at 737'MD. Overpull good. POOH. 11/6/2016 11/6/2016 3.00 PROD1 CSGRCY PULL XT TOOH and lay down 7"fish(116'). 05:21 08:21 11/6/2016 11/6/2016 0.66 PROD1 CSGRCY TRIP X M/U BHA#10-TIH down to 854' 08:21 09:00 Circulate B/U before spearing fish. 11/6/2016 11/6/2016 3.00 PROD1 CSGRCY PULL X Tag TOF @ 854'-took 5K to get nose 09:00 12:00 into fish,P/U and have fish on but could not engange slips.Drag Fish up hole 100',fish dropped off,go back down and latch into fish,full swallow and set grapple.TOOH with fish from 854 to 1399'. Lay down casing.Total length 546'. 11/6/2016 11/6/2016 1.50 PROD1 CSGRCY SVRG X Service rig,TD and C/O diaper pin to 12:00 13:30 bolt on block hinge pin. 11/6/2016 11/6/2016 0.50 PROD1 CSGRCY BHAH X Break cut off spear. 13:30 14:00 11/6/2016 11/6/2016 1.50 PROD1 CSGRCY TRIP X TIH with BHA#11 to fish lasat cut 14:00 15:30 from 1399'to 1713'.Circulate B/U prior to latching fish. 11/6/2016 11/6/2016 2.79 PROD1 CSGRCY TRIP X Circulate bottoms up prior to latching 15:30 18:18 fish at 1,395' Latch fish and tag at 1,401 MD. Pick up and POOH. 11/6/2016 11/6/2016 1.75 PROD1 CSGRCY BHAH X OOH lay down fish. change out 18:18 20:03 elevators,clean rig floor,remove fish from spear. PJSM Prep BHA#12 for fresh cut at—1,760'MD. 11/6/2016 11/6/2016 1.25 PROD1 CSGRCY TRIP X Trip in hole with BHA#12 for casing 20:03 21:18 cut. 11/6/2016 11/6/2016 0.85 PROD1 CSGRCY TRIP X Tag top of 7"cut at 1,710'MD. Work 21:18 22:09 several time in attempt to gain access with Baker casing cutting tool. Unable to gain full access. POOH to PU dressout Mill. Page 7/22 Report Printed: 11/28/2016 • 0 Operations Summary (with Timelog Depths) Fit 1Y-05 ConocoPhiiiips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth '..Start Time; End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKB);. 11/6/2016 11/7/2016 1.85 PROD1 CSGRCY BHAH X OOH contact Anchorage with plan 22:09 00:00 forward to move ahead and dress off 9 5/8". Clean rig floor prepare to pick up BHA. Crwe change. 11/7/2016 11/7/2016 1.00 PROD1 CSGRCY BHAH X PJSM. Break out cross over. Install 0.0 0.0 00:00 01:00 BHA for openning 9 5/8"casing. RIH. 11/7/2016 11/7/2016 0.15 PROD1 CSGRCY TRIP X Tagged at 118'Prep to POOH and lay 0.0 118.0 01:00 01:09 down drill collar. Pickup single to drill down. 11/7/2016 11/7/2016 0.85 PROD1 CSGRCY TRIP X RBIH and engage tight spot at 110.0 115.0 01:09 02:00 11/7/2016 11/7/2016 1.00 PROD1 CSGRCY TRIP X POOH to install Wear ring. Stand 115.0 0.0 02:00 03:00 back collars and BHA. Blow down top drive. 31 min total rotational time begor POOH. 11/7/2016 11/7/2016 0.75 PROD1 CSGRCY WWSP X Install wear ring. 0.0 0.0 03:00 03:45 11/7/2016 11/7/2016 0.55 PROD1 CSGRCY TRIP X RIH with hole openning BHA#12. 0.0 0.0 03:45 04:18 11/7/2016 11/7/2016 6.00 PROD1 CSGRCY MILL X Mill and back ream from 183'down to 183.0 307.0 04:18 10:18 307'. 80 RPM,TQ 2-6k,6 bpm/70 psi,WOB 3-7 K. 11/7/2016 11/7/2016 1.00 PROD1 +CSGRCY TRIP X P/U 1 stand of 6 1/8"DC. 307.0 1,713.0 10:18 11:18 TIH to bottom to guage 9 5/8"No more tight spots encountered to top of 7"@ 1713' 11/7/2016 11/7/2016 1.00 PROD1 CSGRCY CIRC X Circulate B/U with 90 degree FW- 1,713.0 1,713.0 11:18 12:18 followed by 30 bbls sweep&90 FW @ 6 bpm/110 psi. 11/7/2016 11/7/2016 3.00 PROD1 CSGRCY TRIP X TOOH to P/U additional string mill 1,713.0 0.0 12:18 15:18 BHA. 11/7/2016 11/7/2016 1.00 PROD1 CSGRCY BHAH X OOH add Mill and RIH to ream tight 0.0 0.0 15:18 16:18 spots. 11/7/2016 11/7/2016 4.00 PROD1 CSGRCY MILL X Pick up stand of DP RIH tag up at 115' 0.0 110.0 16:18 20:18 MD. Begin reaming operations. 11/7/2016 11/7/2016 0.30 PROD1 CSGRCY TRIP X PUH add drill collar to BHA.Bury 110.0 175.0 20:18 20:36 same.. 11/7/2016 11/8/2016 3.41 PROD1 CSGRCY MILL X Milling at 115'-123, 160-240"very 175.0 220.0 20:36 00:00 tight. 11/8/2016 11/8/2016 6.75 PROD1 CASING MILL X Continue milling with tandem 8-1/2" 220.0 320.0 00:00 06:45 mills from 210'to 2727'. String weight =45k,Pumping at 6.5 bpm, Rotate through 210'to 227'several times. Turn off top drive and slide from 210' to 227'with no problems. Mill from 227'to 320'. Work through several times while rotating. Stop rotating and slide through with no problems. 11/8/2016 11/8/2016 0.25 PROD1 CASING TRIP X POOH from 320'to 137'. 320.0 1,710.0 06:45 07:00 11/8/2016 11/8/2016 0.25 PROD1 CASING BHAH X Pick up one stand of drill collars. 0.0 0.0 07:00 07:15 11/8/2016 11/8/2016 0.50 PROD1 CASING TRIP X RIH from 227'to 1706'with no 1,710.0 1,716.0 07:15 07:45 problems. 11/8/2016 11/8/2016 0.75 PROD1 CASING TRIP X POOH from 1706'to 227' 1,716.0 227.0 07:45 08:30 Page 8/22 Report Printed: 11/28/2016 • • 3 Operations Summary (with Timelog Depths) 0 1Y-05 ConocoPhillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKB) 11/8/2016 11/8/2016 0.50 PROD1 CASING BHAH X Rack back two stand of drill collars 227.0 0.0 08:30 09:00 and lay down milling BHA. 11/8/2016 11/8/2016 0.50 PROD1 CASING BHAH X Clear rig floor. Mobilize Baker tools to 0.0 0.0 09:00 09:30 rig floor 11/8/2016 11/8/2016 0.75 PROD1 CASING BHAH X Make up junk mill BHA 0.0 209.0 09:30 10:15 11/8/2016 11/8/2016 0.75 PROD1 CASING TRIP X RIH with junk mill BHA from 209'to 209.0 1,710.0 10:15 11:00 1710'. Set down 5k and break circulation at 6 bpm, 150 psi.. 80 rpm, 1k ft-lbs torque, P/U=67 k,5/0= 57k, 11/8/2016 11/8/2016 1.00 PROD1 CASING MILL X Mill 7"casing from 1710'to 1712'. 1,710.0 1,712.0 11:00 12:00 11/8/2016 11/8/2016 4.00 PROD1 CASING MILL X Continue milling 7"casing from 1712' 1,712.0 1,716.0 12:00 16:00 to 1716' 11/8/2016 11/8/2016 0.75 PROD1 CASING CIRC X Pump 30 bbl hi-vis sweep at 1714' 1,716.0 1,716.0 16:00 16:45 11/8/2016 11/8/2016 1.25 PROD1 CASING TRIP X Monitor well. Blow down top drive. 1,716.0 0.0 16:45 18:00 POOH 11/8/2016 11/8/2016 0.50 PROD1 CASING RURD X Clear rig floor 0.0 0.0 18:00 18:30 11/8/2016 11/8/2016 0.50 PROD1 CASING WWWH X Flush BOPE 0.0 0.0 18:30 19:00 11/8/2016 11/8/2016 1.25 PROD1 CASING BHAH X Make up BHA with 8-3/8"dressoff 0.0 201.0 19:00 20:15 sleeve and attempt to RIH. Unable to get past 201' Set down 10k and unable to make progress. 11/8/2016 11/8/2016 0.75 PROD1 CASING TRIP X POOH and inspect dress off sleeve 201.0 0.0 20:15 21:00 11/8/2016 11/8/2016 0.50 PROD1 CASING BHAH X Bring 8-3/4"mill to the rig floor. Clear 0.0 0.0 21:00 21:30 rig floor 11/8/2016 11/8/2016 1.25 PROD1 CASING BHAH X Make up BHA with 8-3/4"mill and one 0.0 149.0 21:30 22:45 stand of drillpipe. Wash to 149' 11/8/2016 11/8/2016 0.75 PROD1 CASING WASH X Rack back one stand of drillpipe and 149.0 201.0 22:45 23:30 pick up two drill collars. RIH to 130' and break circulation. Wash to 201' 11/8/2016 11/9/2016 0.50 PROD1 CASING MILL X Mill tight spot from 201'to 202'. Work 201.0 215.0 23:30 00:00 string from 201'to 215'. 11/9/2016 11/9/2016 4.50 PROD1 CASING MILL X Continue reaming and dressing 9 5/8" 215.0 0.0 00:00 04:30 from 155'to 294'with 8.75"string mill. TIH down to top of fish 1715'-TOOH with string mill and lay down BHA. 11/9/2016 11/9/2016 2.00 PROD1 CASING BHAH X P/U 7"dress off assembly with 8 3/8" 0.0 0.0 04:30 06:30 OD-no luck drifting past 222'.lay down&inspect assembly. 11/9/2016 11/9/2016 1.00 PROD1 CASING BHAH X P/U BHA#20-with 8.5"string mill 0.0 224.0 06:30 07:30 with 14 ft of stand off then 8 3/4"string mill. 11/9/2016 11/9/2016 4.00 PROD1 CASING MILL X Begin dressing off 9 5/8"-upper string 224.0 0.0 07:30 11:30 mill beging to work from 224'-work down to 230'.TOOH and attempt to get 7"dress off assembly thru-No luck tagged 1.5ft deeper. P/U string mill assembly with stand off. Page 9/22 Report Printed: 11/28/2016 • • ii'0 Operations Summary (with Timelog Depths) 0 1Y-05 Conots!'hitllps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 11/9/2016 11/9/2016 11.50 PROD1 CASING MILL X Mill and backream from 213'down to 0.0 306.0 11:30 23:00 400'. Pick up to 273'taking 4-6 k over pull!. Slack off and taking 4k to go through tight spot from 250-260'. Re sume milling tight spot from 240'to 306'. Slide through tight spots with 3 k drag. 11/9/2016 11/10/2016 1.00 PROD1 CASING BHAH X POOH and lay down BHA. Inspect 306.0 0.0 23:00 00:00 mills. Bottom mill worn from 8-1/2"to 8-3/16"and upper mill worn from 8- 3/4"to 8-1/4" 11/10/2016 11/10/2016 1.25 PROD1 CASING TRIP X Pick up 7"dress off mill and one stand 0.0 0.0 00:00 01:15 of drill collars. RIH and tag up at 225'. Set down 5-10 k with no success. POOH and lay down dress off tool. 11/10/2016 11/10/2016 1.00 PROD1 CASING TRIP X Make up 8-1/2"tandem milling BHA 0.0 213.0 01:15 02:15 and RIH.to 290'. Hit tight spots at 245',285'and 290'taking 3-7k to get through. 11/10/2016 11/10/2016 4.00 PROD1 CASING MILL X Mill from 213'to 308'at 80 rpm,6 213.0 308.0 02:15 06:15 bpm,50 psi, Slide from 213'to 308' with no pump or rotary taking 1-8 k to get down. Pick up one stand and slide from 308'to 401'with no problems. 11/10/2016 11/10/2016 0.75 PROD1 CASING TRIP X POOH and rack back drill collars. Lay 308.0 0.0 06:15 07:00 down mills. Mobilize new 8-3/4"mills to the rig floor 11/10/2016 11/10/2016 0.50 PROD1 CASING SVRG X Service rig and top drive system. 0.0 0.0 07:00 07:30 11/10/2016 11/10/2016 0.50 PROD1 CASING TRIP X Make up new 8-3/4 tandem milling 0.0 221.0 07:30 08:00 assembly. RIH to 221' 11/10/2016 11/10/2016 2.25 PROD1 CASING MILL X Mill from 221'to 409'. Work mills from 221.0 409.0 08:00 10:15 221'to 409'two times at milling rate. 11/10/2016 11/10/2016 0.25 PROD1 CASING TRIP X RIH to 1081'with no problems 409.0 1,081.0 10:15 10:30 11/10/2016 11/10/2016 0.25 PROD1 CASING TRIP X POOH from 1081'to 409'with no 1,081.0 409.0 10:30 10:45 problems 11/10/2016 11/10/2016 0.50 PROD1 CASING MILL X Back ream out of the hole from 409'to 409.0 221.0 10:45 11:15 221'. No increase in torque 11/10/2016 11/10/2016 0.75 PROD1 CASING TRIP X POOH and lay down milling BHA 221.0 0.0 11:15 12:00 11/10/2016 11/10/2016 0.50 PROD1 CASING SVRG X Inspect torque tube and top drive 0.0 0.0 12:00 12:30 11/10/2016 11/10/2016 1.50 PROD1 CASING TRIP X Make up dress off sleeve BHA and 0.0 1,637.0 12:30 14:00 RIH. Tag at 225'and push through with 10k. Continue RIH to 1637' 11/10/2016 11/10/2016 1.25 PROD1 CASING WASH X Break circulation and start washing 1,637.0 1,715.0 14:00 15:15 down at 1637' Tag fill at 1685'. Pump sweep and wash fill to 1715' 11/10/2016 11/10/2016 1.00 PROD1 CASING MILL X Dress off top of 7"casing from 1715' 1,715.0 1,717.0 15:15 16:15 to 1717'(shoe at 1721'). Pump high vis sweep 11/10/2016 11/10/2016 3.50 PROD1 CASING TRIP X POOH and lay down BHA. Recovered 1,717.0 0.0 16:15 19:45 piece of casing in dress off sleeve (approximately 3/4"x 11'long). Page 10/22 Report Printed: 11/28/2016 • 0 Operations Summary (with Timelog Depths) . ,V 1Y-05 ConacoPhitlips ;.. Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 11/10/2016 11/10/2016 0.75 PROD1 CASING RURD XT Attempt to pull wear ring. 0.0 0.0 19:45 20:30 11/10/2016 11/10/2016 0.75 PROD1 CASING NUND X Nipple down BOPE 0.0 0.0 20:30 21:15 11/10/2016 11/10/2016 0.50 PROD1 CASING OTHR XT Clean and steam wear ring. Pull free 0.0 0.0 21:15 21:45 with 10 k. 11/10/2016 11/10/2016 1.75 PROD1 CASING EQRP X Dress wellhead while cutting and 0.0 0.0 21:45 23:30 slipping drilling line 11/10/2016 11/11/2016 0.50 PROD1 CASING NUND X Nipple up BOPE 0.0 0.0 23:30 00:00 11/11/2016 11/11/2016 2.00 PROD1 CASING NUND X NU BOPE and test flange break to 0.0 0.0 00:00 02:00 500 psi 11/11/2016 11/11/2016 5.50 PROD1 CASING PUTB X PJSM-P/U 7"patch and casing as 0.0 1,722.0 02:00 07:30 per running order. P/U weight 70K on bottom Wash down and rotate from 1708' pumping 5 bpm,pump 20 bbl sweep, lots of sand back over the shakers, slowly rotating-pressure build to 600 psi.Stop pumps,bleed off and swallow 3.5'of casing stub.P/U overpull in stages-from 25K-100K overpull.Pressure test pack off to 1000 psi.-good test. TOP of casing @ 1718'RKB- overshot down to 1721.5' 11/11/2016 11/11/2016 0.50 PROD1 CASING RURD X R/D casing equipment,blow down TD 0.0 0.0 07:30 08:00 11/11/2016 11/11/2016 3.50 PROD1 CASING NUND X PJSM-ND stack, P/U on casing 70K 0.0 0.0 08:00 11:30 over string weight to 140 K,install emergency slips and set down weight.Estimated wieght in emergency slips is 50K. R/U wachs cutter and cut casing- length OOH=23.9'Left in hole 15.5' 11/11/2016 11/11/2016 1.00 PROD1 CASING RURD X Break down rig floor equipment,lay 0.0 0.0 11:30 12:30 down cut joint,pack WH with heavy sealant. 11/11/2016 11/11/2016 3.50 PROD1 CASING NUND X N/U tubing spool,and N/U BOPE and 0.0 12:30 16:00 riser 11/11/2016 11/11/2016 1.00 PROD1 CASING WWSP X Test Casing pack off to 3000 psi ffor 0.0 16:00 17:00 15 minutes 11/11/2016 11/11/2016 1.00 PROD1 CEMENT RURD X R/U SLB cementers,build cement 0.0 0.0 17:00 18:00 manifold in cellar for cement job. 11/11/2016 11/11/2016 1.00 PROD1 CEMENT PRTS X Set test plug and test flange 0.0 0.0 18:00 19:00 connections 250/3000 psi. 11/11/2016 11/11/2016 2.00 PROD1 CEMENT TRIP X PJSM-P/U 2 7/8"setting tool and TIH 0.0 1,650.0 19:00 21:00 on DP to 1650' 11/11/2016 11/11/2016 0.50 PROD1 CEMENT DHEQ X RIH to 1712'and locate cementing 1,650.0 1,650.0 21:00 21:30 string in profile at 1684'with 5000 kips overpull. POOH to 1650' 11/11/2016 11/11/2016 0.25 PROD1 CEMENT CIRC X Circulate 28 bbarels to clear 1,650.0 1,650.0 21:30 21:45 cementing string 11/11/2016 11/11/2016 0.75 PROD1 CEMENT CIRC X Drop dual plug and pump down at 2 1,650.0 1,712.0 21:45 22:30 bpm. Pressure up to 600 psi and then to 2000 psi. Page 11/22 Report Printed: 11/28/2016 0 410 Operations Summary (with Timelog Depths) vs !IA I Y-05 ConocoPhifps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Ttme : End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/11/2016 11/12/2016 1.50 PROD1 CEMENT CIRC XT Space out with a 5'drillpipe pup and 1,712.0 1,712.0 22:30 00:00 RIH to 1712'. Locate in profile and verify location by pulling out of profile three times. Attempt to break rupture disc by increasing pressure to 3000 psi in 500 psi increments without success. (Rupture disc pinned to break at 600 psi) 11/12/2016 11/12/2016 1.00 PROD1 CEMENT CIRC XT Attempt to circulate thru DP and take 1,712.0 1,712.0 00:00 01:00 returns to OA. No luck-shifting dart has not cleared DH X over on top of shifting tool. 11/12/2016 11/12/2016 3.50 PROD1 CEMENT TRIP XT TOOH to C/O 3 1/2 IF X 4"XT39 1,712.0 0.0 01:00 04:30 11/12/2016 11/12/2016 1.50 PROD1 CEMENT TRIP XT P/U newX over that has been drifted 0.0 1,712.0 04:30 06:00 at surface with plug-TIH down to 1712'Drop plug at surface and chase DH. Plug landed on landing collar, hold 2000/5 mins.Shear disc @ 2050 psi. 11/12/2016 11/12/2016 2.50 PROD1 CEMENT CIRC X Break circulation and begin pumping 1,712.0 1,712.0 06:00 08:30 FW around cleaning up sand between 7 X 9 5/8. Pump sweep around-lots of surface sand returns to surface,continue pumping @ 2 bpm/2500 psi until returns clean up over shakers.(total pumped 360 bbls).Shut down and blow down all surface lines back to rock washer to ensure clean of gravel and sand. 11/12/2016 11/12/2016 1.00 PROD1 CEMENT CMNT XT PJSM-Presure test cement lines to 1,712.0 1,712.0 08:30 09:30 2500 psi.Set trips to ensure not exceeding 2500 while pumping cement job. Pumped 10 bbls of neat 2 bpm/100 psi. Pump Pressure net-3 bpm/100 psi- 13 bbls away the pressure locked up to 3000 psi immediatly.Try to squeeze fluid thru tool NO luck. 11/12/2016 11/12/2016 0.50 PROD1 CEMENT DISP XT Call town-pressure up and relieve 1,712.0 1,712.0 09:30 10:00 burst disk @ 4300 psi-chase cement with SLB for 15 bbls.Switch to rig pump 20 bbls contain pill and chase cement from DP&7"pumping 5 bpm @ 1100 psi down DP additional 80 bbls. 11/12/2016 11/12/2016 1.00 PROD1 CEMENT TRIP XT P/U on string 6 ft-saw tool shifting the 1,712.0 0.0 10:00 11:00 patch into closed position after P/U 3ft. TOOH with DP. 11/12/2016 11/12/2016 3.50 PROD1 CEMENT OTHR XT Clean up&flush all 2 7/8"tools,DH 0.0 0.0 11:00 14:30 shifting tool.Flush all lines,BOPE, cement lines&guages. 11/12/2016 11/12/2016 3.00 PROD1 PERF OTHR XT SLB Eline arrived on location-spot 0.0 0.0 14:30 17:30 and R/U while casing guns is being transported from Deadhorse. Rebuild firing head. Page 12/22 Report Printed: 11/28/2016 0 • ' Operations Summary (with Timelog Depths) '' ' 1Y-05 ConocoPhitlips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/12/2016 11/12/2016 4.25 PROD1 PERF PERF XT Make up gun run#1. RIH and get on 0.0 0.0 17:30 21:45 depth. Perforate from 1495'to 1500' WLM. POOH. All shots fired. Attempt to pump into perforations at 2500 psi without success. Make up gun run#2 and RIH. Get on depth and perforate from 1345'to 1350' WLM. POOH. All shots fired. Pump into perforations at 5 bpm @ 100 psi. Pressure increased to 250 psi and started losing 100 bph. Reduced rate to 3 bpm and losses decreased tp 14 bph. Pumped a total of 62 bbl and lost 13.3 bbl. Made gun run#3 and got on depth. Perforated from 1340'to 1345'. POOH. Confirmed all shots fired. 11/12/2016 11/12/2016 0.75 PROD1 CEMENT WAIT XT Wait on cement retainer to arrive from 0.0 0.0 21:45 22:30 Dead Horse. Clear floor 11/12/2016 11/13/2016 1.50 PROD1 CEMENT TRIP XT Make up 7"retainer and RIH to 581'. 0.0 581.0 22:30 00:00 11/13/2016 11/13/2016 1.30 PROD1 CEMENT TRIP X TIH and set retainer at 1212'Top of 1,207.0 00:00 01:18 retainer 1207' 11/13/2016 11/13/2016 0.70 PROD1 CEMENT CIRC X Begin pumping FW and circulate hole 1,207.0 1,207.0 01:18 02:00 clean pumping 3 bpm @ 100 psi. 11/13/2016 11/13/2016 2.50 PROD1 CEMENT CMNT X PJSM-P-test lines 250/4500 psi. 1,207.0 1,050.0 02:00 04:30 Pump 5 bbls fresh water Begin pumping 15.7#Cement seen returns up OA after 62 bbls away,pump additional 7 bbls,shut the OA- squeeze away additional 6 bbls. Pressure increase to 300 psi. Sting out of retainer with 3 bbls remainig in DP. P/U DP to 1050'-Circulate out remaing cement from DP and 7". 11/13/2016 11/13/2016 0.50 PROD1 CEMENT TRIP X TOOH from 1054'LD reatiner running 1,050.0 0.0 04:30 05:00 tool. 11/13/2016 11/13/2016 2.00 PROD1 CEMENT RURD X R/D cementers,clean out stack,floor 0.0 0.0 05:00 07:00 valves,service lines,OA lines in cellar. 11/13/2016 11/13/2016 2.00 PROD1 CEMENT RURD X C/O upper 7"rams to 3.5"X 6"VBR 0.0 0.0 07:00 09:00 Clear rig floor,service rig 11/13/2016 11/13/2016 0.50 PROD1 WHDBOP RURD X R/U test equipment-set test plug. 0.0 0.0 09:00 09:30 **BOPE test waived witness by Bob Noble" Page 13/22 Report Printed: 11/28/2016 0 • Operations Summary (with Timelog Depths) 1Y-05 :wick hillips A%ssA::a Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/13/2016 11/13/2016 5.25 PROD1 WHDBOP BOPE X Begin BOPE test 250/3000 psi using 0.0 0.0 09:30 14:45 3.5&5.5"TJ. Test#1 UPR pipe rams 5 1/2",Valves 1,12,13,14&Manual kill Test#2 UPR IBOP,HCR kill,Valves 9 &11 Test 3 Lower IBOP,valves 5,8,&10 Tes 4 dart valve,valves 4,6&7 Test 5 floor valve&valve#2 Test 6 HCR,choke valve,HCR kill Test 7 Manual choke&HCR kill Test 8 51/2"Annular Test 9-5 1/2" PR Test 10 Blind rams and valve 3 Test 11 Lower rams 3 1/2".Test 12 UPR rams 3 1/2"Test 13 Bag 3 1/2" Kummi test-2975,close 1900 psi, 200 psi attained-38 secs,full pressure 157 secs. 11/13/2016 11/13/2016 1.50 PROD1 WHDBOP RURD X Pull test plug,set wear ring.PJSM for 0.0 300.0 14:45 16:15 P/U BHA.#26-6 1/8"junk mill&boot baskets 11/13/2016 11/13/2016 0.50 PROD1 WELLPR TRIP X TIH and tag top of cement @ 1110'. 300.0 1,110.0 16:15 16:45 P/U and set paremeters.Mill cement pumping visc FW 6 bpm@ 250 psi, RPM 60,TQ 1K,WOB 2-4K. 11/13/2016 11/13/2016 0.75 PROD1 'WELLPR WASH X Wash and ream soft cement from 1,110.0 1,208.0 16:45 17:30 1110'to retainer at 1208'. 11/13/2016 11/13/2016 3.00 PROD1 WELLPR MILL X Millon retainer from 1208'to 1210' 1,208.0 1,210.0 17:30 20:30 11/13/2016 11/13/2016 2.25 PROD1 WELLPR MILL X Mill cement from 1210'to 1345'. CBU 1,210.0 1,345.0 20:30 22:45 11/13/2016 11/13/2016 0.50 PROD1 WELLPR PRTS X Pressure test casing to 1000 psi for 5 1,345.0 1,345.0 22:45 23:15 minutes. Bled off 20 psi in 5 minutes 11/13/2016 11/14/2016 0.75 PROD1 WELLPR WASH X Wash down from 1345'to 1761'. 1,345.0 1,733.0 23:15 00:00 Tagged possible junk. Make up top drive and wash through with no problesm Continue washing to 1733'. Did not tag anything at casing patch at 1718' 11/14/2016 11/14/2016 1.00 PROD1 WELLPR WASH X Circulate and wash down from 1733' 1,733.0 2,238.0 00:00 01:00 to 2238'. 11/14/2016 11/14/2016 1.25 PROD1 WELLPR MILL X Mill on junk from 2238'to 2239'. 2,238.0 2,270.0 01:00 02:15 Wash down to 2270' 11/14/2016 11/14/2016 0.50 PROD1 WELLPR CIRC X Pump hi-vis sweep and displace well 2,270.0 2,270.0 02:15 02:45 to new seawater at 6 bpm. 11/14/2016 11/14/2016 0.75 PROD1 WELLPR TRIP X POOH from 2270'to 220' 2,270.0 220.0 02:45 03:30 11/14/2016 11/14/2016 1.50 PROD1 WELLPR BHAH X Rack back drill collars. Lay down BHA 220.0 227.0 03:30 05:00 and clean boot baskets(full of retainer pieces). Make up reverse circulating junk baskets and boot baskets. 11/14/2016 11/14/2016 0.50 PROD1 WELLPR TRIP X Trip in the hole from 227'to 2213' 227.0 2,213.0 05:00 05:30 11/14/2016 11/14/2016 0.50 PROD1 WELLPR WASH X Break circulation at 2 bpm, Drop ball 2,213.0 2,282.0 05:30 06:00 and increase rate to 6 bpm. Work junk basket down to 2282' 11/14/2016 11/14/2016 0.25 PROD1 WELLPR CIRC X Circulate bottoms up 2,282.0 2,282.0 06:00 06:15 Page 14/22 Report Printed: 11/28/2016 0 °' Operations Summary (with Timelog Depths) D 1Y-05 ConocoPh llips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(MKS). 11/14/2016 11/14/2016 0.50 PROD1 WELLPR TRIP X POOH from 2282'to 227' 2,282.0 227.0 06:15 06:45 11/14/2016 11/14/2016 1.50 PROD1 WELLPR BHAH X Rack back 2 stands of drill collars and 227.0 227.0 06:45 08:15 clean out boot baskets and RCJB. Make up boot baskets and RCJB. 11/14/2016 11/14/2016 0.50 PROD1 WELLPR TRIP X RIH from 227'to 2270' 227.0 2,270.0 08:15 08:45 11/14/2016 11/14/2016 0.25 PROD1 WELLPR WASH X Wash from 2270'to 2282' 2,270.0 2,282.0 08:45 09:00 11/14/2016 11/14/2016 0.25 PROD1 WELLPR FISH X Rotate and work RCJB down from 2,282.0 2,298.0 09:00 09:15 2282'to 2298' 11/14/2016 11/14/2016 0.50 PROD1 WELLPR CIRC X Circulate bottoms up 2,298.0 2,298.0 09:15 09:45 11/14/2016 11/14/2016 0.50 PROD1 WELLPR TRIP X POOH from 2298'to 227' 2,298.0 227.0 09:45 10:15 11/14/2016 11/14/2016 1.50 PROD1 WELLPR BHAH X Clean boot baskets and RCJB. Make 227.0 227.0 10:15 11:45 make up boot baskets and RCJB. 11/14/2016 11/14/2016 0.75 PROD1 WELLPR TRIP X RIH from 227'to 2340' 227.0 2,340.0 11:45 12:30 11/14/2016 11/14/2016 0.50 PROD1 WELLPR WASH X Wash and work RCJB at 2340' 2,340.0 2,340.0 12:30 13:00 11/14/2016 11/14/2016 0.50 PROD1 WELLPR CIRC X CBU 2,340.0 2,340.0 13:00 13:30 11/14/2016 11/14/2016 0.50 PROD1 WELLPR TRIP X POOH from 2340'to 227' 2,340.0 227.0 13:30 14:00 11/14/2016 11/14/2016 1.25 PROD1 WELLPR BHAH X Lay down RCJB and make up RBP 227.0 227.0 14:00 15:15 retrieving tool 11/14/2016 11/14/2016 0.75 PROD1 WELLPR TRIP X RIH to 2284' 227.0 2,284.0 15:15 16:00 11/14/2016 11/14/2016 0.50 PROD1 WELLPR MPSP X Break circulation and wash to the RBP 2,284.0 2,346.0 16:00 16:30 @ 2346'. Pump hi-vis sweep and engage RBP. Release RBP 11/14/2016 11/14/2016 0.50 PROD1 WELLPR CIRC X CBU 2,346.0 2,346.0 16:30 17:00 11/14/2016 11/14/2016 0.75 PROD1 WELLPR TRIP X POOH with RBP from 2346'to 2,346.0 0.0 17:00 17:45 surface. Lay down RBP 11/14/2016 11/14/2016 1.50 PROD1 WELLPR TRIP X RIH with RBP retrieving tool from 0.0 5,532.0 17:45 19:15 surface to 5532' 11/14/2016 11/14/2016 0.50 PROD1 WELLPR MPSP X Wash to 5595 and engage RBP. 5,532.0 5,595.0 19:15 19:45 Release RBP 11/14/2016 11/14/2016 1.00 PROD1 WELLPR CIRC X Circulate bottoms up.@ 6 bpm. Loss 5,595.0 5,595.0 19:45 20:45 rate while circulating=12 bph. Had small volume of gas on bottoms up. Monitor well 11/14/2016 11/14/2016 1.50 PROD1 WELLPR TRIP X POOH with RBP 5,595.0 0.0 20:45 22:15 11/14/2016 11/15/2016 1.75 COMPZN 'RPCOMP BHAH X Clear rig floor and mobilize BHA 0.0 0.0 22:15 00:00 (overshot&jars)to the rig floor 11/15/2016 11/15/2016 1.50 COMPZN RPCOMP TRIP P Continue RIH from 697'to 6091' 697.0 6,091.0 00:00 01:30 11/15/2016 11/15/2016 0.75 COMPZN RPCOMP FISH P Break circulation and wash down to 6,091.0 6,088.0 01:30 02:15 6170'and tag fish. Work overshot to 6175'to engage fish. Fired jars 2 times and fish came free. Pull up to 6088' 11/15/2016 11/15/2016 0.75 COMPZN RPCOMP CIRC P Circulate bottoms up 6,088.0 6,088.0 02:15 03:00 Page 15/22 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) tz 0 1Y-05 ConocoPhiihps. Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/15/2016 11/15/2016 0.25 COMPZN RPCOMP OWFF P Monitor well--fluid level falling 6,088.0 6,088.0 03:00 03:15 11/15/2016 11/15/2016 2.50 COMPZN RPCOMP TRIP P POOH from 6088'to 225' 6,088.0 225.0 03:15 05:45 11/15/2016 11/15/2016 2.75 COMPZN RPCOMP PULL P Rack back drill collars and lay down 225.0 0.0 05:45 08:30 fish(length=131.44')Remove grapple from fish and redress overshot 11/15/2016 11/15/2016 0.50 COMPZN RPCOMP SVRG P Service Rig 0.0 0.0 08:30 09:00 11/15/2016 11/15/2016 1.50 COMPZN RPCOMP BHAH P mobilize rattler and drain sub to the rig 0.0 249.0 09:00 10:30 floor, Make up overshot BHA. 11/15/2016 11/15/2016 1.50 COMPZN RPCOMP TRIP P RIH with overshot from 249'to 6243' 249.0 6,243.0 10:30 12:00 11/15/2016 11/15/2016 0.75 COMPZN RPCOMP FISH P Break circulation. Wash down and 6,243.0 6,243.0 12:00 12:45 engage fish at 6304'. Rattle fish at 2 bpm. Maintain 5 k overpull while rattling and pull fish up 6'. Turn of rattler and POOH to 6243' 11/15/2016 11/15/2016 1.75 COMPZN RPCOMP TRIP P Monitor well and POOH from 6243'to 6,243.0 249.0 12:45 14:30 249' 11/15/2016 11/15/2016 6.25 COMPZN RPCOMP PULL P Stand back drill collars and lay down 249.0 249.0 14:30 20:45 overshot with cut joint. Rig up tubing tongs and lay down fish(1 jt.tubing, GLM 4,4 joints with blast rings,and lower cut joint). Clear rig floor. Remove grapple from fish. Make up overshot. 11/15/2016 11/15/2016 1.25 COMPZN RPCOMP TRIP P RIH from 249'to 6399' 249.0 6,399.0 20:45 22:00 11/15/2016 11/15/2016 0.50 COMPZN RPCOMP FISH P Break circulation and wash down to 6,399.0 6,399.0 22:00 22:30 6490'to engage fish. Pick up 10 k over and rattle fish at 3 bpm. Maintain 10k over pull and rattle fish up 6'. POOH to 6399' 11/15/2016 11/15/2016 1.00 COMPZN RPCOMP CIRC P Drop dart and open pump-out sub with 6,399.0 6,399.0 22:30 23:30 2220 psi. CBU @ 6 bpm. Monitor well. Losing 6 bph 11/15/2016 11/16/2016 0.50 COMPZN RPCOMP TRIP P POOH from 6399 to 4887' 6,399.0 4,887.0 23:30 00:00 11/16/2016 11/16/2016 1.25 COMPZN RPCOMP TRIP P POOH from 4887'to 249' 4,887.0 249.0 00:00 01:15 11/16/2016 11/16/2016 1.75 COMPZN RPCOMP BHAH P Lay down accelerators and rack back 249.0 225.0 01:15 03:00 drill collars. Lay down bumper sub and jars. Lay down overshot--NO RECOVERY. Mobilize tools to the rig floor. Make up cleanout BHA 11/16/2016 11/16/2016 1.25 COMPZN RPCOMP TRIP P RIH from 225'to 6406' 225.0 6,406.0 03:00 04:15 11/16/2016 11/16/2016 0.50 COMPZN RPCOMP WASH P Wash from 6406'to 6485' 6,406.0 6,485.0 04:15 04:45 11/16/2016 11/16/2016 0.50 COMPZN RPCOMP CIRC P Pump sweep and circulate bottoms up 6,485.0 6,485.0 04:45 05:15 11/16/2016 11/16/2016 2.00 COMPZN RPCOMP TRIP P POOH from 6485'to 225' 6,485.0 225.0 05:15 07:15 11/16/2016 11/16/2016 2.75 COMPZN RPCOMP BHAH P Rack back drill collars. Lay down 225.0 233.0 07:15 10:00 clean out BHA and empty boot baskets. Clear rig floor. Mobilize tools to the rig floor. Make up overshot and fishing BHA Page 16/22 Report Printed: 11/28/2016 Operations Summary (with Timelog Depths) 1Y-05 QmocoPhillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End.Depth(ftKB) 11/16/2016 11/16/2016 1.25 COMPZN RPCOMP TRIP P RIH from 233'to 6414' 233.0 6,414.0 10:00 11:15 11/16/2016 11/16/2016 0.50 COMPZN 'RPCOMP FISH P Break circulation and wash down. 6,414.0 6,488.0 11:15 11:45 Engage fish at 6497'. Pull seals out of packer with 170k. Pick up 6488 11/16/2016 11/16/2016 0.75 COMPZN RPCOMP CIRC P Circulate bottoms up 6,488.0 6,488.0 11:45 12:30 11/16/2016 11/16/2016 1.50 COMPZN RPCOMP TRIP P POOH from 6488'to 233' 6,488.0 233.0 12:30 14:00 11/16/2016 11/16/2016 3.25 COMPZN RPCOMP BHAH P Rack back drill collars. Lay down jars 233.0 225.0 14:00 17:15 and accelerators. Lay down seal assembly,pup joint,GLM and cut joint. Total length of fish=37.95'. Clear rig floor and mobilize tools to the rig floor. Make up clean out BHA 11/16/2016 11/16/2016 1.50 COMPZN WELLPR TRIP P Trip in the hole from 225'to 6502' 225.0 6,502.0 17:15 18:45 11/16/2016 11/16/2016 0.25 COMPZN WELLPR WASH P Wash down from 6502'to 6525'. Top 6,502.0 6,525.0 18:45 19:00 of packer at 6515'dpm. 11/16/2016 11/16/2016 1.00 COMPZN WELLPR CIRC P Pump sweep and circulate bottoms up 6,525.0 6,525.0 19:00 20:00 11/16/2016 11/16/2016 1.00 COMPZN WELLPR SLPC P Slip and cut 71'of drilling line 6,525.0 6,510.0 20:00 21:00 11/16/2016 11/16/2016 0.50 COMPZN WELLPR SVRG P Service drawworks,top drive,iron 6,510.0 6,510.0 21:00 21:30 roughneck 11/16/2016 11/16/2016 1.25 COMPZN WELLPR TRIP P POOH from 6510'to 258' 6,510.0 258.0 21:30 22:45 11/16/2016 11/17/2016 1.25 COMPZN WELLPR BHAH P Stand back drill collars and lay down 258.0 0.0 22:45 00:00 clean out BHA. Clear rig floor 11/17/2016 11/17/2016 0.50 COMPZN WELLPR BHAH P Make up Baker Retriev-a-matic packer 0.0 35.0 00:00 00:30 and model G Lock-set Retrievable Bridge plug 11/17/2016 11/17/2016 0.50 COMPZN WELLPR TRIP P RIH from 35'to 516' 35.0 516.0 00:30 01:00 11/17/2016 11/17/2016 0.50 COMPZN WELLPR PRTS P Set Baker Retriev-a-matic packer with 516.0 516.0 01:00 01:30 center of seal element at 516', Test IA to 1000 psi to verify that Baker Retriev -a-matic packer was functioning. Release Baker Retriev-a-matic packer 11/17/2016 11/17/2016 2.00 COMPZN WELLPR TRIP P RIH from 516'to 5493' 516.0 5,493.0 01:30 03:30 11/17/2016 11/17/2016 0.75 COMPZN WELLPR PRTS P Set Baker Retriev-a-matic packer with 5,493.0 5,493.0 03:30 04:15 center of seal element at 5493', Test IA to 3000 psi for 10 minutes--GOOD TEST. Release Baker Retriev-a-matic packer 11/17/2016 11/17/2016 0.25 COMPZN WELLPR TRIP P RIH from 5493'to 5970' 5,493.0 5,970.0 04:15 04:30 Page 17/22 Report Printed: 11/28/2016 kw • • Operations Summary (with Timelog Depths) 1Y-05 Coriilips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/17/2016 11/17/2016 1.50 COMPZN WELLPR PRTS P Set Retriev-a-matic packer with center 5,970.0 5,587.0 04:30 06:00 of seal element at 5970'. Attempt to pressure test to 3000 psi--TEST FAILED. Set Retriev-a-matic packer with center of seal element at 5873'. Attempt to pressure test to 3000 psi--TEST FAILED. Set Retriev-a-matic packer with center of seal element at 5780'. Attempt to pressure test to 3000 psi--TEST FAILED. Set Retriev-a-matic packer with center of seal element at 5682'. Attempt to pressure test to 3000 psi--TEST FAILED. Set Retriev-a-matic packer with center of seal element at 5587'. Attempt to pressure test to 3000 psi--GOOD TEST. 11/17/2016 11/17/2016 2.75 COMPZN WELLPR TRIP P POOH from 5587'to 35' 5,587.0 35.0 06:00 08:45 11/17/2016 11/17/2016 1.25 COMPZN WELLPR BHAH P Lay down Retriev-a-matic packer and 35.0 0.0 08:45 10:00 model G Lock-set Retrievable Bridge Plug. Clear rig floor 11/17/2016 11/17/2016 1.00 COMPZN RPCOMP RURD P Rig up to run packer. Mobilize 0.0 0.0 10:00 11:00 completion equipment to rig floor 11/17/2016 11/17/2016 2.50 COMPZN RPCOMP PUTB P Make up Lower completion: Seal 0.0 340.0 11:00 13:30 assembly,locator sub,BX profile, blast rings,GLM,profile nipple,liner hanger and liner top packer. 11/17/2016 11/17/2016 0.25 COMPZN RPCOMP RURD P Rig down tubing tongs 340.0 340.0 13:30 13:45 11/17/2016 11/17/2016 1.50 COMPZN RPCOMP TRIP P RIH with lower completion on 4"14#, 340.0 4,134.0 13:45 15:15 S-135,XT-39 drillpipe from 340'to 4134'. 11/17/2016 11/17/2016 1.75 COMPZN RPCOMP TRIP T Rig up tubing tongs and POOH from 4,134.0 249.0 15:15 17:00 4134'to 11/17/2016 11/17/2016 1.00 COMPZN RPCOMP OTHR T Inspect nipple and verify RHC plug in 249.0 249.0 17:00 18:00 place 11/17/2016 11/17/2016 2.00 COMPZN RPCOMP TRIP P RIH from 249'to 6518' 249.0 6,499.0 18:00 20:00 11/17/2016 11/17/2016 0.50 COMPZN RPCOMP OTHR P Pick up single and RIH while pumping 6,499.0 6,518.0 20:00 20:30 slowly. Pressure increased to 450 psi at 6518'. Shut off pump and RIH to no -go at 6524'. Verify tally. Pick up to 6518' 11/17/2016 11/17/2016 1.50 COMPZN RPCOMP CIRC P Circulate bottoms up. Pump 30 bbl 6,518.0 6,518.0 20:30 22:00 corrosion inhibitor and displace with 60 bbl seawater 11/17/2016 11/17/2016 1.00 COMPZN RPCOMP PACK P Drop setting ball and allow to fall for 6,518.0 6,183.0 22:00 23:00 10 minutes. Pressure up to 2000 psi to set liner hanger. Bleed off pressure and rotate off liner and mechanically set liner top PACKER with 25k. TOL @ 6183' Monitor well 11/17/2016 11/18/2016 1.00 COMPZN RPCOMP TRIP P POOH from 6183'to 3945' 6,183.0 23:00 00:00 11/18/2016 11/18/2016 1.00 COMPZN RPCOMP TRIP P Continue to POOH w/Liner setting 3,945.0 45.0 00:00 01:00 tool from 3,945-ft to 45-ft Page 18/22 Report Printed: 11/28/2016 • • ' Operations Summary (with Timelog Depths) 1Y-05 Co ocondltips r.. Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time : End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/18/2016 11/18/2016 0.25 COMPZN RPCOMP BHAH P Lay down Liner Running assembly as 45.0 0.0 01:00 01:15 per Baker 11/18/2016 11/18/2016 0.50 COMPZN RPCOMP BHAH P Bring 7"Retriev-a-Matic test packer to 0.0 17.0 01:15 01:45 rig floor and MU for RIH to 17-ft. 11/18/2016 11/18/2016 2.25 COMPZN RPCOMP TRIP P RIH w/Test packer from 17-ft to 6,185 17.0 6,185.0 01:45 04:00 -ft and tag up. 11/18/2016 11/18/2016 1.50 COMPZN RPCOMP PRTS P Drop ball and Rod and allow for 10 6,185.0 6,172.0 04:00 05:30 minute drop time. Set test packer at 6,183-ft. Pressure up to 3,000 psi, bleeding off with flow at the flow line. Pull packer up 3-ft to 6,180-ft and re- test,still leaking. Pull packer up 8-ft to 6,172-ft and reset. Pressure up to 3,000 psi,still leaking with returns up the annulus. 11/18/2016 11/18/2016 0.50 COMPZN RPCOMP TRIP P POOH from 6,172-ft to 5,500-ft 6,172.0 5,500.0 05:30 06:00 11/18/2016 11/18/2016 1.50 COMPZN RPCOMP PRTS T Set test packer at 5,455-ft(Loss=75 5,500.0 5,500.0 06:00 07:30 psi every 5 minutes),POOH to 5,471- ft,-Test down IA again to 3,000 psi- failed test same result. Release packer and lower to 5,500-ft,Circulate at 4 bpm @ 225 psi. Reset Packer at 5,500-ft and Pressure test to 3,000 psi.with lower pressure guage on DP. Gain on DP was the same as the loss on the IA. Bleed off pressure and release packer. 11/18/2016 11/18/2016 1.75 COMPZN RPCOMP TRIP T POOH from 5,500-ft to 17-ft. 5,500.0 17.0 07:30 09:15 11/18/2016 11/18/2016 0.75 COMPZN RPCOMP BHAH T Lay down RH Set Retriev-A-Matic test 17.0 17.0 09:15 10:00 packer and Pick up LH Set Retriev-A- Matic test packer and RIH to 17-ft. 11/18/2016 11/18/2016 1.00 COMPZN RPCOMP TRIP T RIH W/test packer#2 to 960-ft,set 17.0 960.0 10:00 11:00 and func test-Good test-5 min.for 30 minutes. 11/18/2016 11/18/2016 1.75 COMPZN RPCOMP TRIP T Continue to RIH w/Test packer from 960.0 6,145.0 11:00 12:45 960-ft to 6,145-ft 115k Up wt, 105K Dn wt. 11/18/2016 11/18/2016 1.25 COMPZN RPCOMP PRTS T Set void between the Test Packer w/ 6,145.0 6,175.0 12:45 14:00 COE @ 6,175-ft and Liner Top at 6,183-ft to 3,000 psi for 30 Minutes- Good test. Release Packer. 11/18/2016 11/18/2016 0.50 COMPZN RPCOMP TRIP P POOH from 6,175-ft to 5,505-ft, PU 6,175.0 5,524.0 14:00 14:30 working jt and RIH to 5,524-ft. 11/18/2016 11/18/2016 1.00 COMPZN RPCOMP PRTS P Test void between the Test Packer w/ 5,524.0 5,524.0 14:30 15:30 COE @ 5,524-ft and surface to 3,000 psi for 30 Minutes-Good test. Release Packer. 11/18/2016 11/18/2016 1.50 COMPZN RPCOMP TRIP P POOH from 5524'to 963' 5,524.0 963.0 15:30 17:00 11/18/2016 11/18/2016 1.00 COMPZN RPCOMP PULD P Lay down 4"drill pipe from 963'and 963.0 0.0 17:00 18:00 lay down test packer. Clear rig floor 11/18/2016 11/18/2016 0.50 COMPZN RPCOMP RURD P Rig up tubing tongs and handling 0.0 0.0 18:00 18:30 equipment 11/18/2016 11/18/2016 0.50 COMPZN RPCOMP SVRG P Service drawworks,blocks and 0.0 0.0 18:30 19:00 topdrive. 11/18/2016 11/18/2016 1.00 COMPZN RPCOMP PUTB P Make up 5-1/2"scab liner 0.0 709.0 19:00 20:00 Page 19/22 Report Printed: 11/28/2016 • 0 r ,,g 5 Operations Summary (with Timelog Depths) 1Y-05 %Phillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity.Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/18/2016 11/18/2016 2.00 COMPZN RPCOMP RUNL P RIH with 5-1/2"scab liner on 4" 709.0 6,180.0 20:00 22:00 drillpipe.from 709'to 6180 11/18/2016 11/18/2016 0.50 COMPZN RPCOMP PACK P Break circulation and sting into setting 6,197.0 6,183.0 22:00 22:30 sleeve @ 6185'. Shut off pump and slack off. No-go at 6193'. Pick up to 6183'to expose seals 11/18/2016 11/18/2016 0.50 COMPZN RPCOMP CRIH P Pump 22 bbl of inhibitted brine and 6,183.0 6,183.0 22:30 23:00 displace with 75 bbl seawater 11/18/2016 11/19/2016 1.00 COMPZN RPCOMP PACK P RIH to no-go and pick up to 6191'. 6,183.0 6,191.0 23:00 00:00 Drop setting ball and allow to fall. Pressure up to 2500 psi to set liner hanger. Rotate off of liner and set liner top packer with 25k down weight. TOL at 5490' 11/19/2016 11/19/2016 1.00 COMPZN RPCOMP PRTS P Rig up and pressure test casing to 6,191.0 6,191.0 00:00 01:00 3000 psi for 30 minutes- good test. Rig down test equipment 11/19/2016 11/19/2016 3.50 COMPZN RPCOMP TRIP P POOH 6,191.0 0.0 01:00 04:30 11/19/2016 11/19/2016 0.50 COMPZN RPCOMP PULD P Laydown liner setting tool. 0.0 0.0 04:30 05:00 11/19/2016 11/19/2016 1.00 COMPZN RPCOMP BHAH P Make up cleanout BHA 0.0 213.0 05:00 06:00 11/19/2016 11/19/2016 1.00 COMPZN RPCOMP TRIP P RIH with cleanout BHA to 1177' 213.0 1,177.0 06:00 07:00 11/19/2016 11/19/2016 3.00 COMPZN RPCOMP MILL P Wash and mill from 1177'to 1687' 1,177.0 1,687.0 07:00 10:00 11/19/2016 11/19/2016 1.00 COMPZN RPCOMP TRIP P POOH from 1687'to 213' 1,687.0 213.0 10:00 11:00 11/19/2016 11/19/2016 0.75 COMPZN RPCOMP BHAH P Lay down cleanout BHA 213.0 0.0 11:00 11:45 11/19/2016 11/19/2016 0.75 COMPZN RPCOMP PRTS P Close blind rams and pressure test 0.0 0.0 11:45 12:30 casing to 3000 psi for 30 minutes. Recorded test on Martin Decker chart recorder. Good test 11/19/2016 11/19/2016 4.50 COMPZN RPCOMP PUTB P Mobilize Weatherford patch running 0.0 369.9 12:30 17:00 equipment to the rig floor. Make up 3 stands of 3-1/2"tubing and stand back in the derrick. Make up 10 joints of 5- 1/2"patch. Make up inner string and run inside patch. 11/19/2016 11/19/2016 1.00 COMPZN RPCOMP RUNL P Run in hole with 5-1/2"patch(liner)on 369.9 1,570.0 17:00 18:00 4"drillpipe to 1570' 11/19/2016 11/19/2016 1.50 COMPZN RPCOMP OTHR P Pressure up on drillpipe to 3900 psi to 1,570.0 1,280.0 18:00 19:30 set patch. Swedge through patch. Maximum overpull=95 kips 11/19/2016 11/19/2016 0.50 COMPZN RPCOMP PULD P Lay down 4"drillpipe from 1280'to 1,280.0 369.0 19:30 20:00 369' 11/19/2016 11/19/2016 1.00 COMPZN RPCOMP PULD P Lay down Weatherford patch running 369.0 0.0 20:00 21:00 tools and stand back 3 stands of 3- 1/2"tubing. 11/19/2016 11/19/2016 0.50 COMPZN RPCOMP RURD P Rig down Weatherford tongs and 0.0 0.0 21:00 21:30 equipment 11/19/2016 11/19/2016 0.50 COMPZN RPCOMP TRIP P RIH with 8 stands of 4"14.0 Ib,S-135, 0.0 740.0 21:30 22:00 XT-39 drillpipe from the derrick 11/19/2016 11/19/2016 0.50 COMPZN RPCOMP PULD P Lay down 24 joints of 4"14.0 Ib,S-135 740.0 0.0 22:00 22:30 XT-39 drillpipe Page 20/22 Report Printed: 11/28/2016 • • 0;!,;-er:-,::::--- „,.. Operations Summary (with Timelog Depths) 1Y-05 ConocoPlaillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/19/2016 11/20/2016 1.50 COMPZN WHDBOP WWWH P Attempting to pull wear ring. Rig up 0.0 0.0 22:30 00:00 Stack-Washer and and wash wear ring 11/20/2016 11/20/2016 1.50 COMPZN RPCOMP WWWH P Attempt to pull wear ring. Rinse stack 0.0 0.0 00:00 01:30 with stack washer. Pull wear ring and rig down running tool 11/20/2016 11/20/2016 1.50 COMPZN RPCOMP RURD P Rig up to run upper completion 0.0 0.0 01:30 03:00 11/20/2016 11/20/2016 3.25 COMPZN RPCOMP PUTB P Run 3-1/2"upper completion to 2184', 0.0 2,184.0 03:00 06:15 collars of 3-1/2"EUE tubing hanging up on casing patch. 11/20/2016 11/20/2016 1.75 COMPZN RPCOMP PULL T POOH laying down 3-1/2"9.3#,L-80 2,184.0 810.0 06:15 08:00 EUE completion tubing. 11/20/2016 11/20/2016 1.00 COMPZN RPCOMP OTHR T Off-load with 3-1/2"IBTM tubing. 810.0 810.0 08:00 09:00 11/20/2016 11/20/2016 0.50 COMPZN RPCOMP SVRG P Service drawworks,top drive and 810.0 810.0 09:00 09:30 roughneck 11/20/2016 11/20/2016 5.00 COMPZN RPCOMP OTHR T Load shed with 3-1/2"9.2#,L-80 IBTM 810.0 810.0 09:30 14:30 tubing. Remove thread protectors, tally and drift. 11/20/2016 11/20/2016 5.00 COMPZN RPCOMP PUTB T Pick up 3-1/2",9.3#, L-80 IBTM tubing 810.0 6,213.0 14:30 19:30 to 6232' 11/20/2016 11/20/2016 0.50 COMPZN RPCOMP HOSO P Rig up to circulate. Wash down and 6,213.0 6,231.0 19:30 20:00 engage seals at 6213.5'. RIH and fully locate at 6231.53' 11/20/2016 11/20/2016 1.00 COMPZN RPCOMP HOSO P Lay down three joints of tubing. Make 6,231.0 6,231.0 20:00 21:00 up spaceout pups(10.81', 10.81',and 2.26'),full joint,hanger and landing joint. 11/20/2016 11/20/2016 1.50 COMPZN RPCOMP CIRC P Reverse circulate 245 bbl inhibitted 6,231.0 6,231.0 21:00 22:30 seawater down annulus. 11/20/2016 11/20/2016 0.50 COMPZN RPCOMP HOSO P Land tubing hanger and RILDS 6,231.0 6,231.0 22:30 23:00 11/20/2016 11/21/2016 1.00 COMPZN RPCOMP PRTS P Pressure test tubing to 3500 psi for 30 6,231.0 6,231.0 23:00 00:00 minutes. Test recorded on chart recorder. Bled tubing to 2000 psi and pressure tested the IA to 3000 psi for 30 minutes. Test recorded on chart recorder. 11/21/2016 11/21/2016 0.75 COMPZN RPCOMP PRTS P Continue to integrity test the IA at 6,231.0 00:00 00:45 3,000 psi, Bleed IA to Zero and Bleed TBG pressure to Zero. Shear out @ 2,100 psi. Obtain circ rate through valve @ 1 bpm @ 600 psi 11/21/2016 11/21/2016 0.50 COMPZN RPCOMP RURD P RD Testing equipment,remove 00:45 01:15 landing joint. Drain stack 11/21/2016 11/21/2016 0.50 COMPZN WHDBOP MPSP P Install BPV and Test in the 1,000 psi 01:15 01:45 for 10 minutes. 11/21/2016 11/21/2016 1.50 COMPZN WHDBOP NUND P Nipple Down BOPE while conducting 01:45 03:15 Sim ops-Un-loading completion tubular's,Cleaning Pits,Flush and blow down pumps. Dismantle mud pumps and Freeze protect for rig move. 11/21/2016 11/21/2016 2.25 COMPZN WHDBOP NUND P NU Adapter spool and test seals @ 03:15 05:30 250/5,000 psi for 10 minutes. NU 3- 1/8"5M Tree. 11/21/2016 11/21/2016 0.25 COMPZN WHDBOP MPSP P Remove BPV and Install test plug. 05:30 05:45 Page 21/22 Report Printed: 11/28/2016 • • Operations Summary (with Timelog Depths) a &Wens ; 1Y-05 Como:W itltps Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/21/2016 11/21/2016 1.50 COMPZN WHDBOP PRTS P Fill tree with diesel and test tree @ 05:45 07:15 250/5,000 psi for 5 minutes- small bleed off with no visual leaks. 11/21/2016 11/21/2016 0.75 COMPZN RPCOMP RURD P RU Little Red Services and PT lines 07:15 08:00 250/5,000 psi-Good Test 11/21/2016 11/21/2016 1.50 COMPZN RPCOMP FRZP P Freeze Protect well w/75 bbls of 08:00 09:30 diesel @ 2 bpm @ 1,200 ICP and 1,650 FCP. RD LRS, Allow well to swap TBG x IA.. Bleed off balanced pressure of 200 psi to Zero. 11/21/2016 11/21/2016 0.25 COMPZN WHDBOP MPSP P Install 3"IS-A with dry rod 09:30 09:45 11/21/2016 11/21/2016 1.00 COMPZN MOVE OTHR P Blow down and Rig down freeze 09:45 10:45 protect lines and dress tree. TBG PSI=0, IA PSI=0,OA PSI=0 Release Doyon 141 at 10;30 hrs on 11 -21-16 Page 22/22 Report Printed: 11/28/2016 r�� 1; KUP I� � 1Y-05 ConocoPhillips ' \ Well Attribute Max Angle TD Alaska Inc Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Garwco?Fdllips 500292096600 KUPARUK RIVER UNIT INJ 38.53 7,100.00 7,266.0 °°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1Y-05,12121/20163:1242 PM SSSV:NONE Last WO: 10/30/2016 35.01 6/1/1983 Vertical schematic.{actuaQ Annotation Depth(ftKB) End Date 'Annotation Last Mod By End Date F ,� Last Tag:SLM 6,598.0 1/14/2015 Rev Reason:WO,GLV CIO 8 PULL AVA pproven 12/20/2016 HANGER;26.1 la.,I,t:a) IICasing Stnngs ',.��,' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread R 16 15.062 31.0 73 73.0 e1 ;49 CasingUCEcrOiption OD(i 9 5 8 ID gn8.835 Top(ftKB)30 9 Set Depth(ftKB) Set Depth 2,204 9 40.00 J H-40 WELDED "`r't"'L"„'n""""„("",r„'p(""„ �'� � A TIEBACKscri tion OD 7 6276 0 WtlLen(I...Grade Top Thread ell,,,u4 M .. C 7 ftKB Set Depth ftKB Set De th ND... { 40.00 J-55 BTC WtlLen(I.. Grade Top Thread CONDUCTOR;31.o-73.0 �' •' 27.8 1,720.6 1,720.6 26.00 L-80 TCII Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len g...Grade Top Thread SUBSIDENCE CMT JOB;31.0 ." PRODUCTION 7 6.276' 1,715.6 7,236.0 6,664.4 26.00 K-55 BTC ft SUBSIDENCECi.1TJ09;311.0 ablR1 • ' i Tubing Strings ftKB , - .4 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection 6 ++ Upper Completion 31/2 2.992 26.1 6,229.3 5,834.8 9.20 L-80 IBT-M VRWO 2016 t W Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top not(°) Item Des Com (in) • 26.1 26.1 0.04 HANGER FMC TC-1A-EN,6x3-1/2 EUE API SEAL W/IS-A bpvg 2.992 ! i 6,210.9 5,818.5 27.85 LOCATOR LOCATOR SUB 2.992 1 1 6,211.4 5,818.9 27.85 SEAL ASSY BAKER GBH-22 80-40 SEAL ASSEMBLY 2.992 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection WFT Expandable 6.235 5.433 1,280.1 1,570.0 1,570.0 60 Patch RWO 2016 Completion Details TIEBACK 278-1,720 6 Nominal ID I Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com (in) 1,280.1 1,280.0 0.54 MCL Top Cap WFT 5-1/2"Exp.Casing Patch Covering Cmt Perfs 5.433 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ibttt) Grade Top Connection SURFACE;30.9-2,205.1 5-1/2 Scab Liner 5 1/2 4.950 5,490.3 6,192.0 5,801.8 15.50 TN-110 H563 RWO 2016 Completion Details it GAS LIFT;5,4315 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(1) Item Des Com (in) 5,490.3 5,172.3 25.71 SETTING SLV ZXP Setting sleeve 5.240 111 5,501.9 5,182.7 25.60 PACKER HD Liner Top Packer 4.290 SETTING SLV;5,490.3 PACKER;5,501.a 5,509.4 5,189.5 25.61 HANGER DG Flex-Lock Liner Hanger 4.390 HANGER;5,509.4 i 5,519.3 5,198.4 25.62 XO 5",15#,BTC box x 5-1/2"H563 Pin Cross over 4.870 5,520.8 5,199.8 25.62 Liner 5-1/2",15.5#,TN-110 SS Hydril 563 Casing pup joint 4.950 6,180.2 5,791.3 27.65'XO 5-1/2"H563 x 5"BTC Pin Cross over 4.950 6,181.0 5,792.0 27.65 SEAL ASSY 5.25"Bullet Seal Assembly 4.370 SEAL ASSY;6,181 0, ,., Description String Ma...ID(in) Top(ftKB) Set Depth(ft..JSet Depth(ND)(...Wt(Ib/ft) Grade Top Connection r SETTING SLV;6,183.2 iii I C-Sand Selective 31/2 2.992 6,183.2 6,524.0 6,091.1 9.30 L-80 EUE Ii RWO 2106 PACKER;6,194.9 s - - Completion Details HANGER;6,202.5 I I', Nominal ID lop(ftKB) Top(ND)(ftKB) Top Incl(°l Item Des Com (in) LOCATOR,6,2106 ilE 6,183.2 5,794.0 27.67 SETTING SLV ZXP Setting sleeve 5.260 (ILII SEAL ASSY;8211 4 T T 6,194.9 5,804.4 27.76 PACKER HD Liner Top Packer 4.320 SBE',6,,214.1, 4-._-� 6,202.6 5,811.1 27.81 HANGER DG Flex-Lock Liner 4.380 al 6,214.1 5,821.3 27.87 SBE 5",H521 80-40 Seal Bore Extension 4.000 6,233.3 5,838.3 27.96 XO Reducing 5",159,H521 x 3.5"EUE crossover 2.990 NIPPLE,6,289.5 6,289.6 5,887.9 28.23 NIPPLE 3-1/2"x 2.813"DS Nipple 2.813 N. 6,361.5 5,951.0 29.20 Blast Joints Baker Blast Joints(6) 2.992 6,502.0 6,072.3 31.45 SLIDING SLV Baker CMU w/2.813"BX Profile 2.992 6,516.3 6,084.6 31.69 LOCATOR Baker Locator Sub 2.992 GAS LIFT;6,342.5 6,517.5 6,085.5 31.71 SEAL ASSY Baker GBH-22 80-40 seal assembly 2.980 Tubing Description String Ma...ID(in) Top(MB) Set Depth(ft..i Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection IPERF;6,381 0-6,472.0PACKER ASSY 3 1/2 2.992 6,522.3 6,551.3 6,114.2 9.30 J-55 BTC. Completion Details Nominal ID AIN lop(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) SLIDING SLV;6,502.0 'AIN 6,522.3 6,089.6 31.79 PACKER BAKER FB-1 PACKER 4.000 111 LOCATOR;6,516.3 NIL 6,524.8 6,091.7 31.83 SBE BAKER SEAL BORE EXTENSION ' 3.000 SEAL ASSY;6,517.5 6,539.8 6,104.5 32.08 NIPPLE CAMCO D NIPPLE NO GO 2.750 PACKER;6,522.3 6,550.5 6,113.5 32.25 SOS CAMCO SHEAR OUT SUB,ELMD TTL @ 6554'during 3.000 LDL on 6/2/1990 SBE;6,524.8 - Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(In) 6,785.0. 6,307.4 36.19 FISH 5"Geo-Vann 365 88'long 6/13/1983 0.000 NIPPLE;6,539.8 Perforations 8 Slots SOS,6.550.5 Mir Shot Den Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 6,381.0 6,472.0 5,968.0 6,046.7 C-2,C-3,C-4, 6/13/1983 - 12.0 (PERF 5"Geo-Vann,120 deg. IPERF;6,603.06,607.0 C-1,1Y-05 Phasing 6,603.0 6,607.0 6,157.7 6,161.1 A-5,1Y-05 6/13/1983 12.0 (PERF 5"Geo-Vann,120 deg. IPERF;6,618.06,638.0 - Phasing - 6,618.0 6,638.0 6,170.3 6,186.9 A-4,1Y-05 6/13/1983 12.0 IPERF 5"Geo-Vann,120 deg. (PERF;6,657.0-6,670.0---. Phasing FISH,6,785.0 * 6,657.0 6,670.0 6,202.7 6,213.5 A-3,1Y-05 6/13/1983 12.0 IPERF 5"Geo-Vann,120 deg. Phasing PRODUCTION;1,715.0-7,236.0 • KUP I 1Y-05 ConocoPhillips Alaska<Inc. CAraCOPhilips <•• 1Y-03,12120/20163:12:42 PM Veronal schematic(actual) HANGER;26.1 kill III Cement Squeezes Top(TVD) Btm(TVD) Top(fKB) Btm(ttKB) (0KB) (kKB) Des Start Date Com j ] u . 31.0 1,350.0 31.0 1,350.0 SUBSIDENCE 11/13/201 CMT 9-5/8"x 7"ANN TO SURFACE CMT JOB 6 Mandrel Inserts CONDUCTOR;31.0-73.0- lk St Vl ati SUBSIDENCE CMT JOB;31.0 e� �,, s 18<8 ey { N Top(TVD) Valve Latch Port Size TRO Run SUBSIDENCE CMT JOB;31.0 �ysti , Nj N Top(kKB) (0KB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 5,431.5 5,119.4 CAMCO KBG 2- 1 INJ DMY BTM 0.000 0.0 11/28/2016 9 `' 2 6,342.5 5,934.4 CAMCO MMG 11/2 INJ DMY RK 11/17/2016 1.6 NO 1 • Notes:General&Safety End Date Annotation 1 10/22/2010 NOTE.View Schematic w/Alaska Schematic9-0 1 l . TIEBACK;27.&1,7206 11 11 SURFACE;30.9-2,205.1 1 II GAS LIFT;5,431.5 SETTING SLV;5,490.3 l PACKER;5,501.9 HANGER,5,509.4 .I • ! SEAL ASSY;6,181.01 - := - O ao fcrO ° ~> c ,,,,?w `J L h°"m ° " °C13 4- �al, 0�J � y 4-, '" ° Q1 E > 'n C�� O O e- ra r 0 N0 U_ v a` a +, r • o0 0 „ 0 !o co f0 <o co CO co cc (c <c cc cc cc Nci, o a m J C Q > > > > > > > > 0 0 0 0 E -a (( J O O O O O O O O w Z Z Z Z Z Z Z Z Z Z Z Z 7- C C p V/L 1.0// N N o N O Z Q N M M in cO O N N ° O C r g 0 v .- cc r ° ° L ~ ( �•3 t0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 C v " U J J J J J J J J J J J J J 0D C 41.. U 0 W W W W W W W W W W W W W �n N 'C LL LL LL LL LL LL LL LL LL LL LL LL LL + 4) N N 13 0 J J J J J J J J J J J J J - jo > - tt Q Q Q Q Q Q Q Q Q Q Q Q Q a ^ C w "_ OG Cr) Z Z Z Z Z Z Z Z Z Z Z Z Z v t v ° a LL LL LL LL LL LL LL LL LL LL LL LL LL fY c > N rte+ > J N y N ro CO .0 N u O r' v, a N u > U V. C _O OA c ca . O f- 2 T u c Z O a ~ > no a o 0 05 ,, z n: 1- Q v a C Q T G v � 'U � O WD aJ ao a = - = aJass Co ill SO W •- 0 .- (n •- 2 •- 0 So o G m O J O m O F3 W H 0 J Li_m a a !M g F O W cc 0 ' �; al co U W i'-'> )) V > 0 o 0 cal m03 ... . W i x g 0� 0 (Q 00 V a J J J J J J J J J J J J J a) tll 0 f ceJYreJYctre JYJYrecececec 1 01 E WWWWWUJUJWWWWWW W > > > > > > > > > > > > > r .tr Ln z Y Y Y Y Y Y Y Y Y Y Y Y Y O 0 > > > 0 0 0 0 > > > > > > +, w Q Q Q Q Q Q Q Q Q Q Q Q Q > pi.. LL a a a n. a s a a a a a a a A > > > > > > > > > > > > > .` U CI CC. Y Y Y Y Y Y Y Y Y Y Y Y Y C o OD N X n Liti �� W M M V c0 N- CO C) 1- . N M c0 CIS0 N N N N N N N N C a a a a a a a a r- e- C O 0 o 0 0 0 0 o o 0 0 o 0 0 0 y F...1) 0 O o O co o O co co O O co co co V .. LL LL LL LL LL LL LL LL O V 0 0 0 �n C � 0 F F F F F- 1- 1- 1- ao 0o co 00 00 L >" 0000000000000co )y 0 0 0 0 0 0 0 0 0 0 0 0 0 C 0 O ® N v Ul Z $ 0 0 0 0 0 0 0 0 0 0 .- o o c CD 0 0 0 0 0 0 0 0 0 0 0 C o pp CC a o0 0o co cc N in o )n ii) an o cc o u1 E L N c0 c0 c0 CD O) e- r- COa0 COa0 a0 c0 0 1f�1 O O T 0) M N O O CO C) M O U O O O O O O O O O O N O N N N N N N N N N N N N N N N L JO MM C) O M M M M M M O O C) v ,n p a a NNO O 000 ONNN ' � G1 O co O O O " . O O co O O O O O O O O O O y, 0 N C. �aa A C in u) U) U) U) u) in in in in in in in G u C =r) h" d f0 N L �++ E E cu > Z u cc c c 1.- 6J F + 2 Q i • I Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, November 15,2016 8:54 AM To: Beat,Andrew T; Loepp,Victoria T(DOA) Cc: Buck, Brian R; Kanady, Randall B;Wallace,Chris D(DOA) Subject: RE: PTD 183-087 1Y-05 RWO(extended scab liner) Andrew, The new strategy proposing using two patches as shown in the latest diagram is APPROVED. Also, in the future make sure you notify the AOGCC before you perforate casing if it wasn't specifically approved in the sundry. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC %AWED [tai A v' 2 g 201! 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com] Sent:Tuesday, November 15,2016 8:31 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com>; Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Subject: RE: PTD 183-087 1Y-05 RWO (extended scab liner) Guy, Great catch. No arguments from our side. Instead,we can set a patch over that interval and lower the scab liner back to its original depth as shown in the attached diagram. Let me know if this completion design works. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov) Sent: Monday, November 14,2016 5:02 PM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com>; 1 • Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Subject: [EXTERNAL]RE: PTD 183-087 1Y-05 RWO(extended scab liner) Andrew, My concerns are that the middle ZXP packer(at 6250 ft md) cannot be tested (at least not easily).Only the upper scab liner packer can be tested. If you have the scab liner all the way back to 1200 ft.there is no way to tell if fluids are migrating up that 5"X 7"annulus to the perf holes shot for cement circulating. This being a WAG well I have some concerns gas could find its way to the surface casing shoe and up OOA. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From:Schwartz,Guy L(DOA) Sent:Monday, November 14,2016 4:46 PM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Subject: RE: PTD 183-087 1Y-05 RWO Update Andrew, I have reviewed the proposal and have some questions for you. Give me a call. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Beat,Andrew T[mailto:Andrew.T.Beat@conocophillips.com] Sent: Monday, November 14,2016 3:19 PM To:Schwartz,Guy L(DOA)<guy.schwartz(a)alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Buck, Brian R<Brian.R.Buck@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Subject: PTD 183-087 1Y-05 RWO Update Guy/Victoria, This email is to update the state on operations that occurred over the weekend regarding the subsidence repair portion of the workover on 1Y-05 (added scope approval received on 11/3). 2 • • Over the weekend we attempted to pump cement through the stage tool to cement the new 7" back to surface.Shortly after we began,we packed off and could no longer circulate. In order to complete the 7"cement job,we were required to punch the 7"just above the stage tool and pump cement to surface through the perforations.We plan to extend our scab liner to^'100'above the 7" perforations to isolate the holes in the production casing.An updated schematic is attached. As described above,the new completion design has changed slightly with the scab liner top moving up to 1200' MD. Does the state approve moving the top of the scab liner to"'1200' MD? Please let me know if you have any questions. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office 3 onochillip P ' ' 1 Y-05 o KRU Injector Surface to -1.750' KB P&R Upper Selective Repaired 7" Casing with Sealing I w/ Scab Liner & Patch Overshot and Cemented to Surface PROPOSED **Patch to cover trom top casing punch i i to below 7"overshot** COMPLETION Well Details: API: 500292096600 PTD: 183-087 ' . . e (, / Wellhead: FMC Gen IV 5M Tree: FMC 3-1/8"5M Casing/Tubing Details: 16"62.5#H-40 Conductor to 73'MD 9-5/8"40#J-55 Surface to 2,205' MD 7"26#K-55 Production to 7,236'MD 3-1/2" 9.3#L-80 Tubing to 6,527'MD Misc Details: —5,090' —Top of Cement Max Inclination:38.53° Max Dogleg:4.07°/100' "•' Last Tagged Fill: 6,612'MD I= I Total Depth: 7,266' MD 5,800' — 5" x 7" Packer tPerforation Details: 6,381'-6,482'MD—C 1-4 Sands 6,603'-6,607' MD—A 5 Sand f - —6,060'- Production Casing Leak 6,618'-6,638' MD—A 4 Sand k 6,657'-6,670' MD—A 3 Sand I -6,250' - 5" x 7" Packer :AL - I". 1Camco DS Nipple w/ RHC Plug Body p Injection Mandrel \CSandPerfs ' Blast Joints 1 Sliding Sleeve • .E 6,522' - Existing FB-1 Packer • A Sand Perfs 1 I I [ i Date: November 15,2016 Drawn By: Andrew Beat 0z 1 1Y-05 çonocoPhiIIip KRU Injector 1,200' -5" x 7" Packer + c.5. P&R Upper Selective aL„c.` w/ Scab Liner Surface to -2,000' KBir `-'rr PROPOSED Repaired 7” Casing with Baker Sealing COMPLETION Overshot and Cemented to Surface 1 ....y1 Well Details: l .,`"-5- t _© {� API: 500292096600 : PTD: 183-087 Wellhead: FMC Gen IV 5M ' Tree: FMC 3-1/8"5M , Casing/Tubing Details: /' 16"62.5#H-40 Conductor to 73' MD 9-5/8"40#J-55 Surface to 2,205' MD 7"26#K-55 Production to 7,236'MD 3-1/2"9.3#L-80 Tubing to 6,527' MD ; Misc Details: : — .90' -Top of Cement Max Inclination: 38.53° , Max Dogleg:4.07°/100' '02 Last Tagged Fill: 6,612'MD i.c, .c.A6 / Total Depth: 7,266' MD i r/ Perforation Details: 6,381'-6,482' MD—C 1-4 Sands 6,603'-6,607' MD—A 5 Sand —6,060'- Production Casing Leak 6,618'-6,638' MD—A 4 Sand ; 6,657'-6,670'MD—A 3 Sand ; , s h _ i) 1.-- -5" x 7" Packer 4 A)-riS7 O P E-c-t<2ry , Camco DS Nipple w/ RHC Plug Body Injection Mandrel C Sand Perfs = I h Blast Joints / �. ■ 1 p i Sliding Sleeve I 3r,. 6,522' - Existing FB-1 Packer A Sand Perfs I- Date: November 3,2016 Drawn By: Andrew Beat Schwartz, Guy L (DOA) From: Buck, Brian R <Brian.R.Buck@conocophillips.com> Sent: Thursday, November 03, 2016 5:24 PM To: Schwartz, Guy L(DOA) Subject: RE: PTD 183-087: Deviation from Original Procedure Follow Up Flag: Follow up 0 Flag Status: Flagged 3 i Thanks Guy! Thank you, Brian Buck Completions and Workover Supervisor office:907-265-6826,cell:907-223-6320,home:907-868-4834,fax:918-662-6213;700 G St.,ATO-1500;Anchorage,AK 99501 From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Thursday, November 03, 2016 5:21 PM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Buck, Brian R<Brian.R.Buck@conocophillips.com>; Kanady, Randall B<Randall.B.Kanady@conocophillips.com> Subject: [EXTERNAL]Re: PTD 183-087: Deviation from Original Procedure Andrew, Approval to proceed with 7" casing cut and recovery as proposed. Pressure test new casing as we discussed. Regards, Guy Schwartz SCANNED MAR p 1.2017, AOGCC 907-301-4533 Sent from my iPhone On Nov 3, 2016, at 1:47 PM, Beat,Andrew T<Andrew.T.Beat@conocophillips.com>wrote: Guy, This is to notify the state of the deviation in submitted procedure for the rig workover on 1Y-05. We have encountered significant subsidence damage in the production casing and will be adding a subsidence repair to the original workover scope.An outline of the added steps is attached. We will resume the original scope once the subsidence repair has been completed. Let me know if you have any questions. Well: 1Y-05 PTD: 183-087 Sundry:316-487 i Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office <1Y-05 Sundry Scope Change Procedure.pdfy 2 1Y-05 Rig Workover P&R Selective w/Scab Liner (PTD#: 183-087) Current Status: Tubing has been pulled down to the pre-rig cut just above the production packer.An RBP has been set and tested in 7"above production packer. Scope Addition: Pull the damaged 7"casing,mill 9-5/8"casing to regain drift access,install new 7"casing and cement to surface. General Well info: Well Type: Injector MPSP: 1,851 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 2,460 psi/6,091'TVD(7.8 ppg EMW)measured on 06/19/2016 Wellhead type/pressure rating: FMC Gen II,7-1/16"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-IA failed-07/17/2006(Prod.Csg.leak above packer-Admin.App.to continue injection on 09/13/2006) MIT-T failed-07/14/2008(Packer leaking into upper selective-Ammended Amin.App.to continue injection on 10/29/2008) MIT-OA passed-07/08/2013 Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Proposed Procedure 1. R/U E-Line and perform caliper log and CBL from the RBP to surface to determine TOC in 7". 2. R/D E-Line. 3. MU RBP setting tools and RIB on DP.Set second RBP 500'below TOC.Pressure test from above to confirm set. 4. Dump 100'of sand on top of RBP.POOH racking back DP. 5. MU casing cutter on DP and RIH to top of sand.Tag top of sand to confirm top. 6. TOH to casing cut depth.Begin circulating and cut casing.Once a cut is confirmed,attempt to circulate through cut. a. Casing may swedge back into itself once cut because of compression and will not allow for circulation through cut.If circulaton cannot be obtain,TOH to the middle of the next full joint and cut again.Continue until circulation can be obtained. 7. Shut in the IA and pump diesel followed by heated seawater through casing cut and up the OA to displace the Artie Pack(gelled diesel)until returns are clean.Chase heated seawater with ambient seawater. 8. POOH with casing cutter racking back DP. 9. N/D BOPE and tubing head.N/U BOPE and test break to 500 psi. a. If 500 psi cannot be reached statically due to open surface casing shoe,perform a dynamic pressure test observing the flange for visible leaks. 10. MU casing spear BHA and spear production casing.POOH with casing laying it down. 11. In the event of multiple casing cuts,continue fishing casing until all sections have been removed. a. When the cut joint from the first casing cut is removed,discuss with engineer whether a dress of run on the stub downhole is possible or if the stub needs to be removed so that a triple connect can be used to tie back into original casing. 12. MU milling BHA and RIH checking for drift issues.If drift issues are observed,mill surface casing until able to cleanly drift BHA to production casing cut depth.POOH racking back DP. 13. Prepare to run new 7"production casing.RIH with casing and tie back into existing production casing.Land casing in slips and cut off excess. a. Tie back will be completed using either a triple connect or sealing overshot depending on how the first cut joints looks once removed.If dressing the stub off does not appear to be manageable,a triple connect will be used to thread back into the existing casing. 1 1Y-05 Rig Workover P&R Selective w/Scab Liner (PTD#: 183-087) 14. RU cementers and cementing equipment.Cement new production casing to surface. 15. N/D BOPE 16. N/U tubing head and BOPE.Test breaks to 250/3,000 psi. 17. RIH with RBP retrieval tools and pull first RBP.POOH racking back DP. 18. RIH and pull second RBP.POOH racking back DP. 19. Return to original RWO scope of pulling and replacing the selective as described in the original Sundry request. 2 tiOF Ty • • THE STATE Alaska Oil and Gas ofALASKA Conservation Commission z �= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 5-�� Fax: 907.276.7542 www.aogcc.alaska.gov Andrew BeaMA'' A, 0 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 Y-05 Permit to Drill Number: 183-087 Sundry Number: 316-487 Dear Mr. Beat: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 6ILA P444-754 Cathy P. oerster Chair ffet— DATED this to day of October, 2016. RBDMS U-- OCT 1 0 2016 RECE ED STATE OF ALASKA it ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 3 2016 APPLICATION FOR SUNDRY APPROVALS /o (6 / / 4. 20 AAC 25.280 AOGGC 1.Type of Request: Abandon U Plug Perforations❑ Fracture Stimulate H Repair Well U ' Operations shutdown[i Suspend ❑ Perforate H Other Stimulate ❑ Pull Tubing ❑✓ • Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑✓ ,, Other: Scab Liner n 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. • Exploratory H Development H 183-087'i 3.Address: Stratigraphic ❑ Service ❑ , 6,API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-20966-00 i 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 1Y-05 • Will planned perforations require a spacing exception? Yes ❑ No 2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025646 ' Kuparuk River Field/Kuparuk River Oil Pool i 11. PRESENT WELL CONDITION SUMMARY �( 1 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7266' 6688' • 7236' . • 6664' Ilr none none Casing Length Size MD •II Burst Collapse Structural Conductor 42' 16" 73' 73' Surface 2168' 9.625" 2203' 2203' Intermediate Production 7201' 7" 7234' 6663' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6381'-6472' , 5968'-6047' 4.5"x 3.5" J-55 6551' 6603'-6607' , 6158'-6161' 6618'-6638' • 6170'-6187' 6657'-6670' ' 6203'-6213' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV: CAMCO TRDP-1A SAFETY VALVE • MD=1791 TVD=1791 PACKER-CAMCO HRP-1-SP PACKER • MD=6250 TVD=5853 PACKER-BAKER FB-1 PACKER • MD=6522 TVD=6090 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development H Service E 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/15/2016 OIL H WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned H 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Andrew Beat @ 265-6341 Email Andrew.T.Beat@conocophillips.com Printed Name Andrew Beat 265-6341 Title Sr.Wells Engineer Phone Signature ADate /A L I/zo t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Er Mechanical Integrity Test V Location Clearance H Other: g0P i.e t tc, G v�nvl R✓ ��1'Cv'vi tr. � t- ed, / fp ZS OG �5 , r A 1 /V{ l5 c�r-4 va,, <d 16, 1 1 o w j� Glcc� r hr !d Glc/ 530 �bor � Post Initial Injection MIT Req'd? Yes No ❑ f .� to f`� p e r f it G 2 S• 1 2 <b Spacing Exception Required? Yes ❑ No / Subsequent Form Required: /0 —414 RBDMS 'U OCT 1 0 2016 APPROVED BY / / Approved by .l I SIGNER THE COMMISSION Date:l D0uI16N[For46'. cormui�-au1I e i $'VT Ii 31 1p140AVI I valW for 12 monll��rumLthe dale of approval. Attachments in Duplicate �Naf cgVl/' L /b/4 & V A 704 ,6 • • 11''"' • • ConocoPh i l l i ps Alaska ;,EP 23 2016 P.O. BOX 100360 rP'1G�, ANCHORAGE,ALASKA 99510-0360 4a,1 September 21,2016 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to work over Kuparuk Injector 1Y-05 (PTD# 183-087). This well had previously been granted Sundry Approval(315-505),however, scheduling prioritization caused this well to fall back to beyond the approval expiration date.The work scope remains the same and this application is a repeat of the request submitted in 2015. 1Y-05 was originally drilled and completed in 1983 as an"A"and"C"sand gas-lifted producer in Kuparuk. In 1994,it was converted to a MI WAG injector.In 2002,the well transferred to a water only injector.In 2006, a leak in the production casing was found at 6,060' MD,above the upper selective packer. An Administrative Approval to continue injecting was granted on 9/13/2006 after proving that injection was not entering IA above packer and was still restricted to permitted zones.In 2008,the tubing failed a MITT with the leak point located at the upper selective packer. The Administrative Approval was amended on 10/29/2008 to include authorization to submit a RST Water Flow Log(WFL)instead of a MITT to verify tubing integrity.The RST WFL showed that the packer was leaking fluid into the upper selective and not into the IA which included the production casing leak. 1Y-05 continued injection until 2/6/2012 when it was shut in for reservoir management and a water header repair. On 12/29/2014 during the post water header repair inspection, it was discovered that the IA pressure had slowly risen while the well was shut in.Due to this IA pressure anomaly,the well has remained shut in until it can be repaired. The proposed workover scope for 1Y-05 is to pull the existing 3-1/2"completion down to the lower most packer and install new 3-1/2"tubing with a 5-1/2"scab liner to isolate the production casing leak at 6,060'MD. The upper packer to be run with the scab liner will be set at approximately 5,850' MD(531' above top perforation)which does not comply with 20 AAC 25.412"The packer must be placed within 200 feet measured depth above the top of the perforations". The top of production cement,verified by a CBL performed June 4, 1983,was found at approximately 5,090' MD which is 760' above the upper packer.We wish a variance be granted from the regulation. This Sundry is intended to document the proposed work on the injection well, including the modifications to the production casing,request a variance from 20 AAC 25.412,and request approval to work over the well. If you have any questions or require any further information,please contact me at 265-6341. Sincerely, -4•114111L Andrew Beat Wells Engineer CPAI Drilling and Wells 1Y-05 Rig Workover P&R Selective w/Scab Liner (PTD#: 183-087) Current Status: This well was shut in on February 6,2012 and is currently waiting to be worked over to replace tubing and fix a production casing leak. Scope of Work: Pull the existing 3-1/2"tubing and upper packer,install a 5-1/2"scab liner with dual packers to isolate production casing leak. General Well info: Well Type: •'- MPSP: 1,851 • using 0.1 psi/ft gradient Reservoir Pressure/TVD: •1 psi/6,091' TVD(7.8 ppg EMW)measured on 06/19/2016 Wellhead type/pressure rating: FMC Gen IV,7-1/16"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-IA failed-07/17/2006(Prod. Csg. leak above packer-Admin.App.to continue injection on 09/13/2006) MIT-T failed-07/14/2008(Packer leaking into upper selective-Ammended Amin.App.to continue injection on 10/29/2008) MIT-OA passed-07/08/2013 Earliest Estimated Start Date: November 15,2016 Production Engineer: Kay Sind Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Pre-Rig Work 1. Inspect pad and work area for hazards. Complete the PJSM. 2. RU Slickline. Set plug in nipple reducer and set catcher sub on top of plug. 3. RIH and pull DV from GLM#9. 4. RD Slickine. 5. RU E-Line and RIH with radial cutting tool to perform the following cuts: a. Cut tubing above GLM#12 b. Include CCL, cut tubing between GLM#11 and blast rings c. Include CCL, cut tubing above upper packer 6. RD E-Line. 7. PT POs and FT LDS. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV.Reverse circulate seawater. Obtain SITP&SICP,if still seeing pressure at surface,calculate new KWF,weight up,and repeat circulation as necessary.Verify well is dead. 3. Set BPV,ND tree,NU BOPE&test to 250/3,000 psi. a. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe rams will be tested upon pulling the completion. 4. Pull BPV,screw in landing joint,BOLDS's,unland tubing hanger. 5. POOH laying down 3 '/2"tubing. a. On TOH,set a storm packer.RU Hydratight equipment,if necessary.NDBOP&Tbg head,grow casing, and land in slips.Replace IC packoffs.NU BOP&test.Pull storm packer. 6. RIH with overshot&grapple for 3-1/2"tubing,engage tubing stub and jar OEJ free. 1 • • 1Y-05 Rig Workover P&R Selective w/Scab Liner (PTD#: 183-087) 7. POOH standing back DP,lay down OEJ. 8. MU&RIH with fishing assembly for slickstick.Engage the slickstick and jar the upper selective packer free. POOH standing back DP. 9. MU overshot&grapple with Rattler,RIH to tubing stub, engage tubing stub and rattle blast rings section free. POOH standing back DP, lay down blast rings. 10. RIH with overshot&grapple for 3-1/2"tubing,engage tubing stub and jar seal assembly from the FB1 packer. POOH standing back DP. 11. RIH with Baker Extreme casing scraper and cleanout down to SBE. POOH standing back DP. 12. RU E-Line: RIH with 40 arm caliper for 7"casing,caliper from FB1 packer to surface.Determine best location to set new upper packers. 13. MU selective SLZXP packer assembly, SBE,blast joints,and sliding sleeve spaced out accordingly,RIH on DP to just above SBE. 14. Spot a balanced pill of corrosion inhibited brine in the tubing&IA from the existing SBE to above new packer. 15. Slowly cycle the charge pump and look for pressure increase or lack of returns as the seals engage. Shut down charge pump. Space out from fully located. 16. Pressure up DP to activate the pusher tool and set the packer. Release running tools. 17. POOH standing back DP. 18. MU straddle SLZXP packer and scab liner,RIH to tie-back sleeve,sting tie-back sleeve and space out from fully located.PT the IA to confirm packer is set.Release running tools. 19. POOH laying down DP. 20. RIH with new tubing to just above the SBE. 21. Slowly cycle the charge pump and look for pressure increases or lack of returns as the seals engage. Shut down charge pump. Space out,mark the pipe,and pull out of the SBE. 22. Install space out pups below the hanger,MU hanger.Load the IA with corrosion inhibited fluid. Land the hanger,RILDS. 23. PT the tubing,bleed tubing,PT the IA,and record.Bleed the IA to zero,then tubing.Ramp up the IA pressure quickly to shear the SOV. 24. Pull the landing joint,install BPV.Pressure test the BPV from below. 25. ND BOPE. 26. NU tree.Pull BPV and install tree test plug. Test tree and pull test plug. 27. Freeze protect well with diesel. Set BPV. 28. RDMO. Post-Rig Work 1. Pull ISA BPV. 2. RU Slickline: a. Pull ball&rod. b. Pull SOV and run DV. c. Pull plug body,catcher sub,and plug. d. Pull nipple reducer from D-nipple. 3. RD Slickline. 4. Reset well house(s)and flowlines of adjacent wells. 5. Turn well over to operations. 2 )0097 1Y-05 onocoPhillips11) KRU Infector P&R Upper Selective w/ Scab Liner Well Details: API: 500292096600 PROPOSED PTD: 183-087 COMPLETION Wellhead: FMC Gen IV 5M Tree: Calico 3-1/8"5M Casing/Tubing Details: 16"62.5#H-40 Conductor to 73' MD - 9-5/8"40#J-55 Surface to 2,205' MD 7"26# K-55 Production to 7,236' MD 3-1/2" 9.3#L-80 Tubing to 6,527' MD Misc Details: Max Inclination: 38.53° Max Dogleg: 4.07°/100' — - -5,090' -Top of Cement Last Tagged Fill: 6,612' MD Total Depth: 7,266' MD GLM - Circulation Point Perforation Details: 1 -5,850' - Packer 6,381'-6,482' MD-C 1-4 Sands 6,603'-6,607' MD-A 5 Sand ' -6,060'- Production Casing Leak 6,618'-6,638' MD-A 4 Sand 6,657'-6,670' MD-A 3 Sand tir -6,259' - Packer 1 ® o Camco DS Nipple IINDI Ma Injection Mandrels C Sand Perfs - 11 E ---1' Blast Joints I, ---- 0 bi Sliding Sleeve 6,522' - Existing FB-1 Packer 1-1 6,- A Sand Perfs - G Date: August 18,2015 I Drawn By: Andrew Beat S. n KUP INJ 0 1Y-05 ConocoPhillips ? Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(3 MD(ftKB) Act Btm(ftKB) (inn„,, „g;m , 500292096600 KUPARUK RIVER UNIT INJ 38.53. 7,100.00 7,266.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1Y-05,213201510:47:01 AM SSSV:TRDP _ Last WO: 9/23/1984 35.01 6/1/1983 Vertcal schematic(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ._.... ..__.... Last Tag:SLM 6,598.0 1/14/2015 Rev Reason:SET PLUG lehallf 2/3/2015 y Casing Strings HANGER;28.5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread' CONDUCTOR 16 15.062 31.0 73.0 73.0 62.50 H-40 WELDED 1.. Casing Description OD(in) ID(in) Top MKS) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 30.9 2,205.1 2,204.9 40.00 J-55 BTC ' " ora.' - 101I1Nai CCasing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ✓titin CONDUCTOR;31.0-73.0 7 N y�PRODUCTION 7 6.276 29.5 7,236.0 6,664.4 26.00 K-55 BTC Tubing Strings SAFETY VLV;1,791.1 -la" Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection a TUBING WO 31/2 2.992 28.5 6,527.3 6,093.9 9.20 J-55 BTC Completion Details GAS LIFT;t928.31. Nominal ID Top(ftKB) Top(ND)(ftKB) Top Ind(') Item Des Com (in) 28.5 28.5 0.05 HANGER FMC TUBING HANGER 3.500 1,791.1 1,791.1 1.32 SAFETY VLV CAMCO TRDP-1A SAFETY VALVE 2.813 6,226.9 5,832.7 27.93 SBR CAMCO OEJ SBR 2.937 SURFACE;30.9-2,205.1 r 6,249.6 5,852.7 28.04 PACKER CAMCO HRP-1-SP PACKER 2.867 GAS LIFT;2.247.0 6,363.4 5,952.7 29.22 BLAST RINGS BLAST RINGS(4) 2.992 al 6,521.4 6,088.9 31.77 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY-BOTTOM OF 3.937 GAS LIFT;2,810.1I. SEAL ASSY SITS INSIDE FB-1 PACKER Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection PACKER ASSY 31/2 2.992 6,522.3 6,551.3 6,114.2 9.30 J-55 BTC GAS LIFT;3,375.0 Completion Details Nominal ID GAS LIFT;3,940.9 a Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) il , 6,522.3 6,089.6 31.79 PACKER BAKER FB-1 PACKER 4.000 GAS LIFT;4,562.1 6,524.8 6,091.7 31.83 SBE BAKER SEAL BORE EXTENSION 3.000 • 6,539.8 6,104.5 32.08 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT;5,187.4 6,550.5 6,113.5 32.25 SOS CAMCO SHEAR OUT SUB,ELMD TTL @ 6554'during 3.000 LDL on 6/2/1990 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;5.687.1 Top(ND) Top Incl ■ Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 6,280.0 5,879.5 28.18 PLUG WEATHERFORD WRP 1/29/2015 GAS LIFT;6,186.3 _ 6,475.0 6,049.2 31.01 PATCH 12.3'MERLA TUBING PATCH 9/26/1993 2.375 6,539.8 6,104.5' 32.08 REDUCER AVA NIPPLE REDUCER w/AVA PROFILE 9/20/1993 2.250 SBR;6,226.9 _ PACKER;6,249.6 6,785.0 6,307A 1 36.19 FISH 1'5'Geo-Vann 365.88'long 6/13/1983 I 0.000 Perforations&Slots Shot Dens PLUG;6,280.0 Top(ND) Btm(TVD) (shots k Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zane Date t) Type Com 6,381.0 6,472.0 5,968.0 6,046.7 C-2,C-3,C-4, 6/13/1983 12.0 IPERF '5"Geo-Vann,120 deg. INJECTION;6,289.5 • C-1,1Y-05 Phasing 6,603.0 6,607.0- 6,157.7 6,161.1 A-5,1Y-05 6/13/1983 12.0 IPERF 5"Geo-Vann,120 deg. INJECTION;6,356.9 Phasing • 6,618.0 6,638.0 6,170.3 6,186.9 A-4,1Y-05 6/13/1983 12.0 IPERF '5"Geo-Vann,120 deg. Phasing (PERF;6,381.Ob,472.0 _._ H. 6,657.0 6,670.0• 6,202.7 6,213.5 A-3,1Y-05 6/13/1983 12.0 IPERF 5'Geo-Vann,120 deg. Phasing Mandrel Inserts PATCH;6,475.0 i Sat nl N Top(ND) Valve Latch Port Size TRO Run INJECTION;6.499.9 Top(ftKB) (ftKB) Make Model -OD(in) Sery Type Type (in) (psi) Run Date Com 1,928.3 1,928.2 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 9/23/1984 2 2,247.0 2,246.9 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000' 0.0 3/1/1988 •o• 3 2,810.1 2,806.7 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 11/6/1993 PACKER;6,522.3` 4 3,375.0 3,352.7 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 3/1/1988 SEAL ASSY;6,521.4 1 a 5 3,940.9• 3,853.8'CAMCO KBUG 1 GAS LIFT •DMY BK-2 0.000 0.0 3/1/1988 SBE;6,524.8 so 6' 4,562.1 4,368.5 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 11/6/1993 - 7 5,187.4 4,903.8 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 11/6/1993 8 5,687.1 5,349.7 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 11/6/1993 9 6,186.3 5,796.7 OTIS WB 1 GAS LIFT DMY BK-2 0.000 0.0 3/1/1988 1 6,289.5 5,887.8 CAMCO 'KBUG 1 INJ DMY BTM 0.000 0.0 4/12/2009 Close NIPPLE;6,539.8 0 d REDUCER;6,539.81 - - 1 6,356.9 5,947.0 CAMCO KBUG 1 INJ DMY INT 0.000 0.0 6/11/2009 Close 1 d 1 6,499.9 6,070.5 CAMCO KBUG 1.INJ DMY BK 0.000 0.0 9/18/1993 Close 2 d SOS,5.550.5 Notes:General&Safety End Date Annotation 102/1997 NOTE:Tubing LEAK @ Tubing Patch 6475'-6486' 7/21/1999 NOTE:Suspect CSM @ 6357'RKB may be flow cut 8,leaking (PERF;6,603.0-6,607.0-- _ 7/27/2006 NOTE:CASING LEAK DETECTED @ 6060'ELMD 10/22/2008 NOTE:WAIVERED WELL IA x FORMATION - IPERF;6.618.0-6,638.0 4/12/2009 NOTE:Catcher Sub POOH w/top 8"of Merla Patch during GLV 0/0 10/22/2010 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;6,657.0.6,670.0 FISH;6,785.0 PRODUCTION;29.57,236.0 • • Loepp, Victoria T (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Tuesday, October 04, 2016 10:09 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 1Y-05(PTD 183-087, Sundry 316-487) RWO Victoria, I have confirmed that 1,851 psi is the correct MPSP. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (303)378-8881 cell (907)265-6341 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, October 04, 2016 8:47 AM To: Beat,Andrew T<Andrew.T.Beat@conocophillips.com> Subject: [EXTERNAL]KRU 1Y-05(PTD 183-087,Sundry 316-487) RWO Andrew, The MPSP on the 10-401 form is 2884 psig and is 1851 psig in the procedure. Please verify correct MPSP. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aa..alaska.00v 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.Loem@alaska.gov @alaska.gov 1 \�����j/�s� THE STATE Alaska Oil and Gas of IA s KA Conservation Commission 333 West Seventh Avenue ' = _ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907.279 1433 OFALArSIE'N' Fax 907 276.7542 www.aogcc.alaska.gov Andrew Beat SCANNED Sr. Wells Engineer 0 205 VS3" ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Rive Oil Pool, KRU 1 Y-05 Sundry Number: 315-505 Dear Mr. Beat: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this D day of August, 2015 Encl. RBDMS � 1 OM STATE OF ALASKA • ' AL _AKA OIL AND GAS CONSERVATION COMI ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing Change Approved Program r Rug for Redrill r Perforate New Pool U air Well rRe-enter Sus Wellr Other: � U„ f 2 Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. . Exploratory r Development r 183-087 • 3.Address: Stratigraphic r Service r . 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-20966-00' 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool Will planned perforations require spacing exception'? Yes r No r/ KRU 1 Y-05 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25646 • Kuparuk River Field/Kuparuk River Oil Pool • 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): 7266 •• 6688 • 7236' ' 6664'• 6280' 6785' Casing Length Size MD TVD Burst Collapse CONDUCTOR 42 16 73' 73' SURFACE 2174 9.625 2205' 2205' il E 1if ED PRODUCTION 7207 7 7236' 6664' �•• AUG 1 2015 AOGC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): ` 6381-6472,6603-6607,6618-6638,6657-6670 5968-6047,6158-6161,6170-6187,6203-6214 3.5 J-55 6527 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-CAMCO HRP-1-SP PACKER • MD=6250 TVD=5853 PACKER-BAKER FB-1 PACKER j MD=6522 TVD=6090 SSSV-CAMCO TRDP-1A SAFETY VALVE MD=1791 TVD=1791 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r. 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/8/2015 OIL r WINJ 1 nr� WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG I/i^' GSTOR r SPLUG r Commission Representative: 1 GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Andrew.T.Beatt 265-6341 Email. Andrew.T.Beatanconocophillips corn Printed Name 'ndrew Air A Title: Sr. Wells Engineer /zo/5 Signature \` -.19.416, Phone:2656341 Date �, Commission Use Only Sundry Number: Conditions of approval. Notify Commission so that a representative may witness 31S—G O yA- t/vm ) vcri3 � 41/0,-4-,'efettrel to pAckrrtb beplaccc/l A' 3c2 , h above t- e Plug Intef(rity r BOP Test " Mechanical Integrity Test rV Location Clearance r -FPP perfo - 1-1 (wA-A.c M I (en 9e c��0r`a.„s r, t�0 .6e //1 aeGBrklfr,Ge `t///`1 llo 2lj C il 25 4!2 (6)) Other: imer M w 40 re ves+ C u-Kr-t a @� I Aio 11?.0 f S' S , Spacing E\cception Required? Yes 0 No [v/ Subsequent Form Required: /h— 4/)4 E'- ' tr-f,1 lc ooc'�/. •,, ( ,14P5P 75 I3Zg ✓ si) 5 •tela✓ 55ccl ,l Ir Tis - r g� 'U1 /3ctI-t1"1, s� �r it.3(cl rY'Jr c «. , APPROVED BY Approved by: P-- p COMMISSIONER THE COMMISSION Date: O 'i/-/5' VIZ- 9/31/!S Approved application is valid for 12 months tropm the date of approval. Submit Form and Form 10-403 Revised 5/2015 ORIGINAL 4sa 14 I J `t t'//9/Wif-Attachments in Duplicate t • 1 ConocoPhillips Alaska AUG 19 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 A(JG G August 18,2015 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to work over Kuparuk Injector 1Y-05 (PTD# 183-087). 1Y-05 was originally drilled and completed in 1983 as an"A"and"C"sand gas-lifted producer in Kuparuk. In 1994,it was converted to a MI WAG injector.In 2002,the well transferred to a water only injector. In 2006,a leak in the production casing was found at 6,060'MD,above the upper selective packer.An Administrative Approval to continue injecting was granted on 9/13/2006 after proving that injection was not entering IA above packer and was still restricted to permitted zones.In 2008,the tubing failed a MITT with the leak point located at the upper selective packer.The Administrative Approval was amended on 10/29/2008 to include authorization to submit a RST Water Flow Log(WFL)instead of a MITT to verify tubing integrity. The RST WFL showed that the packer was leaking fluid into the upper selective and not into the IA which included the production casing leak. 1Y-05 continued injection until 2/6/2012 when it was shut in for reservoir management and a water header repair. On 12/29/2014 during the post water header repair inspection,it was discovered that the IA pressure had slowly risen while the well was shut in.Due to this IA pressure anomaly,the well has remained shut in until it can be repaired. The proposed workover scope for 1Y-05 is to pull the existing 3-1/2"completion down to the lower most packer and install new 3-1/2"tubing with a 5-1/2"scab liner to isolate the production casing leak at 6,060' MD. The upper packer to be run with the scab liner will be set at approximately 5,850' MD(531' above top perforation)which does not comply with 20 AAC 25.412"The packer must be placed within 200 feet measured depth above the top of the perforations". The top of production cement,verified by a CBL performed June 4, 1983,was found at approximately 5,090' MD which is 760' above the upper packer. We wish a variance be granted from the regulation. This Sundry is intended to document the proposed work on the injection well,including the modifications to the production casing,request a variance from 20 AAC 25.412,and request approval to work over the well.If you have any questions or require any further information,please contact me at 265-6341. Sincer- y, —.10111I NoiNk Andrew Beat Wells Engineer CPAI Drilling and Wells 1Y-05 Rig Workover • P&R Selective w/Scab Liner (PTD#: 183-087) Current Status: This well was shut in on February 6,2012 and is currently waiting to be worked over to replace tubing and fix a production casing leak. Scope of Work: Pull the existing 3-1/2"tubing and upper packer,install a 5-1/2"scab liner with dual packers to isolate production casing leak. General Well info: Well Type: Injector MPSP: 1,729 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 2,338 psi/6,091'TVD(7.6 ppg EMW)measured on 01/04/2015 Wellhead type/pressure rating: FMC Gen IV,7-1/16"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-IA failed-07/17/2006(Prod.Csg. leak above packer-Admin.App.to continue injection on 09/13/2006) MIT-T failed-07/14/2008(Packer leaking into upper selective-Ammended Amin. App.to continue injection on 10/29/2008) MIT-OA passed-07/08/2013 Earliest Estimated Start Date: August 5,2015 Production Engineer: Scott Pessetto Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Pre-Rig Work 1. Inspect pad and work area for hazards. Complete the PJSM. 2. RU Slickline. Set plug in nipple reducer and set catcher sub on top of plug. 3. RIH and pull DV from GLM#9. 4. RD Slickine. 5. RU E-Line and RIH with radial cutting tool to perform the following cuts: a. Cut tubing above GLM#12 b. Include CCL,cut tubing between GLM#11 and blast rings c. Include CCL,cut tubing above upper packer 6. RD E-Line. 7. PT POs and FT LDS. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV.Reverse circulate seawater. Obtain SITP&SICP,if still seeing pressure at surface,calculate new KWF,weight up,and repeat circulation as necessary.Verify well is dead. 3. Set BPV,ND tree,NU BOPE&test to 250/3,000 psi. V- a. a. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe rams will be tested upon pulling the completion. ' 4. Pull BPV,screw in landing joint,BOLDS's,unland tubing hanger. 5. POOH laying down 3 'h"tubing. a. On TOH, set a storm packer.RU Hydratight equipment, if necessary.NDBOP&Tbg head,grow casing, and land in slips.Replace IC packoffs.NU BOP&test.Pull storm packer. 6. RIH with overshot&grapple for 3-1/2"tubing,engage tubing stub and jar OEJ free. 1 1Y-05 Rig Workover • P&R Selective w/Scab Liner (PTD#: 183-087) 7. POOH standing back DP,lay down OEJ. 8. MU&RIH with fishing assembly for slickstick.Engage the slickstick and jar the upper selective packer free. POOH standing back DP. 9. MU overshot&grapple with Rattler,RIH to tubing stub,engage tubing stub and rattle blast rings section free. POOH standing back DP,lay down blast rings. 10. RIH with overshot&grapple for 3-1/2"tubing,engage tubing stub and jar seal assembly from the FBI packer. POOH standing back DP. 11. RIH with Baker Extreme casing scraper and cleanout down to SBE.POOH standing back DP. 12. RU E-Line: RIH with 40 arm caliper for 7"casing,caliper from FB1 packer to surface.Determine best location to set new upper packers. 13. MU selective SLZXP packer assembly, SBE,blast joints,and sliding sleeve spaced out accordingly,RIH on DP to just above SBE. 14. Spot a balanced pill of corrosion inhibited brine in the tubing&IA from the existing SBE to above new packer. 15. Slowly cycle the charge pump and look for pressure increase or lack of returns as the seals engage. Shut down charge pump. Space out from fully located. 16. Pressure up DP to activate the pusher tool and set the packer. Release running tools. 17. POOH standing back DP. 18. MU straddle SLZXP packer and scab liner,RIH to tie-back sleeve, sting tie-back sleeve and space out from fully located. PT the IA to confirm packer is set.Release running tools. 19. POOH laying down DP. 20. RIH with new tubing to just above the SBE. 21. Slowly cycle the charge pump and look for pressure increases or lack of returns as the seals engage. Shut down charge pump. Space out,mark the pipe,and pull out of the SBE. 22. Install space out pups below the hanger,MU hanger.Load the IA with corrosion inhibited fluid.Land the hanger,RILDS. 23. PT the tubing,bleed tubing,PT the IA,and record.Bleed the IA to zero,then tubing. Ramp up the IA pressure quickly to shear the SOV. 24. Pull the landing joint,install BPV.Pressure test the BPV from below. 25. ND BOPE. 26. NU tree.Pull BPV and install tree test plug. Test tree and pull test plug. 27. Freeze protect well with diesel. Set BPV. 28. RDMO. Post-Rig Work 1. Pull ISA' BPV. 2. RU Slickline: a. Pull ball&rod. b. Pull SOV and run DV. c. Pull plug body,catcher sub,and plug. d. Pull nipple reducer from D-nipple. 3. RD Slickline. 4. Reset well house(s)and flowlines of adjacent wells. 5. Turn well over to operations. 2 1Y-05 onocoPhuIlips� KRU Injector P&R Upper Selective w/ Scab Liner Well Details: PROPOSED API: 500292096600 PTD: 183-087 COMPLETION Wellhead: FMC Gen IV 5M Tree: Calico 3-1/8" 5M Casing/Tubing Details: 16"62.5#H-40 Conductor to 73' MD - - 9-5/8" 40#J-55 Surface to 2,205' MD 7"26# K-55 Production to 7,236' MD 3-1/2" 9.3# L-80 Tubing to 6,527' MD Misc Details: Max Inclination: 38.53° Max Dogleg: 4.07°/100' -5,090' -Top of Cement Last Tagged Fill: 6,612' MD Total Depth: 7,266' MD GLM - Circulation Point �_ -5,850' - Packer Perforation Details: " ` '` 6,381'-6,482' MD—C 1-4 Sands ' 6,603'-6,607' MD—A 5 Sand , -6,060'- Production Casing Leak 6,618'-6,638' MD—A 4 Sand 6,657'-6,670' MD—A 3 Sand h h i i - ir, -6,259' - Packer is z7 Camco DS Nipple Injection Mandrels C Sand Perfs - , Blast Joints { 6 Sliding Sleeve . 6,522' - Existing FB-1 Packer A Sand Perfs -� Date: August 18,2015 I Drawn By: Andrew Beat —G_ • Wallace, Chris D (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Wednesday,August 19, 2015 3:20 PM To: Wallace, Chris D (DOA) Subject: RE:Sundry 315-505 for well KRU 1Y-05 PTD 1830870 Chris, This will go back to WAG injection and we would cancel the administrative approval, assuming a successful workover. We will have two barriers between the injection pressure and the production casing leak and the leaking packer will be replaced so the AA should not be needed. Let me know if you have anymore questions. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (281) 928-0463 cell (907) 265-6341 office From: Wallace, Chris D (DOA) [maiito:chris.wallace@alaska.gov] Sent: Wednesday, August 19, 2015 2:59 PM To: Beat, Andrew T Subject: [EXTERNAL]Sundry 315-505 for well KRU 1Y-05 PTD 1830870 Andrew, We are progressing the sundry approval for this well. What is the intent of this well after a successful workover? Water only or back to WAG? I see there is an administrative approval AIO 2B.015 which limits this well to water based on a production casing leak and leaking packer. I need to have a better understanding of if CPAI intends to pursue a cancellation of AIO 2B.015 after the workover or if a modified AIO 2B.015 should be issued after the workover with different restrictions based on the new packer depth and testing requirements. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@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 Y 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 2 -o7 7 2514%0 th CE1VED WELL LOG TRANSMITTAL FEB 13 2015 DATA LOGGED :d K.BENDER AOOCC To: Alaska Oil and Gas Conservation Comm. February 5, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED MA,, 6 , RE: Plug Setting Record: 1Y-05 Run Date: 1/29/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: _ Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1Y-05 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20966-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS ANC @halliburton.com Date: Signed: Vag' 6-eitgat ect Well History File e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ! ~",.~_ - (~ _~ '~ Well History File Identifier Organizing(done) [~Two-Sided JJl IJlJlHIIJJ II JJJ I-] Rescan Needed JJJ J I IHJH IJllJJ RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color item s: [] Diskettes, No. [3 Maps: 63 Grayscale items: [] Other1 No/Type [] Other items scannable by large scanner [] Poor Quality Originals: -- OVERSIZED (Non-Scannable) D Other: :~ NOTES: "D Logs of va'rious kinds [] Other BY: ~ BREN VINCENT SHERYL MARIA LOWELl. DATE:~i~'~'I~xC¢' IS/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ By: BEVERLY BREN~T SHERYL MARIA LOWELL. . DATE,~/~." IS/~¢~ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~I~OUNT MATCHES NUMBER IN SCANNING PREPARATION: _~_ YES NO BY; B~' BREN VINCENT SHERYL MARIA LOWELL DATE;//-~5 Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES NO BY: (SCANNING IS COMPLETE AT THIS POINT UNLE~ SPECIAL ATTENTION IS R~:OUI~ED ON AN ~DIVIOUAL PAGE BASIS DUE TO OUALITY, GRAY$CALE OR CO~OR IMAGES) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked {done) 10125/02Rev3NOTScan ned.wpd • • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 04, 2011 2:05 PM AN 7.011 To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 -- message 3 Here is the latest addition to the email trail. 20. 2A -03 - AA 2B.050 issued 6/9/2010. 19. 1Y -10 - AA 2B.041 issued 03/11/2009. Well last injected 01/10. 18. 1Y-09 - AA 2B.051 issued 05/20/2010. 17. 1Y -08 - AA 2B.056 issued 10/22/2010. Well last injected 04/07. Are there plans to return the well to operation? 16. 1Y -05 - AA 2B.0015 originally issued 09/12/06, revised 10/21/08. 2 year RST required (condition 3). Original RST 09/01/08, next RST 07/13/10; report "automatically" submitted by Halliburton. Since the RST is a requirement of the AA, the report should be submitted by Problem Wells. 15. 1Y -04 - Last injected 07/09. 7/5/09 email stated intention to keep on injection for diagnostics and possibly apply for AA. Apparently diagnostic results were inadequate for AA. 14. 1Q-11 - AA 2B.058 issued 11/02/2010. I need to review condition 3 of AA for revision. F : Maunder, Thomas E (DOA) Sent: uesday, January 04, 2011 10:53 AM To: NSK ) , -II Integrity Proj Cc: 'NSK Pro. - Well Supv' Subject: RE: Co oPhillips Monthly Injector Report - Dec 2010 All, I am continuing to review the • -cember Monthly Injector report. I am through a t. of 13 wells. I wanted to send this latest message due to , gat I have found or not found on 1 Q -02B. A , continue to work through the report, I plan to send interim messag- as I get 7 - 10 new wells reviewed Call or message with any questions. 13. 1Q -02B - Well name is 1Q -02B. Well last inje: ed 9/ t. I do not show having received any specific notification /request in June, 2010 regarding this we. There is an email in the file from 4/20/10 reporting diagnostics accomplished to that time containing a : em- ' that you intend to return the well to injection and remove it from the waiver report in May. 12. 1 L -05 - AA 2B.054 issued 10/22/21 0. Well last injected 9/10 11. 1 L -03A - Well name is 1 L -0 • . Permit to Drill # is 199 -037. MITIA faile. 09/25/2010. Well last injected 9/10. 10. 1G-01 - AA 2B.0. issued 7/30/2008. 9. 1 F -16A - i -11 name is 1 F -16A. IA DD failed 4/12/2007, but MITs are listed to have passe. 'nce. Well last injected 4/ :07. AA 2B.018 was issued in October 2007, but no injection has occurred into the we . ooking at the pre ure plot, it is shown that the IA pressure appears to have been bled off in October and Novem. -r. Was 1/4/2011 . • The following information is received monthly from CPAI. Reporting this information isa requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [ mailto :n1617 ©conocophillips.com] ` �� Sent: Saturday, January 01, 2011 10:55 AM l To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 • • ConocoPh i l l i ps Well 1Y-05 Injection Data • Tbg Psi • IA Psi • OA Psi 4000 3500 - i 3000 - a) 2500 a a 2000 1500 **••• »•••••••••••• ••••••• • r.... • • 1000 _ _ _ P 500 ••••••••:_e ; • Awe. � .� • 0 09/10 10/10 11/10 12/10 01/11 Date PTD:183 -087 AIO 2B.015 issued 09/12/06, amended 10/21/08 Reason: TxIA comm, failed MITIA 7/17/06. Csg leak @6060'. RST WFL showed no upflow behind pipe (07/13/10) AOGCC witnessed MITOA passed 07/17/10 AIO 2B.015 requires any pressure bleeds to be reported monthly No pressure bleeds have occurred in the past month • 0 ConocoPhillips Well 1Y -05 Injection Data • Water Injection • Gas Injection 4000 3500 - 3000 - ° 2500 Q I 000 - 2000 1500 8 A iliPaii o 1000 I 0 AWL 500 I 0 0 1000 2000 3000 4000 5000 6000 7000 Injection Rate, bwpd or mscfpd 1 Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected (mscfpd) Pressure (psi) (psi) (bwpd) (psi) 31- Dec -10 4854 0 1685 730 170 30- Dec -10 4809 0 1673 709 147 29- Dec -10 4717 0 1652 660 116 28- Dec -10 4753 0 1657 675 133 27- Dec -10 4654 0 1639 668 139 26- Dec -10 4739 0 1647 692 169 25- Dec -10 4675 0 1634 722 201 24- Dec -10 4689 0 1635 668 161 23- Dec -10 4781 0 1648 771 284 22- Dec -10 4882 0 1669 950 450 21- Dec -10 4779 0 1661 950 450 20- Dec -10 4672 0 1635 663 136 19- Dec -10 4697 0 1638 692 167 18- Dec -10 4629 0 1624 677 164 17- Dec -10 4710 0 1635 734 227 16- Dec -10 4761 0 1645 726 223 15- Dec -10 4666 0 1620 768 274 14- Dec -10 4697 0 1621 723 202 13- Dec -10 4817 0 1639 679 182 12- Dec -10 4807 0 1631 765 269 11- Dec -10 4759 0 1623 737 240 10- Dec -10 4719 0 1614 684 187 9- Dec -10 4725 0 1611 676 196 8- Dec -10 4775 0 1621 704 222 7- Dec -10 4743 0 1614 684 222 6- Dec -10 4735 0 1609 726 274 5- Dec -10 4848 0 1631 730 290 i • . 4- Dec -10 4771 0 1627 871 439 3- Dec -10 4798 0 1626 814 374 2- Dec -10 4798 0 1619 900 400 1- Dec -10 4848 0 1623 900 400 30- Nov -10 4858 0 1614 714 238 29- Nov -10 4887 0 1615 694 236 28- Nov -10 4942 0 1619 720 278 27- Nov -10 4932 0 1613 745 315 26- Nov -10 4951 0 1613 765 336 25- Nov -10 4988 0 1615 809 402 24- Nov -10 5012 0 1614 825 403 23- Nov -10 5028 0 1604 800 368 22- Nov -10 5076 0 1600 749 320 21- Nov -10 5186 0 1612 799 380 20- Nov -10 4893 0 1545 744 322 19- Nov -10 4718 0 1507 748 338 18- Nov -10 4836 0 1526 781 376 17- Nov -10 4806 0 1515 814 430 16- Nov -10 5074 0 1569 900 511 15- Nov -10 5101 0 1567 900 508 14- Nov -10 5192 0 1572 919 518 13- Nov -10 5168 0 1557 929 516 12- Nov -10 5207 0 1554 939 514 11- Nov -10 5214 0 1539 985 537 10- Nov -10 5263 0 1532 962 480 9- Nov -10 5201 0 1497 857 376 8- Nov -10 3881 0 1210 683 244 7- Nov -10 2060 0 836 629 183 6- Nov -10 2076 0 854 699 298 5- Nov -10 1985 0 833 713 327 4- Nov -10 1974 0 829 685 310 3- Nov -10 1925 0 809 741 400 2- Nov -10 1991 0 823 867 548 1- Nov -10 2155 0 867 920 600 31- Oct -10 2180 0 872 1037 665 30- Oct -10 2829 0 1026 972 446 29- Oct -10 5966 0 1651 554 130 28- Oct -10 3060 0 1203 660 142 27- Oct -10 4990 0 1616 595 108 26- Oct -10 5004 0 1611 774 316 25- Oct -10 4970 0 1602 795 327 24- Oct -10 5042 0 1608 790 317 23- Oct -10 4942 0 1576 775 307 22- Oct -10 5102 0 1599 835 349 21- Oct -10 5221 0 1624 771 296 20- Oct -10 4687 0 1525 820 348 19- Oct -10 4581 0 1500 821 327 18- Oct -10 4559 0 1489 819 318 17- Oct -10 4621 0 1495 889 359 16- Oct -10 4542 0 1478 564 132 15- Oct -10 4649 0 1488 495 107 14- Oct -10 4695 0 1490 443 96 • 0 13- Oct -10 4619 0 1469 425 94 12- Oct -10 4516 0 1450 450 107 11- Oct -10 4539 0 1455 633 342 10- Oct -10 4620 0 1480 801 523 9- Oct -10 4868 0 1530 852 562 8- Oct -10 4814 0 1529 808 527 7- Oct -10 4848 0 1530 871 579 6- Oct -10 4807 0 1520 868 565 5- Oct -10 4732 0 1502 825 512 4- Oct -10 4710 0 1492 826 506 3- Oct -10 4861 0 1518 700 418 2- Oct -10 4758 0 1495 700 500 I • MEMORANDUM TO: ~~ ' Jim Regg ~~~~, ~~ ~~ I ~~ P.I. Supervisor Z FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 Y-OS KlJPARUK RIV UNIT lY-OS Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .~' ~- Comm Well Name: KUPARUK RIV UNIT lY-OS Insp Num: mitLG100717131549 Rel Insp Num: API Well Number: 50-029-20966-00-00 Permit Number: 183-087-0 Inspector Name: Lou Grimatdi Inspection Date: 7/17/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel>~ lY-os 'Type Inj. W TVD 5853 •' IA 610 640 670 670 P.T.D 1830870 iTypeTest SPT Test psi 1500 ~ QA 150 1820 ~~ 1750 1740 Interval REQvAR p~ P Tubing 900 900 900 900 NOtes: MIT-OA for AA compliance. ZP,mc.~i~ ~ y; ;A i 9 F ...e. V Y, c t ,' (r i. ~ ~ I i Tuesday, August 10, 2010 Page 1 of 1 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Water Flow Log: lY-OS Run Date: 7/13/2010 July 30, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1Y-05 Digital Data in DLIS/LAS format, Digital Log file, Interpretation Report 50-029-20966-00 Water Flow Log (Proccessed) 50-029-20966-00 ` 4 a~ y ~ ,e ~ " ~s,a;' t SpectraFlow (Field print) 50-029-20966-00 1 CD Rom 1 Color Log 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: ~3, a~~ 1 ~. ti ~~ ~ Signed: . • S HALLIBURTON ConocoPhillips Alaska, Inc. Kuparuk River Unit 1 Y -05 API #: 50- 029 - 20966 -00 JAN I g 2oTh Report Oxygen Activation Log Evaluation Prepared For: GKA Drillsite Petroleum Engineering Date: 7/28/2010 Submitted by: Rafael Barreto rafael.barreto @halliburton.com 6900 Arctic Blvd. Anchorage, AK 99518 Ph: 907 - 273 -3527 HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF. • • HALLIBURTON Conoco Phillips TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY 3 2.0 SPECTRAFLOW LOG EVALUATION 4 2.1 IMPULSE TESTS 7 3.0 WELL DIAGRAM 12 Page 2 of 12 S HALLIBURTON CA!"10C0P'tllll 5 1.0 EXECUTIVE SUMMARY Well: 1Y-05 Oxygen Activation Log Evaluation Survey date: 13 -Jul -2010 Logging Objective Check for upflow behind tubing using SpectraFlow Log. Conclusions The SpectraFlow tool was run to check for upflow behind the 3.5" tubing. The SpFI tool string was run in the normal configuration (generator below detectors) using impulse tests at several depths: 6200 ft. MD, 6250 ft. MD, 6300 ft. MD, 6500 ft. MD and 6552 ft. MD. The impulse tests showed no indication of water flow up behind tubing. Page 3 of 12 • • HALLIBURTDN ConocoPhillips 2.0 SPECTRAFLOW LOG EVALUATION The SPFL was run using stationary impulse tests across the zones of interest. Water flow can be detected by measuring gamma rays originating from activated oxygen within any water flowing past the neutron generator (activation) then moving past the detector section (decay). The fluid /water velocity is estimated from oxygen activation using impulse test data. The flow direction is determined by the position of the sensor relative to the neutron generator. The flow region, near or far, is derived by the ratio of Compton backscatter gamma rays compared to original gamma ray counts from activated oxygen. Lower Compton ratio indicates a flow region further from the tool i.e. behind the next string of pipe. Total oxygen activation will be a function of: • volume of water in the region of neutron cloud • flow velocity of water • tool speed • flow distance to detector • time of exposure Below is a representation of the sequence of radioactive excitation and subsequent relaxation of Oxygen. Gee Spectral "t (6,13 MeV) Beta Gamma Ray Q ia Decay Detector N" 7.13 -sac Halt -Life High Energy Oxygen (14 -MeV) t; Activation Neutron Generator Figure 1: Sequence events of oxygen activation The tool is configured in the normal mode with the neutron generator below the detector section. In the normal configuration, water will only be detected when moving up relative to the Spectral Flow tool, in both the stationary impulse mode and continuous mode. Any oxygen activation detected by near and far detector should be from water flow up. Page 4 of 12 • e HALL (BURTON ConocoPhillips M, . t1 1 j 0 GR 1 . • i • Far detector e l i' Near detector II 11 r i GEN I NI Figure 2: Flow scenario related to spectra flow log tool Stationary Impulse Method This technique is basically a travel -time measurement and has the significant advantage of not requiring any calibration of the detectors. When the tool is stationary at a specified depth, the generator is turned on and allowed to stabilize. The count rate in each detector is then recorded for one or two minutes, at which time the generator is shut down. At some time later (depending on the fluid flow velocity and distance from the various detectors to the source), the count rate recorded in the detectors will drop to background level. The count rate will drop to nearly zero in the spectral window encompassing the oxygen peak. The surface computer records the various detector count rates, steps down the generator, measures the time until the recorded count rates fall to one -half full value, and then computes a velocity from the travel time. The fluid velocity is the distance from the source to the detector divided by the time between the count -rate drop and the time when the generator was shut down. The procedure is completely automated. The spectral data can be processed to provide fluid velocity in one step because the count rate falls essentially to zero after the activation passes. Processing the total gamma ray count rates requires two steps. The natural background must be measured for approximately one minute after the drop to correct for the nonzero background activity. Fig. 3 is a graphical representation of the timing cycle used by the stationary impulse method. Page 5 of 12 • 0 HALLIBURTON ConocoPhillips S t a t i o n a r y I m pulse OHAI.LIBU12TdN` Timing Sequence 110 a - --OAI Curve 100 90 -- a 80 Generator 1 /2 Value en Voltage m 2 7 P 60 `o ST ' m R d 50 V c 40 so I Distance to Detector 20 Velocity = 1 Li 0 50 , 00 150 200 Time/Seconds Figure 3: Stationary Impulse timing sequence Y P 9 uence Q Page 6 of 12 • 1110 HALLIBURTDN ConocoPhillips 2.1 Impulse tests The impulse test at depth 6200 ft. MD shows no water flow in the upward direction as indicated by the far and near detectors. Both near and far oxygen activation curves read no change in counts when generator is on or off. The GR sensor above SPFL tool does not show different readings during generator on and off, indicating no water flow up. — 7171 GFNV C , TFA - 0A114 OAIN <d NEAR ACT ,vu FAR ACT IIIIIIIIIIIIE N . i h `I l ,f i.,...,............ 11, ��� • lit ", I ��� MIN I ___ 1 �,,_��__ , i'lliiiiilla,11111MIMII H,'._7�m� 'kik ..______ ,, . : , ` 1,.�� FAR ACT NEAR ACT OA194 • 6 a _ NV r GRATF o TFA GAIF 0 . V CRAIN /NA :AIN _ Figure 4: Impulse test at depth 6200 ft. MD SPECTRAFLOW RESULTS FILE. IMP6200.cls TOOL DEPTH - 6200 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON ILEX (FT /M) DIR OAIN 0.15 0.00 UNDETECTABLE UP OAIF 0.01 0.00 UNDETECTABLE UP TNA 211.16 0.75 UNDETECTABLE UP TFA 106.57 0.16 UNDETECTABLE UP CR 113.79 0.02 UNDETECTABLE UP CRATN 0.76 CRATF 0.41 Page 7 of 12 • HALLIBURTON ConocoPhillips The impulse test at depth 6250 ft. MD shows no water flow in the upward direction as indicated by the far and near detectors. Both near and far oxygen activation curves read no change in counts when generator is on or off. The GR sensor above SPFL tool does not show different readings during generator on and off, indicating no water flow up. r. tJ TNA ^.5; 1wu xvu C ;ENV C c R ATF TFA GAIF +04114 VOLFE Cp . I dl A t u cu 1� ■��� I 1 ■■■ ■17■■■■■ 111111111111111112:111 ■ ■ ■ ■■ 111111111: 11111111111111111t ■■■■r mom 1111'11111 M11111} ifl ■■ i ►�■■■ w■ ■■ri1111w■■■■w■ i.� ■■■ ■■Fk'■■■■■ ■ ■■■■■r , ww i'■■■■■ ■ ■lt�iwr ■ ■ ■ ■ ■ ■1' " imw- 11E111111 II 11111111 I i_...11111111111111111111 Illi11111 i �w� 1111E r� ■ ww 111111011.1111111 F ■■■ ■■U■ 1: +��■■i 1111'11II11 u®I®11♦i :w 111131111 I r �; 11 .nn■■ 2111111:1111111111111111111111111 , `n■11■ ■__s ■r�■ ■■ �; ww 1 AI? AG NEAR ACT 740 OA 184 U t40 UFNV GAAJf TFA UAII 0A114 ,w &O3 0 70 0 /40 CRATN 1'! /+ OAIN �1t.x --- 0 `A /40 Figure 5: Impulse test at depth 6250 ft. MD SPECTRAFLOW RESULTS FILE= IMP6250.cls TOOL DEPTH = 6250 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT /M) DIR OAIN 0.18 0.00 UNDETECTABLE UP OAIF 0.05 0.00 UNDETECTABLE UP TNA 251.22 0.80 UNDETECTABLE UP TFA 103.01 0.20 UNDETECTABLE UP GR 65.50 0.00 UNDETECTABLE UP CRATN 0.63 CRATF 0.73 Page 8 of 12 • HALLIBURTON ConocoPhillips The impulse test at depth 6300 ft. MD shows no water flow in the upward direction as indicated by the far and near detectors. Both near and far oxygen activation curves read no change in counts when generator is on or off. The GR sensor above SPFL tool does not show different readings during generator on and off, indicating no water flow up. 24V A 7. 240 EMIIL u■ni>tr ®n smumminnumiiiim 111121111111111IN ■■1�1M11iiii° IL ■ ■«gin■ ■ ■.1=1 11w 1 ®1l �� ® ®S m - moo i=w IIINKIIIII mow ■U - r !►• AI At, 0 2.m NEAR ACT U 740 0A194 U au GFNV !! lu GRATE 11-A OAIF OA114 � U 000 ran yaw , 4 CHAIN 1' -1„ 020IN 0163 ISU RE CS. 0 ,Ik0 - -- - -00 000 /40 Figure 6: Impulse test at depth 6300 ft. MD SPECTRAFLOW RESULTS FILE= IMPG300.cls TOOL DEPTH = 6300 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT /M) DIR OAIN 0.20 0.00 UNDETECTABLE UP OAIF 0.03 0.00 UNDETECTABLE UP TNA 224.37 0.82 UNDETECTABLE UP TFA 103.76 0.16 UNDETECTABLE UP GR 85.06 0.00 UNDETECTABLE UP CRATN 0.93 CRATE 2.84 Page 9 of 12 i • HALLIBURTON ConocoPhillips The impulse test at depth 6500 ft. MD shows no water flow in the upward direction as indicated by the far and near detectors. Both near and far oxygen activation curves read no change in counts when generator is on or off. The GR sensor above SPFL tool does not show different readings during generator on and off, indicating no water flow up. Lsinsa■■ I■I■II■..1110 ■ ■ ■ ■111111111■ ■■ 111111111 hill 111111iiiii 11 � �C� ]■■■■■■ ■ ■■ ■■ri ■■ ■ ■■■�■ ■■' * =mum ■rte ■■ ■a ■■ ■■�■■■ 1‘4. �� u rm■ll■■■■■ ■l11■■�Sf ■ ■■ ■� ■ ■ ■f ��MI iuii■■■■■ r�■rrii■■■ ■ ®■■■r ,�w w■■e�� �uu■ ■■■■ ■s:i■■■■ ®■■■i � ��� 1i■ " � M1iiiiiii viiii�ii� !w1111111.111.1 111[ 1 11N III,inh1111. : C 11111111 11111lnhiiuuuu; • 111111 1111111111111111111 ;AFAR ACT _4. _ CIATF_ TFA GAJP $ n GA114 100 CRATN TNA it G15; + 1 � :Ef., -; 0 10 0 s?n - eu a Figure 7: Impulse test at depth 6500 ft. MD SPECTRAFLOW RESULTS FILE= IMP6500.cls TOOL DEPTH = 6500 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT /M) DIR OAIN 0.30 0.00 UNDETECTABLE UP OAIF 0.01 0.00 UNDETECTABLE UP TNA 477.17 0.87 UNDETECTABLE UP TFA 104.30 0.28 UNDETECTABLE UP GR 34.03 0.05 UNDETECTABLE UP CRATN 0.11 CRATE 0.14 Page 10 of 12 HALLIBURTON ConocoPhillips The impulse test at depth 6552 ft. MD shows no water flow in the upward direction as indicated by the far and near detectors. Both near and far oxygen activation curves read no change in counts when generator is on or off. The GR sensor above SPFL tool does not show different readings during generator on and off, indicating no water flow up. OAlN 04il GFNV CRATF TFA •`�AiF 0A114 d' i 1 u 5!F'r - t,o n /40 OFtili 4 040 Nk-.Aii A(:I n !4J rAR ACT O /40 ■ ■�,�w ■■ .....1Jwww.wwwww _ ■III ®w .....1/r•wl....wl , ■ ■i1 ■■ .....■i.... ■... .i l �� ■ iu.■■ .n.■ a........ , 1.1 ii 11I•■■ w.•.awww.wwww.l ■� 1 ■■ 111111111111111111111011111111111111111111 1 ; ■■w ■ ■ir�w ■1! MOM= EMIR 1.i �+�M 111111 1111111M11111411111111•111111.01 �,: ww ■■c1 ® ■11 w....IE /... 111..w ' ` 1 ■■alma w...a ■... .a '\1.04:1:0-- NMI MIN sesso.�/... ■ _.1 t wnw 1 u :4A 740 VAI94 u [4u (:,I -NV CRATF ?FA OAIF 0AI14 Jot( -' n 50 11 /40 v,s 1 600 CRATN T' -1F, OAIN 0163 I11 Ef: - --- - - - 500 1140 Figure 8: Impulse test at depth 6552 ft. MD SPECTRAFLOW RESULTS FILE= IMP6552.cls TOOL DEPTH = 6552 FT. CASING(ID) = 2.99 IN. AVERAGE COUNT RATE REL. FLOW VEL. FLOW GEN. ON INDEX (FT /M) DIR OAIN 0.64 0.00 UNDETECTABLE UP OAIF 0.05 0.00 UNDETECTABLE UP TNA 732.45 0.90 UNDETECTABLE UP TFA 146.51 0.52 UNDETECTABLE UP GR 55.10 0.01 UNDETECTABLE UP CRATN 0.13 CRATF 1.07 Page 11 of 12 • • . HALLIBURTON ConocoPhillips 3.0 WELL DIAGRAM i KUP IY -05 • ConocoPhillips � 1 ennnrix1es xAngle&MD TD wallbon 0682*l R48 lima 3 I ®ndl`t MD( Kej 500292096600 KUPARUK RIVER UNIT !NJ 3853 7,100.04 Last Tag. 0 1 �-t Crsing Strings cn.e 1 1 IR ,rip , - .CONDUCTOR 0 rim � 0.0 1 1 ®� ro, o es e>ros1 ,205 4 [0 ' 8 i it PRODUCTION 7 6.151 0.0 7,232.0 6,661.3 26.00 J-55 i� --"rr •InOGenpbon fitim �se t06p 7 . 0 . N 13;a 4Dt... [jy, - '• lei TUBING ® 6,257.0 5,839.0 ®® ono atcnp pan 8• Ci O. 0 99 2 6,2 Top • 761 ntapbl (1.. N 1 (TVD}.., s 0'I.. b s.... TOpU® Dui TUBING 1 12 G 's 1 2.992 57.0 6,5510 6,1 6,113.8 9.30 J-55 J55 060 EU Other In role (Wtreline retrievable plugs, valves, pumps, fish. etc.) trill 0^0112; op Gpin T op 001 0 1 Top WI 1055 IB) ittl. i G 4cnob wank on mm Run Gb bfi11 1,791 1,791.0 1 SaOCarrico y Valve Carrico TRDP -IA 2311184 2613 �1am' i 1,828 1,8279 1.62 GAS LIFT CAMCO/KBUG/I /DMYBK -251 Comment STA1 0 1984 2.875 2,247 2,2469 050 GAS LIFT CAMCO/KBUG /1/DMYBK -01/1 Comment. STA2 1/1988 2.875 2,810 2,808.7 13.34 GAS UFT CAMCO/K8110 /1 /DMYBK2U/ Comment. STA3 115/1993 2.875 `w' ijid i 3,375 3,352.6 17,81 GAS UFT CAMCO/KBUG /1/DMYBK211 /Comment'. 5TA4 e (/1988 2.875 3,941 3,8539 3520 GAS LIFT CAMCOIKBUGII /OMYBK-2111 Comment STAS a 1/1988 2.875 r m � 4,562 4,368.5 32.52 GAS LIFT CAMCO/KBUG/1/DI.YBK -21// Comment'. STAG 115/1993 2.875 082 � 5,187 4503.5 29.18 OAS UFT CAMCO/KBUG /1 /DMYBK- 2/4/ Colmlent: STA7 115/1993 2275 ,w- 5687 5,349.6 25.42 GAS LIFT CAMC0 /KBUG /I /DMYBK-2g4 COmmeiv STA8 115/1993 2.873 6,186 5,796.5 27.69 GAS UFT OTIS/Yl5/l /DMY /8K -2//.1 Comment: STA9 1/1988 2.891 6,227 5,832.2 27.18 SBR Camco OEJ 0 3/1994 2.813 6,250 5,8528 2754 PACKER Cameo HRP -I SP PACKER 0 3/1884 2.875 s,,e: 6,289 5,887.4 28.12 INJECTION CAMCO/K8141/0MY/BTM1 /1 Comment: OPEN STA10 122009 2.875 6,357 5,947.0 29.13 INJECTION CAMCO/KBUG1DMY /INTII Comment: OPEN STA11 • 112009 2.875 6,475 0,049.2 31.01 PATCH 12.3' Merle Tubing Patch; Set on 926/93 - • 1893 2.375 1"ns,®; 1 6,500 6,0706 31.42 INJECTION CAMCO /KBUGNDMYBKN/ Comment: CLOSED STA 12 018/1933 2.875 6.522 60893 11.78 PACKER Baker'FB -1' PACKER 1984 3.000 e1z 6,540 6,1045 32.8 NIPPLE Cameo 'D' Ngp1e NO GO 0 1984 2.750 6,540 6,1045 32.8916 -VA NIPPLE REDUCERw1AVA PROFILE 0.01993 2.250 REDUCER _tr czz, 8,551 6.1138 3226 SOS Cameo '23/1984 2.892 6,552 6,114.6 3228 T7L ELMD TTL@ 0554' during LDLon 62 /1090 • 3/1984 2592 l 6,785 6,307.4 30.19 FISH " "Geo -Vann 365.88' long . 13/1983 u 9,230 Perforations & Slots S.105 Ben 11140 ltt 5 O B 0 0ND1 Eons Top 411)5 Ittr:e'1 rttl'.el 00. 3 GU i011_ Tpe Comment 6,381 6472 5,968.0 6,046.6 C,2, C3, C4, 6/1311883 12.0 IPERF 5 "Geo -Vann, 1200eg. Phasing sc ssl 111C7 97 8/ -05 ng , 0 6,603 6,607 6,156.9 6,180.3 A5, 1Y 5 6/13/1983 12.0 IPERF 3"Geo -Na 120 deg, Phasing 6,618 6,638 6,169.7 6,186.6 A4, IY.05 6/13/1983 12.0 IPERF 3 "Geo -Vann, 120 deg. Fbaritg e0 6,657 6,670 6,2025 6,213.4 93, PROS 6/13/1983 120 IPERF 5 " Geo - Vann, 120 deg. Phasing s,s• ' Notes: General & Safety Edit 01d Cob 'Luncheon ca. run 1/12 /1997 NOTE:Tubig LEAK@ Tubing Patch 64734486' 721/1899 NOTE: Suspect C SM 0 6357' RK8 maybe tiger cut t leaking 1,.99.75 ' I I 7272006 NOTE: CASING LEAK DETECTED 61 6060' ELMD 10/232008 NOTE: WAVERED WELL IAN FORMATION 4 NOTE: Catcher Sub POOH w /t0p8 "o4 Merle Patch during GLV CIO lu e,m LIE en � c �' -1.- 1 • 4818098 - .,.r..716 r o?31 Te.: Ax Page 12 of 12 i 1 ! '- °7 = 1 r\ j f N GOVERNOR fA RA r .. k M .�r �� -! - ..: � � ru SARAH PALIN, GO Q 1�T ALASKA. OIL I AND r `_AST 333 W. 7th AVENUE. SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 278 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 2B.015 (Amended) Mr. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 RE: KRU 1Y-05 (PTD 183 -087) Kuparuk River Oil Pool Dear Mr. Rogers: In accordance with Rule 9 of Area Injection Order (AIO) 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants ConocoPhillips Alaska Inc. (CPAI)'s request for an amended administrative approval to continue water injection in the subject well. Specific to this amendment is approval to replace the tubing mechanical integrity test (MIT -T) requirement with a water flow log. The Commission approved AIO 2B.015 for Kuparuk River Unit (KRU) 1 Y -05 on September 16, 2006. The well exhibited a production casing leak above the uppermost packer; CPAI demonstrated to the Commission's satisfaction that KRU I Y -05 could be operated safety with certain conditions restricting injection operations and increased monitoring and surveillance. CPAI reported an MIT -T failed on July 14, 2008. The test was performed for compliance with AIO 2B.015. Commission records indicate the well has been shut in since July. CPAI diagnostic testing following the failed MIT -T included a water flow log, a temperature survey, and a leak detect log. The upper straddle zone packer was identified by diagnostics as the leak source for the failed MIT -T. No upward fluid movement between the upper straddle packer and the production casing leak (above the packer) was evident from the evaluation work completed by CPAI. Based on the results of diagnostic tests, CPAs has elected not to perform corrective action on KRU 1Y -05 to restore full integrity. On September 2, 2008 CPAI requested Commission approval to substitute a water flow log for the required MIT -T with the same frequency (every 2 years). The Commission's review of diagnostic test results agrees with CPAI's assessment that there is no evidence of fluid movement out of the approved injection zone penetrated by KRU 1 Y -05. Further, the failed MIT -T represents a deterioration of the well's mechanical integrity requiring Commission approval to continue injecting. Regulation 20 AAC 25.450 gives the Commission authority to approve less stringent well integrity and operating requirements when there are no • AIO 2B.015 (Amended) October 21, 2008 Page 2 of 3 mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field." Replacing the MIT -T requirement with a water flow log in conjunction with the other conditions included in AIO 213.015 will allow CPAI and the Commission to continue effective monitoring of injector well integrity and fluid movement to assure compliance with regulatory obligations. Administrative approval to continue water injection only in KRU I Y-05 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform a water flow log every two years; 4. CPA1 shall perform an MIT -OA every two years; 5. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; ,,sI4+ 6. After well shut in due to a change in the well's mechanical condition, AOGCC a;' ,rrr . y d shall be required to restart injection; and h 7. The MIT anniversary date is July 23, 2006. DONE at Anchorage, Alaska and dated October 21, 2008. "=- '''nt Daniel T. Seamount, Jr. Cathy P. ' oerster Chair Commi Toner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter detemincd by it, If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall. grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[Ole questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day That does not fall on a weekend or state holiday. • 1Y -05 (183 -087) AA Support Docent Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, October 21, 2008 9:37 AM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF1 Prod Engr; CPF1 DS Lead Techs; Kovar, Mark; Maunder, Thomas E (DOA) Subject: 1Y -05 (183 -087) AA Support Document Attachments: 1Y 05_RST_TEMP_OVERVIEW.pdf «1Y_05_RST TEMP_OVERVIEW.pdf» Jim, As per your request, attached is additional information in support of the administrative approval for Kuparuk injector 1Y -05 (PTD 183 -087). Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 1/4/2011 • • 1Y-05 WATERFLOW LOG W /TEMPERATURE WARMBACKS OBJECTIVE: IDENTIFY IF WELL IS INJECTING OUT OF ZONE FROM CAMCO HRP -1SP PACKER AT 6250' RKB TO KNOWN PRODUCTION CASING LEAK AT 6060'. NFI FOR RECORD RST WATERFLOW LOG CONFIGURED O R UPFLOW BETWEEN PACKER AND KNOWN PRODUCTION CASING LEAK. RST DATA RECORDED IN STANDARD MODES AND USING CUSTOM SETTINGS FOR LOW FLOW RATE DETECTION. RECORDED BASELINE SHUT IN TEMPERATURE AND WARMBACKS AT 1, 2, AND 3 HOURS. DISCLAIMER: THE USE AND RELIANCE UPON THIS RECORDED -DATA BY THE HEREIN NAMED COMPANY (AND ANY OF ITS AFFILIATES, PARTNERS, REPRESENTATIVES, AGENTS, CONSULTANTS AND EMPLYOEES) IS SUBJECT TO THE TERMS AND CONDITIONS AGREED UPON BETWEEN SCHLUMBERGER AND THE COMPANY, INCLUDING: (a) RESTRICTIONS ON USE OF THE RECODED -DATA; (b) DISCLAIMERS AND WAIVERS OF WARRANTIES AND REPRESENTATIVES REGARDING COMPANY'S USE OF AND RELIANCE UPON THE RECORDED -DATA; AND (c) CUSTOMER'S FULL AND SOLE RESPONSIBILITY FOR ANY INFERENCE DRAWN OR DECISIONS MADE IN CONNECTION WITH THE USE OF THIS RECORDED -DATA. TOOLSTRING CONFIGURATION: SURFACE EQUIPMENT WITM -A PSC_16MHZ DOWNHOLE EQUIPMENT MH -22 54.8 MH - 22 EQF - 43 53.2 EQF - 43 EQF 47.2 EQF -43 Detail MT TelStatus PSPT - /B CTEM 41.2 — 41.2 PSC -A PSPT -A PSTC GR — 37.5 PBMS -A 101( Sapphire_Mano RTIS Thermometer Well Temp 34A GR - Manometer G 34.3 CCL CCL _ 33.7 PBMS PBMS PSTC — 32.9 PGMC - A!B ACCE 32.9 PGMC -B Gratlioman — 31.4 Accelero PSOI_Graaio PGMC _ 28.2 RST - C 28.2 RSCH -A RSC-C RSS -A RSXH -A RSX -C RSC -A Far 19.0 RSC -A PNG RSC -A Nea RSX -A PNG _ 18.5 PFCS - A 5.1 Turbine PFCS Spin Relative Bearing PFCS Cali 1.9 Caliper PFCS Rela HV PFCC -A PFCS Cart PFCH -A Tension pll TOOL ZERO MAXIMUM STRING DIAMETER 1.72 IN MEASUREMENTS RELATIVE TO TOOL ZERO ALL LENGTHS IN FEET • • WELLBORE SCHEMATIC: KUP 1Y-05 ConocoPhillips ; ll AttrA We1RM .. I ` !i : I't A I uw.. II4 , .... . -. ITH. _,..IIcD. All I 1'1! kDa u C.... lr aa .1:llx A•xrm '2Dna Ji4Sdpll C.IN,..n. DS. . !.`X1' ' _ ,. :,r.1N tar r..) A: IS!' L.,' Se, ..... . _. VAASA, e.r ..1 •a »rum ea . . Ler Ir D*'! .'61::1 I,..I -nn, ,All t't I W■11 1'16 - JU:t y ; N. Dy.l' wl osnnwl 611 C.... M.D." DC hi .D.ad 1<p nnl f.+Dl tADI or., aa. rAa 11n.1 II ;.. 9CX*)J_1:1 It I!U!! 00 , 3 i.1 f1C 5241111 1151!. - LU1'a'.t 0!+11 451' 00 3, :I5U 2204* WU:.b1 11„�LC•: 'IJ. t II UU 120 56!11 :n U: H' e.i.M1 Tux. ' stri •e tam .:, ann NM i E•Li IIIIIitifillINIREENI PPI -, r,AAI de t}t'`.J 161 112 1 .1:U a :•I L el :t 6 0) .2A a.re't -t .1••••1. O In Hole (AI Je Ill bg Tubing, t13 fotrMVSOh, fled. elc.1 110 T. 11 OK9' D,1< Com., 1.' Cs. C l)) 11010551. 19_`1 TOW 1 'DU ' -'A w. 14.. l'EU .NS Lit IAN:J)YC9U't.l p' -*V.2•4 4 Cr.,.,? 1101 s ^lea tare SAS '. 4 V 11.2 Lit CAN.X..CLU'I.IM•11IY \ arnrt.: I* 2 11:1311! 2 a!! I .1511' 'J.11L+JYOLU'1.W Vr41 rerf : IA: I W'9LS 2 42.3 .x..041 + .• .lo '. ll' ANUT',Y M'N.Z. n.. CLUelhlVCnn. 1.1A4 11,1'01* 2 tat fl I JA: LI' W_ ..YIILuY11.1.8 f" WCannr., ,tint 11'10.!! /IN :Lit: LP 'i: . ,YCLSYI.V.T•Ielrl S'C:wrrwt StAb I .6 "795 26!5 .4' I 4..01 1 "I' I "." u' N .,1'.CLUI,IM'.DIt.21' tsrtn..l. tTA / 9 .k591' • ...• .,v eLC01.11M'ltI.2A'CCe.rnat tint 1 2a!!' SAS D.1 { • 0') I.ur .LII^- n' c.INISII'C421IXnn.n 1'100 51,151t 2aalt' ' m i ... d 15 sQt. 0.'J ^ 94 lat: c .!I.:x IAC'1t +1 unx • -1.• I "A9 *tl•. Rzs "7t+ 2 41✓ ...M-1 }}}}'''' _. JAI 3 Y WNI a. 14'1,a Uat: I I ..•.• A 14 LL 11C1 CAWL:AV *9U1I1 1.19...., 510 U1 •■:•1:t 2a!* . t : !' L tilt;: PPCS CALW.:.4t*LWl'VM.W IMR':..,rnt Otai `4'1 SSAIX: l a!`. ......1. 11. . : 4 . .:11'01911 '2)61.51* '061. 11/ 3/12V511 0.'A "915 2 'i.'. 1 J I MOO nat:711C% i:4N.':.Vl'... , I - I., •.`i•..' fans,' CLCtt CIA 12 0.'15"71. 2W! kN� _ .itU IAN =110 ..... I -I .. 15 " 5M 1UC 115, A_tl.. A..nx ,._t?I: II WOW' 45.) 21 27_'C art tII? t 5400 MJt 0.' " f 714 12". I1 *..V 1'L RZ3"7t- 2112 ...a...t 4.� += CC RbU ti 1 Uo.4,, M• 7 • , 6'I] " 7 *> L..: x T.C, Dr. .Tit; S'^' '.S.l.N1 01,4101 11a21 94101 T ' . - DP C.pvb awls t; III 0 II .I!: b mac tat of K•t' - !:a "119® D' Cl.oahlr''2!8 a.•.N1¢ G 1930 a4c!i t'.rc �Iti I" 1.. 1.:6 't'1NL1�Y[INr Y1 1Tr, ` ( 'Slut; 1 aSA • 11IA 0 a 411 :.• t 1e. ' ! It.. a I': 1. c. ' .. W' 1.19KS YU.Yr, ".. +.+ 0: U 64!! *N:! *41341 4.1' -+ l _N'L1t49 YU.o-'h+r,' a<4G '•a... Nobs: Generlt 8 saaty - - . a. LH Dp I:I 1..5..n I'1:0: `.J 1.1b'. ?.tAY Q Iit.; . inch D.! >'+4'.: •.t Vns `.J't tut .c1La1Pba! ,W, b. lr =ra p3119 1.anl Si, AN;N ..4 161,) - t 54:1541 MA!'. Lt Itti ILL C Mn? 0: 14! AAA Asst SSA ..u1b11tn .1511.5 1111 Sit sal *It l m N M *ibis ter N M *491.. NM 04'4111 .IM a.W W SOAAANAll RST WFL RESULTS: RST DETECTED NO UPFLOW BETWEEN CAMCO HRP -1SP PACKER AT 6250' AND KNOWN PRODUCTION CASING LEAK AT 6060' RKB. RST SENSOR VALIDATION: lY_05_WFL (PROF 015EP2008 PRINT.PDS- Suhiumberger PDSwew ,,:y,.�., . = AU/ j< fie Ede Dsplay Annotate Ann Help d• -; � [ ' 4 \' AE L- CP -e3• =E ! Henwca ■ to Lop File WFL Start Stop Flow Velocity Velocity Number Detector Depth Depth Detected Error lit) iK1 if:min) lit'mini 011 RST - Far 626.0 624.5 Yes 30.5 5.8 Data Acquired on 01- Sep -2008 09:06 Detector is above Minitron (sensitive to Up Flow) WFL Subcycle Time: 0.80 sec On - 52.27 sec Off Number of WFL Cycles: 5 Measured CR Net CR Background CR N 0. La U RIH IN 30 FPM WITH WELL STATIC N l Z 0 13.09 26.17 39.26 52.35 Time (sec) — Smooth Net CR Velocity marker L /\\-, 11 Anrotstrn xt supported at tMS x- Coordnate ... W825 fb Cmlfete _ J 4 Start] J ' , I " _ wn52.350 , .KP0,13K 4 aY_� WFL_ C Docunentl -M.., I XEmeed _7(V_ Fdrer , _ /OP fdda J ,.7PF{5 I . Adobe AVdlet...l l Lh00 C. U f a , IMPM FIGURE 1: TOOL WAS TESTED DOWNHOLE WHILE RIH AT 30 FPM IN A STATIC COLUMN OF WATER. THIS CREATES A NET UPFLOW OF 30 FPM RELATIVE TO TOOL SENSORS. UPFLOW OF 30.5 FPM WAS DETECTED BY SENSORS. • • RST SAMPLE LOG RESULTS: Ie Os_WFt_IPROF sdtnumnnvereosr Fie Ede LQepley Annotate Vsew Hen 01 1 10 700 -- - ---- -' - - -- — — -- - -_ - -- J Velocity(ft/min) RST WFL Station Summary 01- Sep - 2001313:07 Lop Fie WFL Scat Stop Floe Velocity Velocity Mabel Detector Depth Depth Detected Eliot iIn IIII mnein oft mini 035 P13145 -OR 6227 0 62075 No — -_ Data Acquired on 01 -Sep- 20061302 Detector is above Intro (sersdrve to LO Flow) --i NFL Sbcycle htne 060 sec On - 5227 sec 011 Nerker OAR Cycles', 5 - Measured CR - Net CR — Background CR a I LJ . . 11 .tL.�ilrl t i b u r IR' , F11'�1 ,, •T,., , 11 "11 • I 0 1316 26.32 39.47 5263 Time (sec) Smooth Net CR N a U a m 0 0 E o -Alin • r AIL 10 1010 1000 10(00 Velocity(ft/min) RST WFL Station Summary 01- Sep - 200613:07 .1 m FCC NFI S,ar, Stec, FMw Vrevav vice,ac Ready W 36.00 Fla Compete j -' StutJ , � E2 J PARK 114, IY OS WFl IPROF 0_ ®j IY 05 RSD_TETP OVER,., X Exceed Adobe Acrobat Standard... a crai 2 t V r 3:12 PM FIGURE 2. NO UPFLOW DETECTED ON "NORMAL" SETTING AT 6227'. • • RST SAMPLE LOG RESULTS: IY OS WfL IPROF OISEP2008 PRINT,POS Schlumberger POSView ., ..1-0.1211 RN Ed Ospey annotate Vow Help RST WFL Station Summary 01 13:12 Leg Fie MI. hart Stop Row Velocity Velocity lienha Detect. Depth Depth Detected Etta m9 rro m.mm m t�t 036 RST -Near 6227 0 62265 No -- - -- Coto Angie i orc 01Sep- 2009130E Detector b 160ve DSWen (sensiNe to Up Flow) NFL S lnycb TYr0 1 D sec On - 20.27 sec Olt tinier of NFL Cries '9 Measured CR Net CR — Background CR a V " 0 5.16 10.31 15.47 20.62 Time )sec) S — Smooth Net CR a U V th B 3 N " 10 100 Velociry)fUmm) RST WFL Station Summary 01 -Sep - 200813:22 Log Fie WFL Start Stop Row Velocity Velocity 1Aetba Detente, Depth Depth Detected Etta Minim mmig PD5 x:939 Y:156365 W 36.00 Fete Conpbte r st.tl n POPPY II }, iY_DS_WFL_IPROF_O_ mi IV_0s 7EIP_OYER...1 X Exceed I adobe Acrobat Standard.. I a ° Att, @ t � 3.14 pM FIGURE 3: NO UPFLOW DETECTED WITH CUSTOM PARAMETERS AT 6227'. • • RST SAMPLE LOG RESULTS: .a.1Q,21 the Edt Daplay Amotete View 6th RST WFL Station Summary O1- Sep - 200813:22 Log File WEL 51,x1 Star Row Velocity Velocity IhmIce Detector Depth Depth Detected Era mr mr In think et nem 037 DST-Far 62270 62255 No -- — Data Acct.Fed on 01- Sep- 20D61313 Detector n above Matron (enti a to W Flow) NFL SUbcycle hew 1000 hac On • 90.67 sec OH teener of NFL 0(011. 5 - Measured CR - Net CR Background CR n • ye U N z 21 78 Time (sec) 47 51 71 33 91 S — — Smooth Net CR a - U B E to 00 1 10 )co Velocity(ftimin) RST WFL Station Summary 01-Sep-2008 13:22 Loam. WFL Start Step Flow Velocity Velocity Benno 0e1e110, Depth Depth Detected heel an itn dltnew tn 037 RST -Neer 6221 0 62265 No J el ' PD5 x:1126 y:151935 w 36.00 Flle Compete t#f5tmtl ] RI W ° �KPARX l , ty_D5_WDL 1PROF 0.- ®,IY 05_RST TEW_r2IE0 !I X Exceed I Adobe Acrobat Standard...) 44 Dt Br 3:16PM FIGURE 4: NO UPFLOW DETECTED WITH "SLOW" SETTING AT 6225'. THIS TOOL SETTING IS THE MOST SENSITIVE TO LOW WATER VELOCITES. • TEMPERATURE LOG RESULTS: TEMPERATURE SENSOR DID NOT INDICATE DETECTABLE INJECTION FROM CAMCO PACKER INTO KNOWN PRODUCTION CASING LEAK. TEMPERATURE SENSOR VALIDATION: Fb Edt Display ANnotate View Fklp Clara: COIIOCOPMLLIPS ALASKA. PIC. Too! PSP RNb KUPAPIW RIVER m11T SW Type: PP/A5 Welt 12 -25 Sensor: WNITens RTD Pun date: 1- Sel.- MKS PTO Well Thermometer Sonde Sell? HS CUEFFICEIITS Fop PTP TIERMOKE TER PISS 13.33.4t S It Sens. Se. Ia1121 374$ Celih (We dbrarrry 161•07 Mal. Size 16 Coen CRC DFEE Wiens COe11 T "6 Tt "1 Tt "1 Tt "1 I r.5331714S243E43 I - 122973SS3.133FM3 I ..33112nss$nlE+13 11 "3 Tt "A TVS 73"0 I- .551306121153E.42 I ..31624T114223E 10 Clew CO$IOCOPM.LNS ALASKA. UK. Tool: PSP Belt KINANR( MVER MT SW Type: PGML Wet 10 -el Seas.: ACCE Run die: 1.Sep.226$ PlAtS Aseelero VTCO Sonde Serial IS ACC VTCO COEFPKEIITS PGMC- :1621. SENSOR S It Serfs. S. IA IS 1221 CAS Dale rib 111W *MAT Matrix Size 23 Co., CRC $527 Aloe Coen Te111 Tens Te np "2 Ta "0 I +.3021%•11014E41 Y11M3MPM1 I •.MJ1 I .19TM1511e1$F $2 Tel •• Reedy 1V 96.00 IFTe Cempkte 4 Startt n JKFARf IY_05_WFl IP0.0F_0._ �1J' IY_OS RST_TEKV OVER...I ZEx[aad I '. A dpbe Acrobat Standard FIGURE 5: RTD TEMPERATURE SENSOR INCLUDED IN LOGGING TOOL PBMS CALIBRATED IN ACCORDANCE WITH SCHLUMBERGER TECHNOLOGY CORPORATION STANDARD OPERATING PROCEDURES. • SAMPLE TEMPERATURE LOG RESULTS: II 1Y_ 05 _WFL_IPROF_015EP2008_PRIIYT.PDS - Schiumberg File Edit Display Annotate View Help IIIIIIIIII • = = = == ESE__ Jig _ -- IIIE !I! SESSEEE H i i = = =SE =_— _gam__ .355 ==== ___E_ -- -�._ -a EE= =B= 7,-=======1 _ === � _ = = - EiMil NEE MESEME =3 FIGURE 6: TEMPERATURE WARMBACKS CONSISTENT WITH A STATIC WELLBORE ABOVE PERFORATIONS AND DO NOT INDICATE INJECTION HAS OCCURRED AT 6060' RKB. 1 Y-OS (PTD 1830870) request for AIO amendment Page 1 of 2 • • Regg, James B (DOA) From: Colombie, Jody J (DOA) Sent: Friday, September 12, 2008 12:56 PM To: Regg, James B (DOA) Subject: RE: 1 Y-05 (PTD 1830870) request for AIO amendment Example ADMINISTRATIVE APPROVAL AIO 14A.002 (Amended) From: Regg, James B (DOA) Sent: Tuesday, September 02, 2008 11:01 AM To: Colombie, Jody J (DOA) Subject: FW: 1Y-05 (PTD 1830870) request for AIO amendment ! assume you want to #rack amendments to AIO admin approvals? Remind me how we number these. Thank you. Jim Regg AOGCC ~ -. 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, September 02, 2008 10:32 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPFi Prod Engr Subject: 1Y-05 (PTD 1830870) request for AIO amendment Jim, This is a request to amend AIO 28.015 for Kuparuk water injector 1Y-05 (PTD 1830870) to substitute a RST Water Flow Log instead of a MITT to verify there is no out of zone injection. As we had discussed on the phone, an upper straddle zone packer was identified by a LDL as the leak for the failing MITT. A RST WFL was run on 09/01/08 and determined the following: PERFORMED RST WFL, TEMPERATURE LOG, AND INJECTION PROFILE. RESULTS: NO UPFLOW DETECTED WITH RST BETWEEN UPPER STRADDLE PACKER AND PRODUCTION CASING LEAK. WARMBACKS DO NOT DETECT UP FLOW BETWEEN UPPER STRADDLE PACKER AND PC LEAK. PATCH AT 6475' IS HOLDING. INJECTION MANDRELS #10 AND #11 ARE TAKING FLUID. SPLITS: 93% C AND 7% A. NO CROSSFLOW DETECTED WITH WELL SHUT IN. ConocoPhillips would like to amend the requirements for AIO 26.015 to include a RST WFL every two years instead of a MITT against a wireline plug set below the packer. With the results of the WFL and the AOGCC witnessed passing MITOA completed on 07/14/08, ConocoPhillips would like permission to return the well to water injection and amend the AIO for future testing purposes. 9/12/2008 1~'-OS (PTD 1830870) request for AIO amendment Page 2 of Z Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 9/12/2008 ~, ~ ~~ ~; ~, o~ ~ ~: ~F,~~ ~~ `~ IOO~j Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Field: Beluga River Unit Well Job # Log Description ;r:r < < r~j~acr~{ ~ E if! ~~ i ~ t ~.,~4.1l1 NO 4852 -~,~~,,;°~~?~,~at~~. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD os/2s/os 2W-11 12100437 PROD PROFILE ~ - 08/06/08 1 1 1 F-14 12096521 PROD PROFILE - ~ 08/08/08 1 1 1 Y-05 12096520 LDL / ~ 08/07/08 1 1 30-02A 12097415 SBHP SURVEY '~-- a 08/10/08 1 1 1 E-114 12096524 INJ PROFILE - 08/10/08 1 1 2A-24 12097417 PROD PROFILE - ~ ~- 08/11/08 1 1 1G-10A 12097418 PROD PROFILE f 08/12/08 1 1 1 L-14 10228963 INJ PROFILE ~} ~- 1 v 08/12/08 1 1 30-17 11966273 SBHP SURVEY i 08/15/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. e KRU lY-OS (PTD# 183-087) Report Of Failed MITT Page 1 of 1 • i Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, August 22, 2008 11:07 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); CPF1 Prod Engr; CPF1 DS Lead Techs; NSK Problem Well Supv; NSK Well Integrity Proj~ ovar, Mark Subject: KRU 1Y-05 (PTD# 183-087) Report Of Failed MITT Attachments: 1Y-05 Wellbore Schematic.pdf; 1Y-05 TIO Plot.ppt Jim, As per A10.26.015, I am reporting a failed MITT on Kuparuk injector 1Y-05 due to the upper packer at 6250' MD leaking into the C Sand selective. A10.2B.015 requires performing an MITT "every two years agains a~wireline plug set below the packer". Our initial attempt to MITT 1Y-05 on 7/14/08 failed as was witnessed by Jeff Jones. We have made two subsequent attempts to reset the plug below the packer and MITT, both of which failed. On 8/18/08 an ultrasonic noise log was run and interpreted to illustrate leakage at the packer at 6250' MD. Due to the inner annulus being relatively unaffected during pumping operations it has been inferred that the packer is leaking into the selective. CPAI's immediate plans are to keep the well shut-in and secure it with a plug in the Camco OEJ seal bore receptacle at 6227' MD above the packer. nce tubing and accessories above the plug have demonstrated integrity we will internally decide whether to leave the plug in place, secure the well using the nipple in the Camco ~ TRDP-1A SSSV at 1,791' MD, or submit a request to keep the well on water only injection with periodic MITT's using a plug immediately above the packer instead of below. Attached is a Wellbore schematic and 90 TIO plot. «1Y-05 Wellbore Schematic.pdf» «1Y-05 TIO Plot.ppt» ~ Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 10/8/2008 ~~ O o ~ CYO ___. dwalla~l~u~ o ~°n °o ° N ~ .- `n c~ O r ~.+ O a O 1 r ~I d O C) ° ° O ° ~ l°C1 O u°C) O ° N N ~- r- ~ C) 00 O i Q O d~ i.r iPQ 00 ~ ° T ° ° O ~ ISd .. _.. KUP 1Y-05 ~W.. : , ~Ol1dCd~~tl~~IgS ; ~ ~ Well Attributes _~~ CONOUCTOF 7 SSSV, 1,79 GAS LIFl 1,92 SURFACE z2o GAS LIE' 2.24 GAS LIFl 2,81 GAS LIFT 3,37 GAS LIFl 3.94 GAS LIFl 4,66 GAS LIFl 5,18 GAS LIFl 5.60 GAS LIFl 6,16 SBR, 6,22 PACKER, 6,26 PLUG, 6,28. INJECTION s.ze INJECTION 6,36' IPERF 6.361-6.47: PATCH. 6.47! INJECTION 6,501 PACKER, 6,52: NIPPLE, 6,641 NIP REDUCER 6.541 SOS, 6,66 TTL, 6,55: IPERF 6,603-6,60' IPERF 6.618-6.63t IPERF 6,657-6,67( FISH, 6,78: PRODUCTION 7,23: TD, 7,26E ' ~ `' ~ ` 500292096600 KUPARUK RIVER UNIT INJ 38.53 7,266.0 -~ -------- en c~,~ ~ PM Comment H25 (ppm) Date Annotation End Dale KB[irtl (H) SSSV. TRDP ... 0 7/1/2008 Last WO. 923/1984 35.01 Rig Release Date 6/1/1983 __ ..... _ -_ _ ,, ' Annotation Oepth (HKB) End Dale Last Tag: 6,618.0 7/8/2008 Casing Stnngs _ Casing Descrtption OD (in) ID (in) Annotation Rev Reason: TAG, SET WRP - _ - _ - -- _ _ Set Depth Set Depth (TVD) Wt Top (HKB) (HKB) (ftKB) (Ibs/H) Grade End Date 8/162005 _ - Top Thread - CONDUCTOR 16 15.060 0.0 73.0 73A 62.50 H-40 ~> i SURFACE 9 5/8 8.697 0.0 2,205.0 2,204.8 40.00 J-55 '.. i PRODUCTION Tubing Strings 7 6.151 0.0 7,232.0 6,661.3 26.00 J-55 -' Tubing Description OD (in) ID (in) Top (HKB) Set Deptn (HKB) Sat Depth (ND) (HKB) Wt (IbaHt) Grade Top Threa d '. TUBING 31/2 2.992 0.0 6,257.0 5,859.0 9.20 J-55 BTC '~ TUBING 3 1/2 2.992 6,257.0 6,551.0 6,113.8 9.30 J-55 8RD EUE - Other In Hole (All Jewelry: Tubin~Run & Retrievable. Fish, etc.) Top (ftKB) Description Gom ..~,1 Run Date ID (in) 1,791.0 SSSV SSSV: TRDP Camco TRDP-tA 9/23/1984 2.813 `" 1,928.0 GAS LIFT CAMCO/KBUG/1/DMY/BK-2/// Comment: STA 1 9/23/1984 2.875 -- ~ 2,247.0 GAS LIFT CAMCO/KBUG/1/DMY/BK-Z// Comment: STA 2 3/1/1988 2.875 ~'_ 2,810.0 GAS LIFT CAMCO/KBUG/1/DMY/BK-2///Comment: STA3 11/6/1993 2.875 ~~! 3,375.0 GAS LIFT CAMCO/KBUG/1/DMY/BK-Z// Comment: STA 4 3/1/1988 2.875 3,941.0 GAS LIFT CAMCO/KBUG/1/DMY/BK-2///Comment: STAS 3/1/1988 2.875 ~ 4,562.0 GAS LIFT CAMCO/KBUG/1/DMY/BK-Z// Comment: STA 6 11/6/1993 2.875 ~ 5,187.0 GAS LIFT CAMCO/KBUG/1/DMY/BK-2///Comment: STA7 11/6/1993 2.875 ' ' 4 5,687.0 GAS LIFT CAMCO/KBUG/1/DMY/BK-Z// Comment: STA 8 11/6/1993 2.875 ~~ 6,186.0 GAS LIFT OTISIVVB/t/DMY/BK-Zi/Comment STAS 3/1/1988 2.891 ---' ~ 6,227.0 SBR Camco OEJ 9/23/1984 2.813 ' 6,250.0 PACKER Camco HRP-15P PACKER 9/23/1984 2.875 ~~ 6,285.0 PLUG 3.5" WRP 8/142008 0.000 i, 6,289.0 INJECTION CAMCO/KBUG//HFCV/BTM///Comment: OPEN STA 10 8/8/2006 2.875 ~~ 6,357.0 INJECTION CAMCO/KBUG//HVCV/BTM/// Comment: OPEN STA 11 8/8/2006 2.875 _ 6,475.0 PATCH 12.3' Marla Tubing Patch; Set on 9/26/93 9/26/1993 2.375 6,500.0 INJECTION CAMCO/KBUGI/DMYIBK/// Comment: CLOSED STA 12 9/18/1993 2.875 6,522.0 PACKER Baker'FB-1' PACKER 9/23/1984 3.000 '. 6,540.0 NIPPLE Camco'D' Nipple NO GO 9/23/1984 2.750 6,540.0 NIP REDUCER AVA NIPPLE REDUCER 9/20/1993 2.250 - 6,551.0 SOS Camco 9/23/1984 2.992 6,552.0 TTL 9/23/1984 2.992 ti , ~ _- 6,785.0 _ Perfora Top (ftKB) FISH 5" Geo-Vann 365.88' long _- _. - - -.. tions :,net. Top (ND) Btm (ND) Dens Btm (ftKB) (ftKB) (HKB) Type Zone (snot... Date - 6/13/1983 . ~ -. _ Comment - '° ~ !%'i ~~ 6,381.0 6,472.0 5,968.0 6,046.6 IPERF C-2, C-3, C-4, C-1, 1Y-OS 12.0 6/13/1983 5" Geo-Vann, 120 deg. Phasing _._ ' 6,603.0 6,607.0 6,156.9 6,160.3 IPERF A-5, 1Y-05 12.0 6/13/1983 5" Geo-Vann, 120 deg. Phasing '--a 6,618.0 6,638.0 6,169.7 6,186.6 IPERF A-4, 1Y-05 12.0 6/13/1983 5" Geo-Vann , 120 deg. Phasing -"' ~_.-~~ 6,657.0 6,670.0 6,202.5 6,213.4 IPERF A-3, tY-05 12.0 6113/1983 Notes: General & Safes End Date __ _ _..._ -_- .:nnotalieu _.__... 5" Geo-Nang 120 deg. Phasing 1/121997 NOTE: Tubing LEAK @ Tubing Patch 6475'-6486' 7121!1999 NOTE: Suspect CSM @ 6357 RKB maybe flow cut 8leaking 7/27/2006 NOTE: CASING LEAK DETECTED @ 6060' ELMD I, ~nl Con ~ ' ' ocoPhi~lips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 ~IV~~ AUG u ~ 200$ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • REC~~V~~ AUG 2 5 200$ Alaska Oil & Gas Cans, C0~'??i~i~aion Ancha~~ga 1~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 2-17, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kle ~ ~ Z ~C~ ~ ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date Initial top of Vol. of cement Final top of Cement top c Nell Name PTD # cement um ed cement date ft bbls ft 2H-05 185-168 SF N/A SF N/A 2H-17 200-019 6" N/A 6" N/A 2K-27 201-169 10" N/A 10" N/A 2M-03 191-141 16" N/A 16" N/A 1 B-14 194-030 SF N/A SF N/A 1 B-18 194-061 9" NIA 9" N/A 1 B-19 194-064 SF N/A SF N1A 1B-20 203-115 21" N/A 21" N/A 1 B-101 203-133 3" N/A 3" N/A 1 B-102 203-122 4" N/A 4" N/A 1Y-05 183-087 6" N/A 6" N/A 1Y-07 183 068 " - 6 N/A 6" N/A 1Y-17 193-068 SF N/A SF N/A 1Y-22 193-070 SF N/A SF N/A 1Y-26a 188-116 SF N/A SF N/A 1Y-30 188-090 SF N/A SF N/A 1E-112 204-091 14" N/A 14" N/A 1E-119 204-031 14" N/A 14" N/A 1 E-121 204-246 6" N/A 6" N/A 1 E-123 204-074 5" N/A 5" N/A s/~ ~i2nng ff Corrosion inhibitor Corrosion inhibitor/ sealant date al 5.10 8/2/2007 1.27 8/2/2007 8.92 8/2/2007 2.13 8/2/2007 1.70 8/13/2008 8.07 8/13/2008 5.10 8/13/2008 5.95 8/13/2008 1.00 8/17/2008 1.00 8/17/2008 1.27 8/13/2008 1.27 8/13/2008 1.27 8/13/2008 2.12 8/13/2008 3.83 8/13/2008 3.83 8/13/2008 5.95 8/17/2008 4.67 8/17/2008 1.00 8/17/2008 1.00 8/17/2008 MEMORANDUM • TO: Jim Regg j~ vJS L}~~ P.I. Supervisor /\Q~ I FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska ~d Gas Conservation Commission DATE: Tuesday, August O5, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 Y-OS KUPARUK RIV UNIT IY-OS Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RN UNIT lY-OS API Well Number 50-029-20966-00-00 Inspector Name• Jeff Jones Insp Num mitJJ080717125321 Permit Number: 183-087-0 Inspection Date 7/14/2008 Rel Insp Num: MITOP000002312 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IY-os TYPe Inj. N TVD sssa IA goo ~zs Aso X60 P•T• 1830870 TypeTest SPT Test psi Isoo / OA zao Islo .- 1~ao I~zo Interval Required by Variance P/F Pass ~ Tubing 2220 2160 2120 2080 Notes• MIT-OA required by variance. 1BBL diesel pumped; no exceptions noted. 1~~"~-1~N~~ SEF .~ 2DD8 Tuesday, August O5, 2008 Page 1 of 1 MEMORANDUM • To: Jim Regg ~,~ ~„ . ~jl,j'~, P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska d Gas Conservation Commission DATE: Tuesday, August O5, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lY-OS KUPARUK RIV UNIT 1Y-05 Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RN UNIT lY-OS API Well Number 50-029-20966-00-00 Inspector Name: Jeff Jones Insp Num mitJJ080717123632 Permit Number 1s3-087-o Inspection Date 7itai2oos Rel Insp Num: MITOP000002311 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IY-os Type Inj. N TVD sasa IA 6so 67s goo goo p.T. Issos7o TypeTest SPT Test psi Isoo ~ pA zso 2ao zao 2ao Interval Required by Variance p~F Fail ~ Tubing 140 2500 2280 2220 Notes' The MIT.=.Tubing test was achieved with a wireline plug set at 6270' MD. Failure due to <10% pressure loss. 2 wellhead bolts not fully engaged; Mr. Greenwood will repair. ~~~~~N~ S~F :~ ~ 20a~ Tuesday, August O5, 2008 Page 1 of 1 lY-OS (PTD 1830870) Report of failed MITT • Page 1 of 1 • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, July 15, 2008 8:08 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 1Y-05 (PTD 1830870) Report of failed MITT Attachments: 1Y-05 schematic.pdf; 1Y-05 90 day TIO plot.jpg; MIT KRU 1Y-05 07-14-08.x1s Tom, Jim Kuparuk Water injector 1 Y-05 (PTD 1830870) failed aMIT-T required by AIO 26.015 on 07/14/08. The TIO prior to the test was 140/650/230 with a WRP plug set in the tubing @ 6270' for the test. It is possible that the WRP or one of the DMY valves in the tubing are leaking. Slickline will troubleshoot the leak and then repair if possible. If Slickline can make the repair, the inspectors will be given notice in order to perform another MIT-T. If the source of the leak requires more extensive repair, a 10-403 will be submitted if appropriate. ,i Attached is a copy of the witnessed MIT form, a 90-day TIO plot, and a wellbore schematic. ~ Please let me know if you have any questions. .i ~ i «1Y-05 schematic.pdf» «1Y-05 90 day TIO plot.jpg» «MIT KRU 1Y-05 07-14-08.x1s» Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~N~~? ~~~ ~ ~ 20D8 8/21 /2008 KRU 1 Y-OS PTD 183-087 CHOKE FTP -- FTf iaP oaP Tll/~ Plot -1Y-05 200 2500 ............................. .......... 2000 ........................................................................................................................................... 150 1500 .............. ............. _.. ~ a 100 ~ _ 1000 ................................................. ................................................... V '~ " ~ ~~ 50 Sao ~s%:`~y~,,._ r-~.~' ;~. ............ ..........F.............. . ..: ....~~r ................ ..~~~~, ...,.%.. ' -. , . .~ , , .~ _ .. 0 -~ 0 15-Apr-08 28-Apr-08 11-May-08 24-May-08 06-Jun-08 19-Jun-08 02-Jul-08 Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@ataska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska, Inc. FIELD /UNIT /PAD: Kuparuk /KRU / 1Y-05 DATE: 07/14/08 OPERATOR REP: Greenwood /Bates /Phillips - AES AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well 1Y-05 ,Type Inj. N TVD 5,853' Tubing 140 2,500 2,280 2,220 Interval V P.T.D. 1830870 Type test P Test psi 1500 Casing 650 650 675 700 P/F F Notes: MIT-T per AIO 28.015 OA 230 230 240 240 Set Weatherford WRP @ 6270' Well ~Y-05 Type Inj. N TVD 5,853' Tubing 2,220 2,160 2,120 2,080 Interval V P.T.D. 1830870 Type test P Test psi 1500 Casing 700 725 750 750 P/F P Notes: MITOA per AIO 28.015 OA 240 1810 1740 1720 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU tY-05 07-14-08.x1s ~~ KRU 1 Y-05 ~ono~oF~illips .Alaska, Ir~~ 1Y-05 API: 500292096600 Well T e: INJ An le TS: 29 de 6381 sssv (1791-1792 - --- SSSV Type: TRDP Orig Com letion: 6/1/1983 Angle @ TD: 39 deg @ 7266 , OD:3.500) Annular Fluid: Last W/O: 9/23/1984 Rev Reason: TAG, PULL PLUG, C!O CVs Reference Lo Ref Lo Date: Last U ate: 8/9/2006 ~_ ~. Last Ta : 6633 TD: 7266 ftK6 Last Ta Date: 8/7/2006 Max Hole An le: 39 de 7266 Casin Strin -ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 73 73 62.50 H-40 SUR. CASING 9.625 0 2205 2205 40.00 J-55 PROD. CASING 7.000 0 7232 6661 26.00 J-55 ~ Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 6257 5859 9.20 J-55 BTC 3.500 6257 6551 6114 9.30 J-55 8RD EUE Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 6381 - 6472 5968 - 6047 ,C-3,C-2,C 91 12 6/13/1983 IPERF 5" Geo-Vann, 120 deg. Phasin ~ ' 6603 - 6607 6158 - 6161 A-5 4 12 6/13!1983 IPERF 5" Geo-Vann, 120 deg. Phasin ~ 6618 - 6638 6170 - 6187 A-4 20 12 6/13/1983 IPERF 5" Geo-Vann, 120 deg. Phasin 6657 - 6670 6203 - 6213 A-3 13 12 6/13!1983 IPERF 5" Geo-Vann, 120 deg. Phasin Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 1 1928 1928 Camco KBUG DMY 1.0 BK-2 0.000 0 9/23/1984 2 2247 2247 Camco KBUG DMY 1.0 BK-2 0.000 0 3!1/1988 3 2810 2807 Camco KBUG DMY 1.0 BK-2 0.000 0 11/6/1993 4 3375 3353 Camco KBUG DMY 1.0 BK-2 0.000 0 3/1/1988 5 3941 3854 Camco KBUG DMY 1.0 BK-2 0.000 0 3/1!1988 6 4562 4369 Camco KBUG DMY 1.0 BK-2 0.000 0 11/6/1993 i 7 5187 4904 Camco KBUG DMY 1.0 BK-2 0.000 0 11/6/1993 8 5687 5350 Camco KBUG DMY 1.0 BK-2 0.000 0 11/6/1993 sBR (6227-6228 9 6186 5796 Otis WB DMY 1.0 BK-2 0.000 0 3/1!1988 , oD:3soo> - - In'ec tion M andrelsNalves PKR St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt (s25o-sz51, _ 10 6289 5887 Camco KBUG HFCV 0.0 BTM 0.000 0 8/8/2006 O en :. OD:6.156) 11 6357 5947 Camco KBUG HVCV 0.0 BTM 0.000 0 8/8/2006 O en 12 6500 6071 Camco KBUG DMY 0.0 BK 0.000 0 9/18/1993 Closed Other lu s, ui .etc..:- JEWELRY De th TVD T e Descri lion ID 1791 1791 SSSV Camco TRDP-1A 2.813 6227 5833 SBR Camco OEJ 2.813 C -~ _ 6250 5853 PKR Camco HRP-1SP 2.875 6522 6089 PKR Baker'FB-1' 3.000 6540 6104 NIP Camco 'D' Ni le NO GO 2.750 _..-..._- -........_ .... .. ____ __- 6540 6104 NIP REDUCER AVA; Set on 9/20/93 2.250 TUBING (6257-6551 6551 6114 SOS Camco 2.992 , OD:3.500, I ~ 6552 6115 TTL 2.992 ID:2.9sz) Other lu s e ui ., etc. -PATCH. De th TVD T e Descri lion ID ~ ~~ 6475 6049 PATCH 12.3' Merla Tubin Patch; Set on 9/26/93 2.375 ~ Fish -FISH De th Descri lion Comment PKR 6785 5" Geo-Vann 365.88' Ion (s5zz-x523, ', ~ i ~ General Notes oD:s.lss) _ Date Note 1/12/1997 Tubin LEAK Tubin Patch 6475'-6486' 7/21/1999 Sus ect CSM 6357 RKB ma be flow cut & leakin ;see WSR 7/21!99 ~ - 7/27/2006 CASING LEAK DETECTED 6060' ELMD sos (6551-6552, OD:3.500) Perf -~ (6603-6607) -...--...-.. 5" Geo-Vann (6785-6786, OD:2.000) ~• _ _. - _ _ __.-__. i, !i ~~ • ~daa7 ®IiLLA FRt~Al6C ~f. ~URCIORlS~CI, GO!lERAIOR 333 W. T" AVENUE, SUITE 700 ANCHORAGE. ALASKA 99507-3539 PHONE (907) 279-7433 FAX 1907) 276-7542 ADiyIIYISTRriTIi~E APPR~~'AI. iY®. AI® 2B.015 ~'[r. Jerry Dethlefs Problem w'e11 Supervisor ConocoPhillips Alaska. Inc. P.O. Box 100360 Anchorage, AK 99~ 10-0360 RE: KRU 1 Y-0~ (PTD 183-087) Request for Administrative Approval Dear ylr. Dethlefs: ~~~~~ ~~~ ~ ~~a$ On September ~, 2006 ConocoPhillips Alaska, Inc ("CPAI") requested an administrative approval under Rule 9 of Area In}ection Order '`AIO" 2S to allow continued water injection in service well Kuparuk River Unit ("KRU") 1 Y-0~. The Alaska Oil and Gas Conservation Commission ("Commission") GRANTS CPAI's request for WATER ONLY service, as detailed below. 1 Y-0~ was originally reported to have failed mechanical integrity testing on July 18, 2006. Diagnostic testing on July- 23, 2006 indicated that there was a production casing teak 200' above the packer. Additional testing has indicated that the tubing is competent and the outer annulus ("OA") was also successfully tested. CPAI has elected not to perform corrective action on l~'-0~ to restore full integrity. The Commission finds that, based upon reported results of CPAI diagnostic procedures. 1 Y- 0~ exhibits a minimum of two competent barriers to the release of we[1 pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity and will not result in an increased risk of movement of fluids outside the injection zone. V~'here freshwater is not affected, 20 AAC 2~.=l~0 Fives the Commission authority to approve less stringent well integrity and operation requirements. Per Rule 9 of AIO 2B, the Commission hereby grants CP:aI's request for administrative approval to continue water injection in KRU 1 Y"-0~ on the following conditions: 1. Injection is limited to w'ATER OtiLY"; aDMIti[STRATI~'E .~PPRO~%'AL A[O NO 2B 0l~ September 12, ?006 Pa~e2of2 2. CPAI shalt monitor and record tubing, inner annulus and outer annulus (T I'O? pressures and injection rate daily; CPAI shall submit to the Commission a monthly report of well pressures and injection rates including any pressure bleed events; =~. CPAI shall perform a Mechanical Integrity Test of the Tubing (~U1IT-T"} every tw-o years against a wireline plug set below the packer; ~. CPAI shall perform an MIT-OA every two years; 6. CPAI shall immediately shut in the well and notify the Commission upon any measurable change in the wells mechanical condition; and '. After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. $. The ivIIT anniversary date is July 23, 2006. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 P1~1 on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. iska and dated September 12, 2006. laska Oil and Gas Conservation Commission Ga~~ Daniel T. Seamount, Jr. Cathy . Foerster Commissioner Commissioner • • RECEIVED 1 PP v • SEP 1 1 2006 ConocoPhiII Alaska Alaska Oil & Gas Cons. Commission P.O. BOX 100360 Anchorage ANCHORAGE, ALASKA 99510 -0360 September 5, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 WANED JAN 1 9 ZOi Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find the enclosed request for Administrative Relief as per AIO 2B Rule 9 to continue water injection operations for well 1Y -05 (PTD 183 -087). Please call Marie McConnell or Perry Klein at 659 -7224 if you have any questions. Sincerely, M Loveland Well Integrity Project Supervisor Attachments • • ConocoPhillips Alaska, Inc. Kuparuk Well 1Y -05 (PTD 183 -087) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc., proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue injection with known annular communication between the production casing and the formation in Kuparuk injection well 1Y- 05 (PTD 183 -087). Well History and Status Kuparuk River Unit well 1Y -05 (PTD 183 -087) was originally completed in June 1983 as a producing well. 1Y -05 was approved for MWAG injection service Sept 27, 1993 (Approval number 93 -254). Well 1Y -05 was reported to the AOGCC in July 2006 as having failed MITIA after it broke down during a regularly scheduled 4 year MIT. A casing leak was located at 6060' RKB using the temperature response in a diagnostic leak detect log shortly after the MIT failure. A workover will be required to fully repair the well however, Seal -Tite treatment options will be evaluated in the mean time. On July 23, 2006 a passing MITT pressure test was completed against a Weatherford WRP plug set at 6273' RKB. The passing test confirms the primary layer of protection or barrier (the tubing) is still intact. A subsequent passing MITOA was preformed on the outer annulus August 13, 2006 confirmed a competent second layer of protection Barrier and Hazard Evaluation Tubing: The 3 -1/2" 9.2# K -55 tubing has integrity to @ 6273' MD, which is 23' below the packer @ 6250' MD, based on passing MITT performed July 23, 2006. Test pressure was 2500 psi. Surface casing: The well is completed with 9 5/8" 40# J -55 surface casing with an internal yield pressure rating of 3580 psi. The surface casing is set at 2205' MD and a 24 bbl cement shoe was pumped shortly after the original completion date. A passing MITOA to 1800 psi was performed on 8/13/06. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The surface casing and cement shoe will act as a third barrier should the first barrier failure Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or surface casing above the surface casing shoe it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T/I plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. NSK Problem Well Supervisor 9/5/2006 1 Approved Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed); 2. Perform a passing MITT against a tubing plug every 2 -years as per AOGCC criteria (0.25 x TVD @ packer, 1500 psi minimum); 3. Perform a passing MITOA every 2 years; 4. Submit monthly reports of daily tubing & IA pressures and injection volumes; 5. Shut -in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. NSK Problem Well Supervisor 9/5/2006 2 0 S KRU 1Y -05 Conoco `l il Alaska, Inc. n 1Y.05 API: 500292096600 Well Type: INJ Angle @ TS: 29 deg @ 6381 g ' s 1 SSSV Type: TRDP Orig 6/1/1983 Angle @ TD: 39 deg @ 7266 5 _ Completion: (1791 -177x292 ' . Annular Fluid: Last W /O: 9/23/1984 Rev Reason: TAG, PULL PLUG, 00:3.500) C/O CVs s Reference Lo.: Ref Lo. Date: Last U.date: 8/9/2006 .. 1111.1nEl 6633 TD: 7266 f1KB • Last Tag Date: 8/7/2006 Max Hole Angle: 39 deg © 7266 s Casm• Slrin. ALL STRINGS $ .: Descri.tion Size To. Bottom ND Wt Grade Thread CONDUCTOR 0 73 73 62.50 - SUR. CASING G 9.625 9.625 0 2205 2205 40.00 J-55 55 PROD. CASING 7.000 0 7232 6661 26.00 J -55 Tubin. ::Stein. - TUBING Size To. Bottom TVD Wt Grade Thread 3.500 0 6257 5859 9.20 J -55 BTC 3.500 6257 6551 6114 9.30 J -55 8RD EUE ..::. :..• ; Perforations Summa Interval ND Zone Status ®SPF Data IIME Comment , 6381 - 6472 5968 - 6047 • ,C- 3,C -2,C 91 12 6/13/1983 IPERF 5" Geo-Vann, 120 deg. Phasin. 6603 - 6607 6158 - 6161 A -5 -III 6/13/1983 IPERF 5" Geo -Vann, 120 deg. Ph asin. 6618 - 6638 6170 - 6187 A4 20 6/13/1983 IPERF 5" Geo -Vann, 120 deg. '' i.;' .. Phasin. 6657 - 6670 6203 - 6213 A -3 13 12 6/13/1983 IPERF 5" Geo -Vann, 120 deg. Phasing Gas Lift MandrelsNalves ® MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 0 1928 1928 Camco KBUG DMY 1.0 BK -2 0.000 0 9/23/1984 ", Q 2247 2247 Camco KBUG DMY 1.0 BK -2 0.000 0 3/1/1988 © 2810 2807 Camco KBUG DMY 1.0 BK -2 0.000 0 11/6/1993 4 3375 3353 Camco KBUG DMY 1.0 BK -2 0.000 0 3/1/1988 ? © 3941 3854 Camco KBUG DMY 1.0 BK -2 0.000 0 3/1/1988 ;... 6 4562 4369 Camco KBUG DMY 1.0 BK -2 0.000 0 11/6/1993 Q 5187 4904 Camco KBUG DMY 1.0 BK -2 0.000 0 11/6/1993 8 5687 5350 Camco KBUG DMY 1.0 BK -2 0.000 0 11/6/1993 SBR 9 6186 5796 Otis WB DMY 1.0 BK -2 0.000 0 3/1/1988 (6:3.500) ) 500 OD Injection Mandrels/Valves :3. St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv PKR Mfr Run Cmnt "'' '' PKR , Or- -.m.. : ®. 5 10 6289 5887 Camco KBUG HFCV 0.0 BTM 0.000 0 8/8/2006 O.en 00:6.156) 11 6357 5947 Camco KBUG HVCV 0.0 BTM 0.000 0 8/8/2006 Open 12 6500 6071 Camco KBUG DMY 0.0 BK 0.000 0 9/18/1993 Closed Other. .1u ,s, = .ui..,etc. - JEWELRY • ems` Depth ND Type Description ID 1791 1791 SSSV Camco TRDP -1A 2.813 6227 5833 SBR Camco OEJ 2.813 ®ate ;! 6250 5853 PKR Camco HRP -1SP 2.875 6522 6089 PKR Baker'FB -1' 3.000 6540 6104 NIP Camco 'D' Nipple NO GO 2.750 6540 6104 NIP AVA; Set on 9/20/93 2.250 REDUCER TUBING 6551 6114 SOS Camco 2.992 (600.3.500500, , I I 6552 6115 TTL 2.992 00:3. 10:2.992) Other •Iu.s, :.ui•., etc. - PATCH Depth ND Type Description ID .• 6475 6049 PATCH 12.3' Merle Tubin. Patch; Set on 9/26/93 2.375 .. Fish - FISH Depth Description Comment < 6785 5" Geo -Vann 365.88' long PKR v :: •.. General Notes (6522 -6523, r ;;:: III : .: m 00.6 .156) Date Note 1/12/1997 Tubin. LEAK • Tubin. Patch 6475-6486' 7/21/1999 Sus.ect CSM . 6357' RKB ma be flow cut & leakin.; see WSR 7/21/99 7/27/2006 CASING LEAK DETECTED . 6060' ELMD SOS -- (6551 -6552, iiimarassam 00:3.500) MENE Pert i (6603-6607) , 5" Geo-Vann (6785 -6786, i II 0 1 OD: 2 000) Re: FW: lY-05 (PTD 1830870) failed 4 yr MIT . . Marie, It is not necessary to rerun the plug. The information developed by your field people is acceptable. The monitoring information that will be gathered and submitted when the well is back in operation will be the true indicator oftubing integrity. While it is uncertain if the inspector would have been available to witness the MIT, the opportunity to witness should be given. Call or message with any questions. Tom Maunder, PE AOGCC NSKProblem Well Supvwrote, On 8/16/20061:41 p~CANNEº '\UG 1¡~! Tom & Jim, I just realized I mixed up 1Y-05's failure mode with 2K-22. 2K-22 is the well with the leaking packer. 1Y-05 has a casing leak above the packer at 6060'. I've revised the email below for that correction. Please delete the prior email and replace with the corrected one below. The MIT form contained correct information and did not require revision. Sorry for any inconvenience, Marie -----Original Message----- From: NSK Problem Well Supv Sent: Wednesday, August 16, 2006 1:08 PM To: 'Thomas Maunder'; 'James Regg'; 'bob fleckenstein@admin.state.ak.us' Subject: RE: 1 V-OS (PTD 1830870) failed 4 yr MIT Tom & Jim, 1Y-05's failed 4 yr MIT on 7/17/06 was due to a casing leak above the packer at 6250'. An MITT on 7/23/06 with a WRP set just below the packer at 6273' passed. Results of that MITT are attached. An LDl completed on 7/27/06 identified 100% of the IA injection wa going out a hole in the casing at 6060'. The LDL was performed while injecting diesel at 0.25 BPM at 2300 psi. CPAI has completed diagnostic testing and is ready to submit an administrative relief request to resume water only injection with a routine diagnostic testing proposal to verify injection remains in-zone. The WRP was pulled after the MITT was completed on 7/23/06 prior to obtaining an AOGCC witness. Typically, CPAI has provided AOGCC the opportunity to witness the MITT prior to requesting a variance. Is an AOGCC witness of the MITT required prior to approval of an AA, or is the attached in-house test sufficient? If a witnessed test is required, the WRP will be reran at a cost of approximately $20M to CPAI to allow the inspector an opportunity to witness the MIT. Marie McConnell Problem Well Supervisor 659-7224 100 8/16/20062:49 PM Re: FW: lY-05 (PTD 1830870) failed 4 yr MIT . -----Original Message----- From: NSK Problem Well Supv Sent: Friday, July 21, 2006 1 :09 PM To: 'Thomas Maunder' Cc: NSK Problem Well Supv Subject: RE: KRU 1Q & 1 Y 4 yr MIT results . Tom: As per your questions--- 1Y-05: 1. There is minor IA x OA communication that requires a bleed approximately 1 time per month to keep a differential between the IA and OA. Considerable work has been done on the packoffs, and whatever small leak is there is not suspected to be in the wellhead. It appears to be downhole. 2. I am not sure what you mean by final pressures--the current pressures are 11671700/650 psi with the well shut-in. The plan forward is to set a tubing plug and perform MITT, MITIA & CMIT T x IA to determine where the leak is at. You will be notified prior to any startup on the well. Let me know if you want additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] Sent: Wednesday, July 19, 2006 7:33 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: KRU 1Q & 1 Y 4 yr MIT results Thanks Marie, As you might imagine, some questions: 1 Y -05: 1. Based on the TIO plot, it would appear that the IA and OA are in communication. Is that so? 2. What were the final pressures on the well? Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 7/18/20069:56 PM: Tom, Jim, & Bob, Attached are 4 yr injector MIT reports for 1Y and 10 as witnessed by AOGCC inspector Chuck Scheve. All wells passed except for 10-11 and 1Y-05. 1Y-05 (PTD 1830870) pressured up to 2800 psi, then broke down establishing a leak rate of 0.75 BPM @ 2570 psi. A tbg or packer leak is suspected, diagnostics will be completed to evaluate repair options. The well was SI and added to the failed MITIA report until repaired. 20f3 8/16/20062:49 PM Re: FW: lY-05 (PTD 1830870) failed 4 yr i . A repair plan or AA will be submitted once diagnostics are completed. A wellbore schematic and 90 day TIO plot is attached. Please let me know if there are any questions. I will be leaving on 7/19 for 3 weeks. Jerry Dethlefs will be filling in for my vacation from 7/19 to 7/26 when my alternate Perry Klein returns. Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 10 PAD 07-17-06.xls» «10-11.pdf» «10-11 90 day TIO 7-18-06 .doc» «MIT KRU 1Y PAD 07-17-06.xls» «1Y-05.pdf» «1Y-05 90 day TIO 7-18-06 .doc» 3 of3 8/16/20062:49 PM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConoeoPhillips Alaska Inc. West Sak 1 KRU 11Y-05 07/23/06 Evan Reilly- Orbis Packer Depth Pretest Initial 15 Min. 30 Min. Welll1Y-05 I Type Inj. I N TVD I 5,853' Tubing 300 2500 2500 2500 Interval I 0 PTD.11830870 I Type test I P Test psil 1500 Casing 560 620 620 620 P/FI P Notes: Diagnostic MITT with WRP in tubing at 6273' OA 480 480 480 480 Welll1Y-05 I Type Inj. I N TVD I 5,853' Tubing 2500 2500 Interval! 0 P.T.D. 1830870 I Type test I P Test psil 1500 Casing 620 2500 P/FI F Notes: IA LLR of 0.75 BPM @ 2500 psi established while OA 480 480 injecting diesel down IA with WRP in tbg at 6273'. Weill I Type Inj.1 TVD I Tubing Intervall P.T,D.I I Type testl Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Intervall PTD.I I Type testl Test psi I Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test I Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) MIT KRU 1Y-05 07-23-06-1.xls Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnkén 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk . Date BL Color CD RECEIVED AUG () ð 2006 08/01/06 Schlumbepgep ~ On & Gas Cons. comm~o Ancr.·orc:ge '-'ç" \·~¡NE\.t Schlumberger -DCS ::J¡ !¡ .\'. ," 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth '> < ,; rYí\ns ,\ 'u (' : d. !.,.'" ,. ;._\ ç. "L -l- NO. 3899 U:IG 1/63 -OD~' Well Job# Log Description 1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1 D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1 G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1 D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1 R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1 D-1 07 11216309 INJECTION PROFILE 07/12/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1 1Y -05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . RE: KRU 1Q & lY 4 yr MIT results • • Subject: RE: KRU 1Q & lY 4 yr MIT results From: NSK Problem Well Supv <n1617@conocophillips.com> Hate: Wed, 19 ;Iui 2006 10:24:54 -0800 "Co: Thomas R~taunder ~~=tom maunder(ciadmin.stair.ak.us== CC: Jim LZe~~~~ <jiirlr~~~~«r~admin.state.ak.u5=. Tom, Wellwork histories for both wells attached. Marie McConnell Problem Well Supervisor 659-7224 ~~°'~~ ~~~-0~~1 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, July 19, 2006 8:05 AM To: NSK Problem Well Supv Cc: Jim Regg ~~.-'~,:~i .j~.~~ .4k, ~~1'~i Subject: Re: KRU 1Q & 1Y 4 yr MIT results Marie, Further on these wells. I have looked at the well files and there isn't much in them. Last information for 1Q-11 is the 404 when it was converted to injection in January 1985. For lY-OS the last information aside from an MIT from 2004 is November 1993. Is it possible to pull the "event summary" for the wells and send it in? Thanks in advance. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 7/19/2006 7:33 AM: Thanks Marie, As you might imagine, some questions: 1Q-11: 1. Was the fluid level at 550' after pumping the 11.4 bbls? If that is so, the original fluid level could have been nearly 1000' down. 2. Was any gas encountered when the pumping equipment was set up? 3. Looking at the TIO plot, the IA pressure is constant throughout the period. Do you think that pressure is valid? -~~. 1. Based on the TIO plot, it would appear that the IA and OA are in communication. Is that so? 2. What were the final pressures on the well? Tom Maunder; PE AOGCC NSK Problem Well Supv wrote, On 7/18/2006 9:56 PM: Tom, Jim, & Bob, 1 of 2 9/11!2006 3:29 PM RE: KRU 1Q & lY 4 yr MIT results • • Attached are 4 yr injector MIT reports for 1Y and 1Q as witnessed by AOGCC inspector Chuck Scheve. All wells passed except for 1Q-11 and 1Y-05. 1Q-11 (PTD 1841990} did not pressure up after 11.4 bbls were pumped down the IA. The IA FL was found at 550', needing an estimated 15 bbls to load. The well remains on line while diagnostics are in progress. CPAI plans to repeat the witnessed MITIA after it has been loaded. The well was added to the failed MITIA report until a passing MITIA is witnessed. A wellbore schematic and 90 day TIO plot is attached. 1Y-05 (PTD 1830870) pressured up to 2800 psi, then broke down establishing a leak rate of 0.75 BPM @ 2570 psi. A tbg or packer leak is suspected, diagnostics will be completed to evaluate repair options. The well was SI and added to the failed MITIA report until repaired. A repair plan or AA will be submitted once diagnostics are completed. A wellbore schematic and 90 day TIO plot is attached. Please let me know if there are any questions. I will be leaving on 7/19 for 3 weeks. Jerry Dethlefs will be filling in for my vacation from 7/19 to 7/26 when my alternate Perry Klein returns. Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 1 Q PAD 07-17-06.x1s» «1 Q-11.pdf» «1 Q-11 90 day TIO 7-18-06 .doc» «MIT KRU 1Y PAD 07-17-06.x1s» «1Y-05.pdf» «1Y-05 90 day TIO 7-18-06 .doc» Content-Description: 1Q-11 Wellwork history 7-19-06.pdf 1Q-11 Wellwork history 7-19-06.pdf !Content-Type: application octet-stream lY-OS Wellwork history 7-19-06.pdf Content-Encoding: base64 Content-Description: lY-OS Wellwork history 7-19-06.pdf Content-Type: application/octet-stream Content-Encoding: base64 2 of 2 9/11/2006 3:29 PM • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein~admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder~admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk! KRU / 1Y 07/17/06 Rogers/Sauvageau - ASRC Chuck Scheve Packer De th Pretest Initial 15 Min. 30 Min. Well 1Y-01 T e In'. W TVD 5,889' Tubin 1950 1950 1950 1950 Interval 4 P.T.D. 1830500 T e test P Test si 1500 Casin 650 2740 2680 2680 P/F P Notes: OA 260 400 400 400 Well 1Y-02 T e In'. W TVD 5,906' Tubin 1425 1425 1425 1425 Interval 4 P.T.D. 1830590 T pe test P Test si 1500 Casing 650 2580 2550 2550 P/F P Notes: OA 320 450 450 450 Well 1Y-03 T e In'. W TVD 5,888' Tubing 2060 2140 2140 2140 Interval 4 P.T.D. 1830610 T pe test P Test si 1500 Casing 1150 2680 2630 2620 P/F P Notes: OA 380 420 420 420 Well 1Y-04 T pe In'. W TVD 5,914' Tubing 1345 1345 1345 1345 Interval 4 P.T.D. 1830660 T e test P Test si 1500 Casin 1060 2170 2050 2030 P/F Notes: OA 190 190 190 190 Well 1Y-05 T e In'. W TVD 5,853' Tubin 2130 2190 Interval 4 P.T.D. 1830870 T e test P Test si 1500 Casin 1080 2800 P/F F Notes: Witness waived OA 970 Pressured u to 2800 si and broke down. Established IA LLR of .75 b m 2570 si Well 1Y-07 T e In~. W TVD 5,847' Tubin 1870 1880 1880 1880 Interval 4 P.T.D. 1830680 T e test P Test si 1500 Casin 960 2600 2550 2530 P/F P Notes: Witness waived OA 140 160 160 160 Well 1Y-08 T e Inj. W TVD 5,822' Tubin 1920 1920 1920 1920 Interval 4 P.T.D. 1830620 T e test P Test si 1500 Casin 260 2600 2530 2500 P/F P Notes: Witness waived OA 140 140 140 140 Well 1Y-09 T e In'. W TVD 5,821' Tubin 1390 1390 1390 1390 Interval 4 P.T.D. 1830520 T e test P Test si 1500 Casin 560 2250 2190 2180 P/F P Notes: Witness waived OA 40 50 50 50 Well 1Y-10 T e In'. W TVD 4,413' Tubing 1750 1750 1750 1750 Interval 4 P.T.D. 1830510 T e test P Test si 1500 Casing 550 2590 2540 2520 P/F P Notes: Witness waived OA 0 160 160 160 Well 1Y-11 T e In'. W TVD 5,860' Tubin 1400 1400 1400 1400 Interval 4 P.T.D. 1830410 T e test P Test si 1500 Casin 700 2270 2240 2240 P/F P MIT Report Form BFL 911/05 MIT KRU tY PAD 07-17-06-4.xls ConocoPhillips Well History 1 Y-05 API / UWI Field Name 5002920966 KUPARUK RIVER UNIT Well Type Original KB Elevation (ft) Well Status Legal We1lName Well Services 96.00 INJ 1Y-05 Daily ©perations Lanai Start Llata WeIIPJani= ;:FE: RFE Last 24Fr Sum Sup2rw <rK 10/2/2005 1Y 05 10083609 MITOA- passed. LOVELAND [ANN COM ISSUES, WH Maintenance] 9111/2005 tY-05 10037643 PULLED DGLV'S FP.OM STA # 10 AND 11 {NOTE: BOTH DGLV'S SHOWING SIGNS OF WOODS EROSION BETWEEN PACKING STACKS 1. SET 1"" BTP~t LATCH DPHFCV'S IN STA @ # 1 0 i AND#11. [Erosion, GLV] 7/27/2005 1Y-05 10086352 (PROF STARCK A/C SPLIT: 10% A SAND AND 90% C SAND TOP OF PATCH AT 6472' IS LEAKING [Prod-Inj Profile] 7/17/2005 1Y-05 10067643 TAG FILL @ 6635' RKB. EST 35' OF FILL. PULLED 1"" CV'S @ 6289' ~ 6357' RKB, BOTH !SENDEN HAD MODERATE EROSTION. SET DV'S IN THE SAME. JOB COMPLETE. [Open-Close C Sand, Tag] 5x29/2003 1Y 05 10029324 IC hanger Seal tite treatment to 3300 psi. PPPOT-IC. passed. LOVELAND (ANN COM ISSUES. WH Maintenance] 1515/2003 1 Y-05 10029324 Sealtite followup T & IC PO with hydraulic fluid LOVELAND [hVH Maintenance] 7/11/2002 1Y-05 WCW.K02.KR9... TAGGED @ 6674' RKB, EST. 4' RATHOLE. PULLED CVs @ 6289' & 6357' RKB (MINOR FITZPATRICK EROSION). SET CVs @ SAME. CONFIRMED SSSV NOT LEAKING DOWN HOLE, SUSPECT PANEL. CLOSURE TEST SSSV, GOOD. [SSSV Work, Erosion] 2/25/2002 1 Y-05 K85486 Sealtite followup T & IC PO NEZATICKY [WH Maintenance] 11/5/2001 1Y-05 K85329 Seal tite followup IC & T PO NEZATICKY [WH Maintenance] '110115/2001 1 Y-05 K85329 Sealtite follow-up on T R IC packoffs DETHLEFS [V~JH Maintenance] 6/18/2001 1Y-05 K85329 PDST SEAL-TITE OFT & IC PO'S NEZATICKY [Maintenance, WH Maintenance] ~ 4!2112001 1Y 05 K85329 SEAL-TITE FOLLOW UP, STING INTO VOID AND PPPOT-IC TO 3000# WITH GLY-FLOW. ODELL ' LOST 200# IN 15 MINUTES. PRESSURE UP TO 3000# AND RDMO [Maintenance, WH Maintenance] 4/20/2001 1Y-05 K85329 SEAL-TITE FOLLOW UP ON IC PO, PRESSURE UP PO TO 3000# WITH GLY-PLO AND ODELL BLEED DOWN OA FOR MONITORING [Maintenance, WH Maintenance] 4!19/2001 1Y-05 K85329 POST SEAL-TITE Tr~EATM~NT FOLLUW'UP, PRESSUFt~'i)P iCPO TO 3000# AND ODELL TUBING PO TO 4300# WITH GLY-FLO [Maintenance. WH Maintenance] 4/4/2001 1 Y-05 K85329 POST SEAL-TITE FOLLOW UP. PRESSURE UP IG AND TUBING PACKOFF WITH NEZATICKY GLY-FLOW. [Maintenance, WH Maintenance] ?!31!2Q01 !1Y-05 'K?5329 TREAT IC AND TUBING PACKOFF WITt-t'SEAL-TITE. GLY-PEON! ',DETHLEFS [Maintenance. ~NH Maintenance] 3/22/2001 1Y-05 K85329 MITIA/LLR, PASSED 30 MINUTE MIT WITH '0' PSI LOSS. PPPOT-IC PASSED @ 3000#, DETHLEFS POT-IC FAILED, TORQUE LDS. POT-IC FAILED. POT-T, PASSED. [Maintenance, MIT] 1217!2000 1Y 05 K85236 MIT O.A. TO 1500# FOR ANN COM. O.A. PASSED 30 MIN TEST W/ '0' PSI LOST. O.A. 'bETHLEFS WAS BLED DOWN TO 750# AND WOULD NOT BLEED FURTHER. [Maintenance. MIT, PTTbg-Csg] 11/5/19b9 1Y-05 K85177 AC EVAL: POT-T PASSED, POT-IL PASSED SCHUDEL [WH Maintenance] 8x'4/1999 1Y-05 K85176 SPLITS AS FOLLOWS: 'C"" SAND 6381'-6472' = 71%: A5 SAND 6603'-660T = 17.4%; A4 FERGUSON SAND 6618'-6638' = 11.6%; A3 SAND 6657'-6670' COVERED WITH FILL. TAG PBTD @ 6635' [Prod-inj Profile] 7!31/1559 1 Y-05 K85 i 76 TAGGED FILL @ 6633' RKB. EST. 3T FILL OVER BTM PERF (A SAND PERPS 6603'-6670' CHANEY RKB). OPEND C SAND W/ CV'S @ 6289' & 6357' RKB. [Tag, Open-Close C Sand] www.peloton.com Page 1/2 Report Printed: 7/19/2006 ConocoPhillips Well History 1 Y-05 API I UWI Field Name 5002920966 KUPARUK RIVER UNIT Well Type Original KB Elevation (ft) Well Status Legal WeIlName Well Services 96.00 INJ 1Y-05 Daily ©perations ~~aai Start Date ~ 'T~eII~Jarrie ,~FE / BFE Last 2ahrSum Supernsw 7126/1999 1Y-05 K85174 CLEANED OUT FILL USING SLICK SW AND DIESEL FROM 6622' RKB TO 6755' RKB GOBER [FCO] 7!21/1999 11'-05 K85176 .TAGGED FILL @ 6628' RKB, EST 42' OF FILL, 5ET DV'S c~Zi 6289' RKB & 6357' RKB. JOHNS SUSPECT CSM @ 6357' RKB MAY BE FLOW CUT AND LEAKING, SEE WSR, JOB COMPLETE. [Open-Close C Sand] 7B/1999 1Y 05 K85176 DRIFTED TBG (2.10"") & TAGGED FILL a 6633' RKB_ EST. 37' FILL. FITZPATRICK [Tay] 9118!1998 1Y-05 KAb'VWRK TAGGED FILL @ 6650' RKB.SET CV'S ct 6289', 6357 RKB. Sti-11TH [Scale, TaG) 6/14/1997 1Y-05 KAWWRK PRESS TEST TUBING HANGER TU 3000 PSI. 30 MIN PRESS 3000 PSI. PASS. JORDAN PRESS TEST CASING HANGER TO 3000 PSI. 30 MIN PRESS 2750 PSI. PASS. 5J1211997 1Y-05 KAWWP.K OPEN ""C"" SD @ 6253' ~ 6320' RKB. SMITH 9/12/1957 tY-05 KA~WVRK PT TUBING,LOGi+TE TU61NG LEAK,POSSf6LE TUBING LEAK @ TUBING PATCH SMITH 6475'-6486' 11114/1996 1Y-05 KAWWRK TAGGED FILL @ 6665' RKB. PULLED 1"" CV'S & SET 1""DV'S a 6253' & 6320' RKB. SMITH INSPECTED CV'S MINOR EROSION. ""C'"' SAND ISOLATED. ~9J24/1995 1 Y-05 SAFETY VALVE TEST ZUSPAN i 7/5/1995 1Y-05 TAGGED FILL AT 6703'RKB. EST. OF 33' RATHOLE BELOW^J BOTTOM PERF. CHECKED SMITH CV'S AT E320'RKB AND 6253'RKB. NO P~IAJOR ERROSION OR SCALE DETECTED. 2/5/1995 1Y-05 FAILED STATE TEST. HOT OILED SSSV PRE-TST_ 2500. INIT=FINAL=500. NO W/L REQ'D FITZPATRICK I 1/14/1995 1Y-05 OPENED C SAND. PULLED DVS @ 6253' AND 6320' RKB. SET CVS @ 6253' AND 6320' CHAMBERS RKE. rnSnaaa ~.rr-ua vrtrv v arirvu. Irv rR~uRCaa. l..rl/iNIDCRJ www.peloton.com Page 2/2 Report Printed: 7/19/2006 MEMORANDUM State of Alaska Alaska Oil and Gas Consenation Commission TO: Jim Regg PJ. Supervisor -> K~H {;{ Z« ICir DA TE: Wednesday. June 23. 20~ SlIBJECT: Mechaßl~allntegrity Tests CONOCOPHlLUPS ALASKA INC FROM: Chuck Scheve Petroleum Inspector 1 '1'-05 KUPARUK RIV UN1T 1'1'-05 Src: Inspector Reviewed B,r: P.I. Supnr --~ Comm NON-CONFIDENTIAL Well Name: KUPARUI\. RIV UNIT I Y-OS Insp Num: mitCS040619211255 Rellnsp Num: API Well Number: 50-029-20966-00-00 Permit Number: 183-087-0 Inspector Name: Chuck Scheve Inspection Date: 6/19/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I Y-05 Type Inj. P TVD 6687 IA ]080 1840 1790 1750 17-10 P.T. 1830870 TypeTest SPT Test psi )46325 OA 1000 1020 1030 10-10 10-10 Inten'al -1YRTST PIF P Tubing 2050 2050 2050 2050 2050 Notes: Pretest pressures observed for 30+ minutes and found stable. Tags on the annulus valves indicate this is a problem well. keep OA below 1000 psi. keep IA below 2000 psi. Pressures during this test indicate possible slow leak 1:\ to OA at higher differential pressures. No internal waiver posted J\jo A.[GCC (:(PfrLJ\X:cJ ~L.l.Ilc\;(}- é (,~ (v~r) . 5Bt-- Wednesday. June 23. 2004 Page 1 of I ARCO Alaska, Inc. Post Office E. 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 29 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. JohnstOn: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION . ~0'5"~? 1Y-05 Other (conversion) ¢~ ¢.-?O 1Y-22 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI~N REPORT OF SUNDRY WELL OPERATIONS feet 1. Operations Performed: Operation Shutdown Stimulate ~ Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service 571' FNL, 1911' FWL, Sec. 1, T11N, R10E, UM At top of productive interval 1305' FNL, 1897' FEL, Sec. 1, T11N, R10E, UM At effective deplh 1650' FNL, 1568' FEL, Sec. 1, T11N, R10E, UM At total depth 1708' FNLr 1524' FELt Sec. 1~ T11N~ R10E~ U.M 12. Present well condition summary Total Depth: measured 7 2 6 6 feet true vertical 6687 feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-05 9. Permit number/approval number 83-87/93-254 10. APl number so-0zg-20966 11. F~eld/Pool ,Kuparuk River Oil Field/Pool Plugs (measured) Nolle Effective depth: measured 6 5 2 6 feet true vertical 6 0 9 2 feet Junk (measured) 366' Vann Gun, top @ 6785' Casing Length Size Cemented Structural Conductor 73' 1 6" 270 Sx AS II Surface 2172' 9 5/8" 700 Sx AS III & Measured depth True vertical depth 73' 73' 2205' 2205' Intermediate 250 Sx AS I Production 7203' 7" 600 Sx Class G & Liner 250 Sx AS I Perforation depth: measured 6381 '-6472', 6603'-6607', 6618'-6638', true vertical 5968'-6047', 61 58'-6161', 6170'-6187', 7232' 6660' 6657'-667O' 6203'-6213' Tubing (size, grade, and measured depth) 3.5", 9.2 /f/ft., J-55 @ 6532' Packers and SSSV (type and measured depth) PKR's: Baker 'FB-I' @ 6523', Camco HRP-1SP @ 6216'; SSSV: Camco TRDP-I~ @ .1.7-q1,', o ,, ~ 13. Stimulation or cement squeeze summary ~1~ 1' t:. I: I V I:: IJ 14. Converted well from oil producer to MWAG injector on 11/17/93. Intervals treated (measured) N/A DEC - 1 1993 Treatment description including volumes used and final pressure AlaSka IJil & Gas ~ ~,eat~a~ N/A R~oresentative Daily Average Production or Injection Data ~"~al~ OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1 0 2 2 570 2172 1239 208 ~,~-- 0 0 4000 1350 2300 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service MWAG Ini. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned '~~~' ~/'~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE t&DGS ,',' .... ,'.iN~ WELL REPORT FOR !'i/1"/,'93 DR IL.I__S i TE 'LY PRODUCTION [-JELL STATUS :.~,.',:=, LIFT STATUS IOOF', = .15000 ._,c'i DATA CHOKE 7" OR - WC H2S CSG CSG % FTP FTT % PPM PSI PSI OAS GAS 1.1",.1 d OP 'l' OP 'f' METER VOL RATE GL READING MSCF MSCFD ROOTS C hi M 0 R I D S N E 6 8 SI 0 OM OM 91 65 0 0 16 A PR 176 180 88M 3 65 400 400 17 C °R, 176 189 1~9 9'7. 50 i~z-O~= 0 18 B SI 0 OM OM 0 19 B SI 0 OM OM 0 21B SI 0 OM OM 0 22 A PR 176 202 108 27 23 A SI 0 1024 49 76 24 B SI 0 OM OM 0 0 1.50 0 0 0 0 0 0 0 0 680 750 0 i .500 800 0 500 0 25 B PR 176 192 108 40 65 1500 625 ' 26 B PR 176 191 128 72 40 1300 27 B SI 0 OM OM 0 0 0 0 28 C TS 176 225 125 94 0 1300 1100R 29 C PR 176 248 128 74 55 2650R 200 30 B PR 176 193 139 85 80 1820 800 31 B SI 0 'OM OM 0 0 1100 0 32 B PR 176 225M 142 83 110 1350 1640R 34 ~ SI 0 OM OM 0 0 350 0 0 0 0 0.0 2400 75 0 600M 521 O. 0 0000 0 0 1018 i000 3.7 (1000 0 0 0 0 0.0 2400 0 (} 0 0 O.O 2400 0 0 0 0 0.0 2400 0 0 0 0 0.0 0000 0 0 90 0 O. 0 21.00 29 0 0 0 0.0 2400 0 0 1207 1146 ~. 5 0000 0 0 OM 0 OM 0 600M 0 0 0 OM 0 0 0 384 0 0 36 0. 1 0000 O 0 O. 0 '.:)400 0 0 0 0 0000 0 0 0, (} (1000 0 0 O. 0 0000 0 _ 0 O. 0 ;--2400 0 0 O. 0 0000 0 0 O. 0 2400 ! I TOTALS' 3899 2703 INJECTION WELL STATUS INJECTION VOLUMES S I DATA W Z S WATER RECMD OAS E 0 T CHOKE 7" I0" INJ INJ INJ L N A OR INJ CS~ CS~ METER VOL RATE VOL L E T % PSI FTT PSI PSI READING BBLS BWPD MMSCF C H M 0 R I D S N E I B PW 100 2246 152 1200 600 ~e~'? 0 4331 5241- 0.000 0000 0 2 B MI 25 2745 95 0 0 e(o~\¢~s 0 0 0 6.937 0000 0 3 B PW 100 2213 154 1100 400 0 4556 9461~ 0.000 0000 0 4 B'PW 100 2254 153 1050 ~ 0 4741 6250~ 0.000 0000 0 (5 A PW 15 O 0 2500~ OW 7 B MI 25 2936 95 0 0 8 B PW 100 2248 153 700 500 9 B PW 100 2218 151 950 650 10 B PW 100 2198 206 1000 350 11B PW 100 2200M 152 2700R 400 12 B PW 100 2188 152 1800~ 950 13 B PW 15 0 0 900 260 14 A PW 100 2209 153 1700 800 15 B PW 15 0 0 1500R 1300~ 0 lO00M O~ 0.000 1445 70-~) 0 0 0 6.943 0000 0 0 4995 6008 0.000 0000 0 0 4061 3981~ 0.000 0000 0 0 9538 2690 0.000 0000 0 0 2154 1768 0.000 0000 0 0 4170 1468 0.000 0000 0 0 IO00M O~ 0.000 1200 36 212537 1999M 2798~ 0.000 0000 0 0 1000M 0~ 0.000 1430 36 AN * AFTER THE RECOMMENDED WATER INJECTION RATE INDICATES THAT THE DEC - ] 199~ Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate are multiple Applications for Sundry Approval on the following Kuparuk wells. Well Action Anticipated Start Date Y-03 Change Program 9/93 Y-05 Change Program 9/93 B-07 Variance 10/93 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECE!V Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C STATE OF ALASKA '""" ALASKA OIL AND GAS CONSERVATION COMMI,_...,ON APPLICATION FOR SUNDRY APPROVALS 11. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well Plugging Time extension Stimulate Change approved program X_~_ -Pulltubing v-- Variance__ -~erforate __ --Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development __ ,~/,,J AR(;;O Alaska. Inc. Exploratory _ RKB 96 feet 3. Address P. O. Box 100360, Anchorage, AK 99510 Stratigraphic Service 4. Location of well at surface 571' FNL, 1911' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1305' FNL, 1897' FEL, Sec. 1, T11N, R9E, UM At effective depth 1285' FNL, 1858' FEL, Sec. 1, T11N, R9E, UM At total depth 1708' FNL, 1524' FEL, Sec. 1, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 7 2 6 6 true vertical 6687 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-05 9. Permit number 83-87 10. APl number 50-029-20966 11. Field/Pool Kuparuk River Oil Field/Pool feet Plugs (measured) None feet Effective depth: measured 6 5 2 6 true vertical 6092 feet feet Junk (measured) 366' Vann Gun, top @ 6785' Casing Length Size Structural Conductor 7 3' 1 6" Surface 2 1 7 2' 9.6 2 5" Intermediate Production 7203' 7" Liner Perforation depth: measured 6381'-6472', true vertical 5968'-6047', Tubing (size, grade, and measured depth) 3 1/2", 9.2#, J-55 @ 6532' Cemented Measured depth True vertical depth 270 Sx AS II 73' 73' 700 Sx AS Iii & 2205' 2205' 250 Sx AS I 600 Sx Class G & 7232' 6660' 250 Sx AS I 6603'-6607', 6618'-6638', 6158'-6161', 6170'-6187', 6657'-6670' 6203'-6213' p ,ECEIVED s E F' 2 2 199; :alaska Oil & ,3as Cons. Cornrr Packers and SSSV (type and measured depth) Anchorage PKR: Baker 'FB-I' @ 6523', Camco HRP-1SP @ 6216'; SSSV: Camco TRDP-1A @ 1791' 13. Attachments Description summary of proposal X Connvert oil producer to MWAG injector. 14. Estimated date for commencing operation 15. September 1993 16. If proposal was verbally approved Name ofnapprover Date approved Service M WA G 17. I heret~)certify thatt{he fore~e and correct to the best of my knowledge. Si~ned 'V/~~ ~,'~/ ~' Detailed operation program _ BOP sketch Status of well classification as: Oil __ Gas__ Suspended __ Injector Title Senior Encjineeer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance __ Mechanical Integrity Test t,,"" Subsequent form require 10-...~O~ -- .;~ppruged Copy Returned Original $_~gned By ¢-;~ 3'-2.~, Approved by order of the Commission David W. Johnston Commissioner Form 10-403 Rev 06/15/85 JAppro_val No. SUBMIT IN TRIPLICATE , Attachment 1 Conversion to Water Injection Kuparuk Well 1Y-05 ARCO Alaska requests approval to convert Well 1Y-05 from an oil producer to an MWAG injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water alternating with miscible gas will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 5968' and 6213' TVD. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure,, and average annulus pressure will be reported to the AOGCC monthly. R ECEIV c Alaska Oil & Gas Cons. Anchorage ..~,,, STATE OF ALASKA -~. ALA,c' ~IL AND GAS CONSERVATION COM"--'~SION - REPORT'UF SUNDRY WELL OF-RATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska,-;[nc. RKB 96.0 Feet 3. Address 6. Unit or Property name P. 0. Box 100360; Anchorage, Alaska 99510 Kuparuk River Unit 4. Location of well at surface 571' FNL, 1911' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1305' FNL, 1897' FEL, Sec. 1, T11N, R9E, UN At effective depth 1285' FNL, 1858' FEL, Sec. 1, T11N, R9E, UM At total depth 1708' FNL, 1524' FEL, Sec. 1, T11N, R9E, Um 7. Well number 1Y-5 8. Approval number 293 9. APl number 5o- 029-209660 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length 7266' feet 6687' feet 6526' feet 6092 feet Size Plugs (measured) 7152' (PBTD) Junk (measured) 6785' Cemented Measured depth True Vertical depth Conductor 73 ' Surface 2205' Production 16" 270 SX AS 11 73" 9.625" 700 SX AS 111 2205' 250 SX AS I 7232' 7" 600 SX Class G 7232' 250 SX AS I Perforation depth: measured 6381 '-6472' 6603'-6607' 6618'-6638' 6657'-6670' true vertical 5968'-6047', 6158'-6161-', 6170'-6187' ,6203'-6213' Tubing (size, grade and measured depth) 3-1/2", J-55, 6532' Packers and SSSV (type and measured depth) Camco TRDI~-IA @ 1791'; Camco HRP-1SP @ 6250'; Baker FB-1 @ 6523' 73' 2205' 6660' 12. Stimulation or cement squeeze summary Intervals treated (measured) 6381'-6472' (C Sand) 13. Treatment description including volumes used and final pressure 86 6bls 12% HC1 acid; 184, 250 SCF N~: 550 n~io Representative Daily Average Production or Inje(~tion-Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 785 375 0 0 200 Subsequent to operation 673 287 0 427 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 Form 10-404 Rev. 1~/!.85 Title ~r_ npe~a~ions E..~.~eer Date Submit in Duplicate *ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT REMARKS JOPER/~TION AT ~EP~RT TIME o 7~o 0~0. -- ~o¥o /,.~5"0 i¥/o I y'qo t~25- .s /,~ J- ,da 15',.,4"7 /¢qS- /¢,s"o /73o /23o le2C oo~ %¢,/ / CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Iq,___., J ~'hlll C'ad,,J,~qJ, J ~lmlkllllv J WJrld VII_ ARCO Alaska, In~ Pos! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 15, 1987 Transmittal ~ :6054 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3C-16 Kuparuk River Unit 'A' Sand 100598H' 8-26 thru30-87 2Z-1 Kuparuk River Unit 'A' Sand 100557H 8-31 thru9-2-87 3Q-2 Kuparuk River Unit PBU 100559H 8-25 thruS-29-87 3M-12 Kuparuk Well Pressure Report(Otis) Static A Sand 9-3-87 3M-13 Kuparuk Well Pressure Report(Otis) Static A Sand 8-28-87 3M-14 Kuparuk Well Pressure Report(Otis) Static A Sand 9-1-87 1Y-14 Kuparuk Well Pressure Report(Camco) C Sand 8-23-87 1Y-6 Kuparuk Well Pressure Report(Otis) 8-21-87 1Y-5 Kuparuk Well Pressure Report(Otis) Static C Sand 8-23-87 1Y-16 Kuparuk Well'Pressure Report (Otis) 8-21-87 1Y-11 Kuparuk Well Pressure Report (Otis) Static 8-21-87 1Y-9 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-3 Kuparuk Well Pressure Report (Otis) Static C Sand 8-22-87 2X-14 Kuparuk Well Pressure Report (Otis) Static C Sand 7-18-87 2Z-1 Kuparuk Well Pressure Report (Otis) Static C Sand 7-2-87 2X-lO Kuparuk Well Pressure Report (Otis) C Sand 7-19-87 Receipt ~cknowledged: DISTRIBUTION: '.~aTte L_../ Anch0rag/z ~aska 0il& Gas. ConsgCommlssl0n D&M ~'Stateof~Alaska BPAE Chevron Mobil SAPC ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfleldCompany Unocal ARCO Alaska, Inr~'''~ Post Office ...ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 2, 1987 Transmittal # 6049 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Y-3 1Y-14 1Y-5 1G-1 1G-7 2D-3 Pressure Report 'A' Sand 8-20-87 100596H Static Gradient Survey 8-20-87 100556Y14 Static Survey 8-20-87 1005551Y5 Kuparuk Well Pressure Report(Camco) 8-24-87 Kuparuk Well Pressure Report 8-24-87 Kuparuk Well Pressure Report(Otis)'C' Sand 8-2-87 ,Alaska Oil & Gas Co~s. Commissi.on Anchorage Receipt Acknowledged: DISTRIBUTION: Date~ BPAE Chevron Mobil SAPC Unocal D&M ARCO Alaska, Inc. is a Subsidiary ol AllanlicRIchfleldCompany STATE OF ALASKA "-- ~-"- AL~-,,.,I~ OIL AND GAS CONSERVATION CO,,.,, SION 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 PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 571' FNL, 1911' FWL, Sec. ! T11N RgE UM At top of productive interval ' ' ' 5. Datum elevation (DF or KB) RKB 96.0 6. Unit or Property name Kuuaruk River Unit, 7. Well number 1Y-5 8. Permit number Permit #83-87 1305' FNL, 1897' FEL, Sec. 1, T1 At effective depth 1285' FNL, 1858' FEL, Sec. 1, T1 1N, R9E, UM 1N, R9E, UM 1N, R9E, UM 9. APl number 50-- 079-209660 10. Pool Kup~ruk River 0il Pool 11. Present well condition summarYTpAA, MD Total depth: measured .... true vertical6687' MD Effective depth: measured 6526' FiD true vertical6092' FiD feet feet feet feet Plugs (measured~' 152 PBTD 6598 ,. Junk (measured) Casing Length Size Structural Conductor 73' 16" Surface 2205' 9-1/4" XXXXX~XXXXX~X. /ntermealate Production 7232 ' 7" x xx~j~g~xxxx Perforation depth: measured true vertical Cemented Measured depth True Vertical depth 270 SX AS11 73' MD 700 SX AS111 2205' MD 250 SX AS1 600 SX Class G 250 SX AS1 7232' MD 73' TVD 6381'-6472' MD, 6603'-6607' MD, 6618'-6638' MD, 6657'-6670' MD RECEIVED Tubing (size, grade and measured depth) -'" J-55 Tubing to 6532' 2 , , Packers and SSSV (type and measured depth) Camco TRDP-IA ~a 1701 '; Camrn FIRP-lgP _fa F;?EFI'~ R~ker FR-1 ¢) 6523' 12.Attachments Description summary of proposal ~ Detailed operations program [] J U L 3 1 1986 Naska 0il & Gas Cons. Commission Anehnr~_~ BOP sketch [] 13. Estimated date for commencing operation August 4, 1986 14. If proposal was verbally approved Name of approver Subsequent Work Reported on Form No.J0- 5/tOq Dated ~//~~ Date approved 15. I hereby certify that the fg. regoing is true and correct to the best of my knowledge Signed /L/~'%t.7. Z~ ~? /~_X?__///tA/f~.~0'- Title Sr. Operations E,§ineer Commission Use Only Dat~Uly 29, 1986 Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner by order of the commission Date~ '"/""~. Form 10-403 Rev 12-1-85 Submit in triplicate 1Y-05 Stimulation Summary It is proposed that the 'C' Sand in Well 1Y-05 be stimulated with a 12% Hydrochloric Acid solution. An approximate volume of 90 bbls of this sol uti on will be pumped into the formation utilizing a coiled tubing unit to spot the acid across the sand. After the acid has been displaced into the formation, the CTU will be used to help ensure flowback of the spent acid. RECEIVED J U L ~ 1 1986 Alaska Oil & Gas Cons. Commission Anchorage Attachment . Page 3 Drill Site Well No. Log Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~_ 6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~~ 5/10/83 ~ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site 2C Well No. Log Date 2C-4 2/19/85 2~28~85 2C-7 10/15/84 '(2Ct.16~121-11.185 Drill Site Well No. Log Date 2Z' ~_Z~/10/83 2Z-2 ': 6/24/83 7/19/83 2Z-3 8/5/83 2Z-4 7/!2/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF-pg-O052 Alaska Oil & Gas Cons. Anchorage Attachment Page 2 Drill Site Well No. Lo9 Date 1H 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Lo9 Date lQ Drill Site 1E Well No. 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Lo.q Date 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Lo9 Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. 1F 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 3/!2/83 1/22/83 .Alaska Oil & Gas Cons. Anchorage 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 1F-7 Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 ATT~cH~EN'T 11 T,U?~,~UY- RIVER U~I'T FEBRUA~ 19, 19B6 7/6/B3 1~-~ 10/~9/83 ~-5 ~1~!8~ 1~-7 5/7/B2 1/19/83 1~-11 3/21/B3 3/B/B2 1A-12 1A-15 5/11/82 1A-16A 6/8/82 519181. 1C-1 5/B/B1 lC-t 7/13/B1 1C-3 11/8/81 1C-~ 319181 1C-5 ::ll/30/B1 1C-6 5/19/B1 1C-7 5/21/$1 1C-B lB-1 15--3 lB-6 lB-7 1B-B 15-9 Lo~ 1D ll)-I ll/16-1B/B! 3/12/82 11/1B/B1 9/10/B2 I~/2~/~ ~/~/~ ~/~/~ 6/~/82 ~1~1~,~ 1I)-3 1D-5 1D-6 19-7 l/Bo 5123/B3 BISIBO 7/30/B0 6/11/81 6/9/81 P~g~ 3 Drill Site Well No. Log Date 1Y ~- 1Y-1 ~1Y-2 --' 1Y-3 '1Y-4 ,,%"1Y-5 1Y-6 .'"'~¥-8 ~1Y--11 1Y-12 '~ 1Y-13 ~1Y-14 '-1Y-15 "lY-16 '""- 6/6/8~ ~10/21/83/ '~6/10/83~-~ %,3/4/84/ ~ 6/18/83 ~ 7/2/83 "~6/29/83 ~6/27/83 ~6/22/83 ~5/~o/83~ ~11/21/8~ %5/25/83 ~5/27/83 ~/13/83~ ~5/18/83/ ' ~/29/83 ',.'5/30/83'-.x ~ '~10/23/83 / ~ Drill Site Well No. Log Date "2Z-1 -~2Z-2 ~,~ '""2Z-3 '"~2Z-4 '~-2Z-6 "~2Z-8 2Z 7/10/83 6/24/83',,,. 7/19/83/ 8/5/83 7/12/83 7/27/83 7/28/83 8/3/83 Drill Site 2C Well No. Log Date --- 2C-4 "'"2/19/85 ~ 2/28/85× '~' 2C-7 X~10/15/84 .! VLF'pg'O029 RECEIVED FEB 2 1 1~86 Alaska' 011 & Gas Cons. Commt~loll Anchorage ARCO Alaska, Inc. Post Offi~'%~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ; DATE: APRIL n-~ TRAN2MITTAL_ NO' 985 i 48 .n,-rTI;PXt TO' ~'..i ........ ;.., ARCO AI..ASI<A, INC. ATTN' RECORDS C.L. ERI< ATO-i i t DB P,O, BOX i0'336£) ANCHORAGE, Al<' 9".75t ¢ HEREt'JITH ~il'~.E TH[: F'OI...LOWIi'-!G ITEHS F' "* ? ' ^" ' , I_E:.H~, E AC'I< RETURN ONE SIL;NED COi-'-'Y OF THIS 'rRANSHI'FTAL, SOE/SBHF'- 'A' & 'C' SANDS STATIC BHF' DATA STATIC BHP DATA STATIC BHP DATA STATIC BHP DATA STATIC BHP DATA STATIC BHF' DATA STATIC BHF' DATA STATIC BFIF' DATA. STATIC BHP DATA ~TATIC r,'HP D,..i;~-i ~TA~-~ ~:,1' IF:' DATA ~TATIC BHF' DATA ,:?TATZC BHF' DATA ~TA~Tm,~,~ BHP, DATA . i ~1 ~iTATIC [,Hr' ?T~TTO p~J~, ~ATA N~ iiIla Iw ~-- } it ~TAT~C BHP DATA- ~TATZC BHP DATA .- STATIC PI-IF' P,~,A STATIC BHF' DATA S'f'ATZC BI-IF' ~*~'~ STATIC BHP DATA · '-'..::- C.-E l P T A · {'1I .'' rI~E !{: ,. C U F.,.:R I E R :;l-il-"- VRO N "".' .%M F'REjSSURE SURVEY 4/6-7185 3/i i/85 ") / ") /.. /0~,, 312/85 ~/~/85 ~/4/85 ~/t 8/85 t/24/85 t/24/8~, · S/~/85 ~/2/85 ~3/2/85 3/2/85 ~/1 9/dp 3/I 9/85 I/2f ~" 3/2~/85 S/24/85 -~'/~6,/85 i /~ a ~/2= _,/8_, ~/26/85 i ,/S/':.., t /i t/P'~ "i/24185 . i/2~'~'~ RECEIVED APR 2 Alaska Oil & Gas_~C0ns. Commission D A T E: . . K. T~LIN/VAULT ~'I2 - ._, TRIBU'FiON DRILLING W. F'A£HER L. :,,,'n'.-'NSTnN, _ . EXXON ~OBI' ,-- F'HILLIPS OIL NS!< CLERK J, RATHHELL ARCO Ala,~ka, Inc. is a Subsidiary of AllanticRichfieldCompan¥ ARCO Alaska, inc. Post Offic~"'~ix 360 Anchorage, ,.daska 99510 Telephone 907 277 5637 Date: 2/05/85 Transmittal No: 4824 RETURN TO: ~CO ALAS~, INC. ATTN: Records Clerk ATO-1115B ~ ' P~. Box 100360 ~,~~chorage,~ 99510 ~// ~r~n~m~tted herewith are the following it~s. and retu~ one signed copy of this transmittal. Please acknowledge receipt PBU SURVEYS & SEQUENCE OF EVENTS --2X-7/ 8/16/84 ~ Gearhart --~2Z-6/ 9/03/84 Otis 2X-6~' 8/16/84 Gearhart --- 2X-4/ 8/16/84 Camco ---2X-iv': 8/16,19/84 Camco · --2V-5/f 8/16,19/84 Dresser ~--2V-2~ 9/07/84 Otis - -2F-9/' 8/28/84 Otis / --2F-8Vz.-10/08/84 Camco / --2F-7~ 10/07/84 Otis ~2B-15/ 9/03/84 Otis ~--2C-5 ~/ 8/17/84 Otis .... 1Y-!3/ 8/16/84 Dresser ~lY-9/' 9/07/84 Camco --1Y-5/ 9/14/84 Camco 1Y-5v 9/06/84 Otis ~lG-6,~ "8/25/84 Otis ~lH-4~ 9/04/84 Otis ~1F-12¥ 9/09/84 Otis ~lF-9 ~ 8/17,18/84 Camco ~lF-8z~ 8/16,17/84 Camco ~-lE-8~/'. 10/12/84 Otis ~lD-5~' 10/07/84 Camco '~lA-4~ 9/02/84 Otis ----lA-3/ 9/02/84 Otis Receipt Acknowledged: "HP 232" 9/06/84 "SBHP" 9/05/84 "Static BHP" 8/17/84 "PBU"" 8/16/84 "PBU" 10/13/84 "SBHP" "E Line" 10/07/84 "Pressure ?alloff" Date: DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc. Post Officr/ 360 Anchorage, ~laska 99510 Telephone 907 277 5637 Date: 11/27/84 Transmittal No: 4868 RETURN TO: ARCO ALASKA, INC. ~ ATTN: Records Clerk ATO-1115B P.O. Box 100360 chorage, AK 99510 itted herewTth are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CBL's/Schlumberger/FINALS "Variable Density" "GCT/JB/GA" 9/19/84 " " " 9/31/84 11 11 If I1 fl 11 l! 11 I! It 1! !! I1 11 11 . · II II .. I! . I1 II 11 11 II II 11 II I1 II II II Il I1 I! 11 "GCT" 10/07/84 " "GCT" 10/07/84 " "GCT/JB/GA" 9/31/84 " "GCT/JB/Ring 9/17/84 " "GA/JB/GCT" 9/19/84 " " 9/17/84 " "GCT" 7/21/84' " "GCT" 9/21/84 " "OCT/GA/JB" 9/14/84 " " ~/15i84 " · "GCT/JC" 10/12/84 " " 1o/15/84 " " 10/12/84 " " lO/13/84 " "GCT/J~/GA" 10/22/84 " " 10/22/84 " "J~/G^" 8/19/84 " " 8/20/84 Run 3 9/21/84 Run l "GCT/JB" 10/14/84 Run 1 " 10/14/84 " " lO/O5/84 " "GCT" 10/05/84 " "Perf 4"~ 9/10/84 Run 2 5 i/2"/PPS/JB" 11/05/84 Run 1 Acoustic "VDL/Signature/GR" /cat Receipt Acknowledged: B. Currier BPAE Chevron DISTRIBUTION · Drilling W. Pasher Geology. /~2~ G. Phillips Mobil Phillips Oil 6597 - 8292 .~2B-3 7000 - 8460 ~/2B-16~' 4950- 7004 ~2B-13vz 5750 - 8408 .~2B-14 5700 - 7970 '~2B-15 5348 - 6824 -2B-2 7250 - 9182 ,~2B-4 5055- 6487 --2B-lv/ 6200 - 7866 f2D-5 6800 - 8954 --2D-6 5054 - 6650 -2D-'7~ 5597 - 8084 --,2D-'8-/ 5650 - 7951 ~2G-9 5840 - 8524 --~G-11~'/ 4940 - 6765 -~2G-lO~/' 5730 - 7950 --2G-12 5790 - 7814 -- 2G-13 5989 - 8624 -2G-14 8650 - 9334 ?.-iF-6 8650 - 9562 5692 - 6742 5150 - 7252 ..~.lL-1 4500 - 6550 ~lL-2~/ 6800- 7518 -1L-4 7000- 8210 --1L-3V/ 7961 - 8941 --2V-8A 6100 - 6992 -~1E-24 Sohio Union D & M NSK Ops. J. Rathmel1 Well Files' ARCO Alaska, Inc. Post Office B~,x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 31, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1Y-5 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L54 Enclosures If RECEIVED NOV 0 5 1. i$ Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 571' FNL, 1971' FWL, Sec.1, TllN, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 96' 12. I 6. Lease Designation and Serial No. ADL 25646 ALK 2577 7. Permit No. 83-87 8. APl Number 50- 029-20966 9. Unit or Lease Name Kgparuk River Uni'r. 10. Well Number 1Y-5 11. Field and Pool Kuparuk River Fi eld Kuparuk River 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 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 Abandonmentsee20 AAC 25.105-170). Accepted rig @ 2200 hrs, 09/17/84. Killed well. ND tree. NU BOPE & tstd to 3000 psi - ok. Pulled tubing & pkr. Ran CBL. Set R-3 pkr ~ 6300'; tstd csg to 3000 psi - ok. Set FB-1W/L pkr @ 6523'WLM. Ran 3-1/2" completion assy w/tail ~ 6532', HRP-1-SP pkr ~ 6250', & SSSV @ 1791'. Dropped ball & set pkr. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/diesel & Kuparuk crude. Set BPV. Secured well & released rig ~ 1300 hfs, 09/23/84. RECEIVED NOV 0 5 Alaska Oil & Gas Cons. CommlssJon Anchorage 14. I hereby ~ that the foregoing is true and correct to the best of my knowledge. /~ ~~ Signed The spac e~,~ ow ~o ~/~/m ission--~ ~'~- ' ~--se Conditions of Appr~al, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev_ 7-1-80 GRU1/SN73 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska,,' Post Ofl,,.~ rlox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 25, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Y-5 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L36 Enclosures If RECEIVED NOV 0 1 ]984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompany · -?' ..... ~' STATE OFALASKA ALAS~.. O,~ANDGASCONSERVATION.. AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-87 .. 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20966 4. Location of well at surface 9. Unit or Lease Name 571' FNL, 1971' FWL, Sec. 1, TllN, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1305' FNL, 1841' FEL, Sec. 1, TllN, R9E, UM 1Y-5 At Total Depth 11. Field and Pool 1708' FNL, 1524" FEL, Sec. 1, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i ] Pool 96' RKBI ADL 25646, ALK 2577 · 12. Date Spudded 05/24/83 13. Date T.D. Reached 05/30/83 14' Date C°mp" Susp' °r Aband' ! 15" Water Depth' if 0ffsh°re 116' N°' °f C°mpleti°ns. 06/13/83 N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set [ 21. Thickness of Permafrost 7266'ND,6687'TVD 7.152'HD,6598'TVD YES [] NO [] 1791 feet MDI 1350' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/FDC/CNL/Cal, BHCS/GR/Cal, CBL/GR/CCL/VDL, Gyro, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf ~73'~ 24" 270 sx AS II 9-5/8" 40.0# J-55 Surf 2205' 12-1/4" 700 sx AS Ill & 250 sx AS I 7" 26.0# J-55 Surf 7232' 8-1/2" 600 sx Class G & 250 s; AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6381' - 6472' 3-1/2" 6532' 6250' & 6523'WLM 6603' - 6607' 6618' - 6638' w/12 spf 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 6657' - 6670' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~l~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED NOV o Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 GRU1/WC21 Submit in duplicate Rev. 7-1~80 CONTINUED ON REVERSE SIDE .. .-.'~:~ ~L__:~ ..,.:.' ~;~.,_.rI ::!-. ~-EOLOGi-.c~:MAi~Ii~:~i~I§~ : ;:~ :~...!~. ;:...' ? ~¢:.: .,?~.;~,~. '::2; t' :',; ~:L' ,?. r'~ ,':,,,':' ?~F~O~MATTi~N'¥~T8 ........ . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH . GOR, and time of each phase. _ · Top Upper Sand 6381' 5968' Base Upper Sand 6462' ~ 6038' Top Lower Sand -6594' 6150' N/A Base Lower Sand ,6700' - 6238' : . . 31. LIST OF ATTACHMENTS Wnrl~nv~_r Wml 1 Hi.~tnry 32. I hereby certify th.~t the foregoing is true and correct to the best of my knowledge Signed _ Title ~,,~ n.¢~;~,. ~,,. Date /7 .............. '-""' ,, /_,, 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) fo'r depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a'separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Atlantic.ichfieldCompany Dally Well History-Initial Report Prepire and submil~ tha "Initial l~,~e~i" on the flmt Wedne~clay after · well is spudded or workover OplrstlOnl Ire Itlrted. Dally worl< prior to spuddleg-I~ould bi lummlrlzed on the form giving inClulive dltes only, District I County or Parilh Alaska Find ~ Lea~ or Uni! Kuparuk River I ADL 25646 Auth. or W.O. no. ITitle AFE Cap 304492 - Exp 304506 North Slope Borough Drill, Complete & Perforate Istate Alaska JWell no. 1¥-5 ~///0 Pool 102 API 50-029-20966 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded IOate 9 lH°ur 117184 Date and depth as of 8:00 a.m. 9/18/84 9/19/84 9/20/84 9/21/84 Complete record for each day reported 2200 hrs IA.R.Co's W.I. Prior status if a W.O. 56.24% 7" @ 7232' 7152' PBTD, Mx'g mud Accept ri~ @ 2200 hfs, 9/17/84. Pull BPV. pill, monitor well & mx bland mud. Pmp 50 bbls CaCO2 7" @ 7232' 7152' PBTD, NU BOPE Circ hole w/334 bbls bland mud, observe well. tree, NU BOPE. Instl BPV, ND 7" @ 7232' 7152' PBTD, TIH w/OS & DP Tst BOP's rams to 3000 psi. Remove tst plug, circ out gas bubble, fsh tst plug out f/top of tbg hgr, POOH w/tbg & jewelry. PU OS, TIH. 7" @ 7232' 7152' PBTD, Vann gun fsh @ 6785', Rn'g CBL Fin TIH, J into pkr @ 6266', ¢irc up gas, TOH w/pkr. scrprs, to top of Vann gun fsh @ 6785', circ, TOH. CBL. RIH w/csg RU Schl, rn RECEIVED NOV 0 J_ ]98z; Alaska Oil & Gas Cons. Cornmission Anchorage The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. rDate 10/10/84 Drillin~ Superintendent AR3B-459--1 -B INumber all daily well hi~tor~ /orms conseculivaly as they are prepared ;'or each wall. · no. ( ::- .::::::::.: ~> :::',:~.:.. i.: :..: /' ARCO Oil'~'~'~'Gas company ~' DAily Well History-Final Report` Inetr~ctioae: Prepare and submit the "1~ ~' oft the flat Wednesday alta, allowable his been Illlgnld or well ia Plugged. Abl~doned. or Sold. "Fhlll Refill" should be submlffild I{Ig~-'~l~lMt Ol~l'l~fl~l are lUepended for an indefinite or ipprlclible length of time. On workoverl ~ en officlll tilt il not required upon completion, rapers cemM~k~t I~d I'll~'elMltltive test data in blocks provided. Thl "FMM RiflerS" for~ sly bi uIId for ~lportlng Ihl entire operation if space ia &vlillbll. ~'~.-'" . Oletrlct ICounty or Parish I k].ask~ Field ILease or Unit I Kuparuk River Auth. Or W.O. no. AFE: Cap 304492 - Exp 3045061Title I IAccounting Slate COlt clnllr codl Alaska North Slope Borough ADL 25646 Drill, Complete & Perforate Pool 102 AP1 50-029-20966 lWell no. 1Y-5~/0 Operator Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m_ IA_R.Co. W.I. ARCO Alaska, Inc. 56.24% loaf, 9/17/84 Complete record for each day reported 9/22/84 thru 9124184 Iotal number of wells (active or inactive) on this! DSt center prior to plugging and bandonment of this well our I Prior status if · W.O. 2200 hfs 7" @ 7232' 7152' PBTD, RR. Kuparuk crude Rn CBL. PU R-3 pkr, TIH to 6300;, Cst csg to 3000 psi; OK, POOH. RU DA, rn 6.125" gage ring/JB to 6750', TOE. RIH w/FB-I pkr, set @ 6523' W~M. Rn 198 its, 3½", 9.3# J-55 tbg w/tail @ 6532'. Drop ball. Set packer. Shear off SBR. Set BPV. ND BOPE, NU & tst tree to 250/3000 psi. Displ well w/crude. ER @ 1300 hrs, 9/23/84. Old TO Released rig 1300 hrs Classifications (oil. gas, etc.) 0il Producing method Flowing Polential test data JNe. w TD I PB Oepth 7[52 IDes, 9/23/84 Rotary Type complelion {single, dual. etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Resem'oir Producing Inte~el Oil or gasTell time Production Oil On lest Gal per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity AIIowlbll Effective date corrected The above is correct ~ [~~ 10/10/84 Drilling Superintendent For form preparation and distribution, see Procedures Manual. Section 10, Drilling. Pages 86 and eT. AR3B--459-3-C Number all daily will hiltory forms conlecutlvlly II they ere preplrld for each well. ' jPage ~o. D~vldon M A#Mlt~RIcNIddComP4ny ARCO Alaska, Inc.- Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 29, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent nOtices on the following wells at the Kuparuk River Field- Well Action Date Performed 1F-4 Fracture 9/18/84 1F-7 Fracture 9/21/84 1L-1 Fracture 10/23/84 1L-8 Fracture 10/16/84 1Y-2 Fracture 10/9/84 1Y-2 Acidize 10/22/84 1Y-3 Fracture 10/7/84 ~~-? Fracture 10/4/84 1Y-14 Fracture 10/6/84 2C-4 Perforate 10/16/84 If you have any questions, please call me at 263-4253. Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEIVED OCT2 9 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary ol AllanlicRichfieldCompany STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO,vfMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []X 2. Name of Operator 7. Permit No. ARCO ALASKA, INC, 83-87 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50-029-20934 OTHER [] 4. Location of Well SURFACE LOCATION' 571' FNL, 1971' FWL, SEC, 1, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 96' (RKB) 6. Lease Designation and Serial No. ADL 25646, ALK 2572 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1Y-5 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On October 4, 1984, the "A" sands of Kuparuk well 1Y-5 were hydraulically fractured and propped to improve production. treatment consisted of 248 BBLS of gelled water as pad and fluid and 21,170 LBS of 12/20 sand as proppant. The flush of 30 BBLS of gelled water and 31 BBLS of gelled diesel. The carrying consisted Prior to pumping, equipment and lines were tested to 8000 psi. alaska OiJ & Gas Co,~s. Commission ,a. nchorage 14. I hereby certify that the foregoing is true and correct to the best of my ~~UK 1 0 / 2 9 / 8 4 /~ ( (./~L,~__~D~' ~~///"~'" '~ ~'/''~.~ OPERATIONS COORD! NATOR Signed , Title /1Date The space below for Commission use _ . -- ,, Conditions of Approval, if any: By Order of Approved by. 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 Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215- September 21, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are notices of intention to fracture the following Kuparuk Field wells: 1Y-2, 1Y-3, 1Y-5 if you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc;~. .... ~. ) Return To: · . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/08/84 Transmittal No: 4759 PAGE 1 of 2 ansmitted hereWith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ' 'S~.VE~S/PRESS~ ANALYSZS 5/11,12/84 Torque Turn (Pressure & Temp Surveys) ~.lA:6-. 7/06/84 /1B~ll./ 7/10,12/84 ............ >lA-lO 5/10/84 /lC-1 12/17/83 /1c-6 8/04/84 /~G-~O-' 12/2!/83 /1G-11 12/23/83 ~~-~ 8/11/84 ~IF-1 5/21/84 ~~ ~/¢3,¢4/84 /1~3 6/26/84 ~IG-~~ 6/30/84 ,~~> 5/26/83 ~1~-6: 8/11/84 ~L~;~ 6/28/84 ~:1c,8& 5/18/83 /~.~3; 7/07/8~ /ZH-4 12/27/83-. / 1¥-5 12/14/83 ~,.1¥-7 12/15/83 /,~1 7/03/84 ,j,~l 4/10/8~ Camco Otis Otis Static Otis Camco Camco Otis Cmnco Torque Turn (Pressure & Temp Surveys) Camco Static CMInco Camco Camco C~co Camco' Otis Otis Otis Otis Otis Camco HP Static Re ceip 7 ~actnowl edg e d: B. Adams F.G. Baker P. B~ter BPAE Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J,J. Rathmell R & D C. R. Smith Sohio Union Well Tiles Date: 10/08/84 Transmittal No: 4759 PAGE 2 of 2 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~:2B-9i - 5/28/84 '~f 11/09/S3' · 2C-2 11/09/83 2C-6 11/08/83 11/08/83 C-2f'~ 4/18/83 ~i~~ 4/24/83 C~ 4122183 ~r~:::: 4/30/83 22-3 4/28/84 "~.~_-~.~.> 4/29/~ ~-~:' 5/04/84 .... 5/06/84' ~-5 8/12/~ 5/08/ 3C-6 Y/19/~ 3C-6 5/17/84 -' Otis Lynes -Lynes Lynes Lynes Camco Camco Camco Otis Camco. Camco Dresser PBU Flow Survey (Gradient) Otis Static Gradient Otis Camco DrEsser Dresser Mini Drawdown & Buildup Survey / cat Receipt Acknowledged: B. Adams · F.G. Baker P. Baxter BP;£ Chevron Date: DISTRIBUTION D&N Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith Sohio Union Well Files STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 COMPLETED WELL OTHER [] 4. Location of Well SURFACE LOCATION' 571' T11N, RgE, UM FNL, 1971' FWL, SEC. 1, 5. Elevation in feet (indicate KB, DF, etc.) 96' (RKB) 12. 7. Permit No. 83-87 8. APl Number 50-029-2093q 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1Y-5 11. Field.and Pool KUPARUK RIVER FIELD I 6. Lease Designation and Serial No. KUPARUK R I VER 01 L ADL 25646, ALK 2572 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). It is proposed that the "A" sand in Kuparuk well 1Y-5 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Gelled diesel will be used as a flush to clear the tubing. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Radioactive tagging of the proppant and pre-post frac logs are included in the treatment program. Fluid' Gelled water 237 BBLS Gelled diesel 58 BBLS Proppant' 12/20 sand 23,184 L~S RECEIVED ANTIC! PATED START DATE- October 7, 1 984 SEP 2 41J]l] , Subsequent Work Reported on Form No /O-z/O~Dated/O.~Z~.. ~>.z~ Alaska Oil & Gas Cons. Commission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Anchorage Signed /~~.~~ _(N~4::Z.~.~(~ _, Title OPERAT ION$ COORD I NATOR Date The space below for Commission use Conditions of Approval, if any: By Order of . i~¥ il]tiNE g. ~;lllIIl COMMISSIONER the Commission Approved by Approved Cop,/ Returned / Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TRANS~'I I TI-AL TO: William V@nAlen ~,1: D.W. Bose/Shelby J. Matthews Transmitted herewith are the fol lowing' Al:,k3:::) ALASKA, INC. ,.' '.., A'T'DI. SHELBY J. N~TI-HD.,~ - ATO/111 5-B P. O. BOX 100360 ANEI~/DRAGE, AK. 9951 0 ARCO Alaska, Inc. Post Office ~,.,x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 30, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1Y-5 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1Y-5 to a selective single completion. Since we expect to start this work on September 7, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. (erely' 'r JBK/JG/tw GRU1/L17 Enclosures RECEI\/. D Alaska Oil & C:as Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CL],vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 571' FNL, 1971' FWL, Sec.1, T11N, ROE, UN TD: 1708' FNL, 1524' FEL, Sec. 1, TllN, ROE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 96' I 6. Lease Designation and Serial No. An~ ~5646 ALK 2577 7. Permit No. 8:~-87 8. APl Number 50- 07q-?0966 9. Unit or Lease Name Kup~_ruk River Un'.'~ 10. Well Number !Y-5 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1Y-5 to a selective single completion. The procedure will be as fol 1 ows: 1. The well will be killed with brine. Weight to be determined after running pressure bomb. 2. The current completion assembly will be pulled. 3. A CBL will be run to evaluate zone isolation between A and C sand. 4. A retrievable packer will be run to test casing integrity. 5. The well will then be completed as a selective single. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally ~'ested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: SePtember 7, 1984 S~alysequent Work Reported A!?G .7 O -~,ldoK~ l.:,l t., {US CORn. Ccmmis Anchor,.]go 14. I hereby c~j, fy that the foregoing is true and correct to the best of my knowledge. Signed Title Area Dri 11 ing Engineer The space/~'~w f~r~ission~ use Conditi~r~s of Appr~al, if any: Date "/ / / 8RIG;NAL SIG#[D BI' 1.1:)fi~tlE C. SMITH Approved by. COMMISSIONER Approved Cop~. r,_ Returned By Order of the Commission Date sion Form 10403 Rev. 7-1-80 GRU1/SN35 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ~ INEERII',E:; 'TP, AN.~.,'~ 1 'FFAL # TO: William VanAlen ~: D. W. Bose/Shelby J. &~tthews Transmitted herewith are the following. PLEASE KOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, ARC~'ALASKA, IN~. A'FI'N- SHELBY J. ~,"ATTI-I~ - ATO/1115-B P. O. BOX 100360 A.NO-K)R/~E, AK, 99510 D. W. Bose/Shelby J. Matthews Transmitted herewi th are~the'fol lowimj- PLEASE kD-l-E: BE - BLUELINE,, S - SEPIA, F - FIUvl, T - TAPE, / PLEASE P, ER~4 REC, E i PT TO: A~,~X) ALASKA, INC. ATTN' DZla~Y J. ~A-I-fl-tB~vS - ATOI1115-B P, O, P_~X 100360 AkE]-~CE, ~(. 99510 KU PAF~ DgS i NEERINS TO:. William VanAlen D. W. Bose/Shelby J. Mat_thews. Transmitted herewith are the following: PLEASE NOTE. BL - BLUEL ! NE, S - SEP IA, F - F I LM, T - TAPE, ARO3 ALASKA, INC. ATTN: SHELBY J. MATI'HEI~S - ATO/111 5-B P. O. BOX 100360 ~E, AK. 99510 STATE OFALASKA ~-- --'-- ALAS. ,-._,.L AND GAS CONSERVATION MISSION '~J' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILY~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-87 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20966 4. Location of well at surface 9. Unit or Lease Name 571' FNL, 1971' FWL, Sec. 1, T11N, RgE, UNTT..I-- Kuparuk River Unit At Top Producing Interval tI'~CAT~ONSt 1305' FNL, 18~1~ FEL, Sec. 1 , T11N, RgE, UN '[ ~VERIFIED ' 10. Well NumberlY_5 At Total Depth [~r~~[ 11. Field and Pool 1708' FNL~ 152~~ FEL, Sec. 1, T11N, RgE, UH ~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Kuparuk River 0i ] Pool 96' RKBJ ADL 25646 ALK 2577 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. Jl5. Water Depth, if offshore ~16. No. of Completions 05/24/83 05/30/83 06/13/83~ N/A feet MS L~ 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (M~D) 19. Directional Survey 20. Depth where SSSV set ~ 21. Thickness of Permafrost 7266'MD,6687'TVD 7152'MD,6598'TVD YES ~ NO ~ 1781 feet MD~ 1350' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/FDC/CNL/Cal , BHCS/GR/Cal , CBL/GR/CCL/VDL, Gyro , 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP B0~ HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5~ H-40 Surf~ 24" 270 sx AS II 9-5/8" 40.0~ J-55 Surf 2205' 12-1/4" 700 sx AS Ill & 250 sx A~ I 7" 26.0~ J-55 Surf 7232' 8-1/2" 600 sx Class G & 250 sx ~S I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6~81 ' -6472 ' ~ 3-1/2" 6286' 6267' 660~ ' -6607 ' 6618'-66~8' w/12 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6657'-6670' DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) I DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure . CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None iL.' orm 10-407 Submit in duplicate v. 7-1-80 CONTINUED ON REVERSE SIDE , .... , ~ :: ....... . ..... , ......... ~:~ ...... . ......... ~. ..... ~ -, ~. ~ -~- ...... -.,: ~.~ .:., .... FORMATION TESTS .... ' ~"~ .......... : ..... GEOEOG.iC,MA...--..~- ~ ..... :: ': ......... :;-' :' .' ' - .' ........ ' . ... ; .-~ - : . -:.-.- ....- .... Include inter~al te~ted, ~re~ure data, all fluids r~over~ and NAME '~'~ ' MEAS. DEPTH TRUE VERT. DEPTH GOR, and t~e of each pha~e. ....... . . . Top ~p~er Sand fi~81~ 5~68~. ~/~ ' ~ ' . . ~e U~p,r Sand ' fi~62~ ' 6038~ ...... lop [~er Sand ..: -~':65~~.~. 6150~: "' " .... . . ~,~ [~er Sand" 6700~' " 6238~ ' ~ . . .: . . . ;: . .... .. . .. . . - . . . . . .. . - . ,: ~'. : . ., .. . , . . . _ .: . .~ . . , . . .; .. , . .. . 31. LIST OF ATTACHMENTS. ~ . Drilling Hisgory, Comple~ion Sumary, Gyroscopic Survey (2~cop~es') - 32. I hereby ce~ify that the foregoing iS true and correc~ to the best of my knowledge . INSTRUCTIONS General:. This form is designed for submitting a complete, and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for onlY the interval reported. in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO REP: TEST TYPE: P?'-'"CTION (INDECTION) TEST DATA._~.. TEST SUMHARY o. - ' TEST DATE: 8HP- ~ 8~T WELL TYPE: PERFORATIONS: Old __ X New ~ Produce: ! - Injector PERF TYPE: ~,o~f.~ - , LOGCZN~ TOOLS RUN: /'7_.~p-TfC- _,,at- /:'~¥~q ,.,9~sZNTERVALS: : $ TES~ SUMMARY PRE-TEST (If well is currently flowing) AVC PROD (IN3) RATE AVC GOR , - AVC~ WHP. ..,F~'API ' WHP ~ _ CHOK~'''~ /6~ DATE ~ GO ACS. UAL TEST DATA ./ AVO PROD (IN3) RAI'E AVG CDR AY 0~..' R WHP PSI~ APl: WHP . ~fl'/'' CHOKE ~_. /G~ HP ~ ~ FT HP ~ SS TO~L PROD (INO) TIME ' DTAL SHUT iN TIME , ,~BOPD e 60 FT HR HR MA30R WELL. EVENT HISTORY DATE START END . . · . · · EVENT 72_ 2'0 PooF, , CUMULATIVE PRODUCTION (IN3ECTIDN): TOTAL PRODUCTION (IN3ECTION) TIHE: TIHE SINCE LAST MA3OR SHUT IN: " LSRECEIVED DAYS Alaska Oil & Gas Cons. Commission Anchorage KUPARUK RIVER UNIT SEQUENCE DF EVENTS WELL: / ~ --.j~" DPERAT]D~: TIME EVENT f..,,' L; ~ / $ AP ¢-6'A'Y' DATE: ?.,o..~ o_ ),, o.,,,J~ 4 6. o....~ 6 :~-z,~'7 '7;-7? q ? ~',t ~' H 'r' .... /5-Z~' /,y-Z° 1Y-5 DRILLING HISTORY NU 20" Hydril & diverter & tstd same. Spudded well @ 1000 hrs, 05/24/83. Drld 12-1/4" hole to 2250'. Circ & condition hole. Ran 56 jts 9-5/8" 40#/ft, J-55 HF-ERW, BTC csg w/shoe @ 2205'. Cmtd 9-5/8" csg w/700 sx Arctic Set III & 250 sx Arctic Set I. Bumped plug w/2000 psi - ok. ND 20" Hydril & diverter. NU FMC 7" csg head. Tstd - ok. NU BOPE & tstd to 3000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.1 ppg EMW - ok. Drld 8-1/2" hole to 7003'. Ran logs DIL/SFL/SP/GR/FDC/CNL/Cal Run #1 f/7000'-2203'. Ran BHC/Sonic/GR/Cal f/7000'-2205'. Cont. drlg 8-1/2" hole to 7266' TD as of 05/30/83. PBTD 7151'. Ran 185 jts 7" 26#/ft J-55 HF-ERW, BTC csg w/shoe @ 7232'. Cmtd 7" csg w/600 sx Class "G" cmt. Bumped plug w/2000 psi - ok. Instld FMC tbg head & tstd to 3000 psi. Displ top 360' of well to diesel. Arctic packed 7" x 9-5/8" annulus w/250 sx AS I. Secured well & released rig 0430 hrs, 06/01/83. HILL/DH21 06/13/83 1Y-5 COMPLETION SUMMARY ND adapter flange and master valve. RU Dresser-Atlas mast truck & E. Line unit. Ran CBL/CCL/GR/VDL f/7126'-2150'. Ran Gyro f/7100'-surface. RD Dresser-Atlas. NU adapter flange and master valve. Secured well. Accepted rig @ 1430 hours, 06/11/83. ND adapter flange & master valve. NU BOPE & tstd - ok. Ran 3-1/2" completion assy w/tail @ 6286', pkr @ 6267', & SSSV @ 1781'. Ran GR/CCL. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Set pkr. Dropped bar & perf'd the following intervals: 6381'- 6472' 6603'- 6607' 6618'- 6638' 6657'- 6670' Dropped ball, press, up, sheared tbg release @ 1600 psi diff. Closed SSSV. Set BPV. Secured well & released rig @ 1530 hrs, 06/13/83. GRU3' CSlO 07/11/83 © 0 © ' I.:::LIF'A~F~I_II.::] F:' :1: IEI_.KI .... II...llqE (:,., 1 '71:~::3 ,..ICi}:) Nl..ll]V][:3[:~:~ i:~ K .--" :':{ l:) -'.' ::::l () (:} J:::] ]. :J ::: '' I i .,. ::':' ':' l~ ~: l ~:{ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::: ::'::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::: :::: :] :::::: t: ::: ::::: ::::::::::::::::::::::::::::::::::::::::::::::: :[[::: :::::::::::::::::::::::: :::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::: (~::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: '::: T: :: J::l:':: ::: l. :::l ............ : :.:.::~: ............. ........ :::::::::::::::::::::::::::::::::::::::::::::::::: :~:: ::::: ::: ::.: :::::::: :: :::::: :: :::::: ::: :: : .................. :il.: ............ : : l.:::. :::.::l::::l :::::l:: l:l:.:.::.::::::: l::''':''.': '.:: :::'::: 'l ?:(]? ::l ~::[.~ ..::.: ~:~: ....... : l:.. :: l:..::l.:: : :t .......... ................ :: ::: ::::: : : :::: :::::::::::: ::: ~:: :~:::::: :~ ::: :: ::::::::: ::: ::~: ::::::::::::::::::::::::::::::::: :~:::: :::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ..................................... ::~:: ~::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: b :l:~::""':~' :~ ~ !'"[]~' ~ .......................... :: ::: :::: :: :: :' ................ : ................... ' ::.:: ::.:: ::.:: :,;::?:::~' ;~:'~:~ :::::::::::::::::::::::::::::::::::::::: ::?::::' :: :.. ::.~?::: :~: ::::: :"::: ?:::: :: ?"~::. ::::[::: :[ :::::::::::::::::::::::: '.i:: :::::::: :::::~ :'::: ::::::::::::::::::::::::::: ::~:i::t:::::::::::: :: ::: :[::::::: :::::~::.::.: :[:~:::[:::::[: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::[: :]::: ::::::::::::::::::::::::::::::: ::: ::::::::::: ::: :J: ::::: :::::: ::: :::::::::::::::::::::::::: :: :::::::::::::::::: :::::: :: :~: ::::::: :::: ::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::: .:::VJ~::[: :~:~: ~:::;; :::::::::::~ [:; I~;::::]::::::::::!~'.{ [:~:::.::~:: ::~::::.~::l:j:~:~:~::.:~:D::::::::::~:~::~:[~!::::::::::::!~ [:~:!~ :::~:[:~:l~::::::::::::::::::::::::::::::::::::::::::~::::::::::::::::::::::::::::::::::::::::~::::::::::::::::::::~::::::::::::::::::::~::::::::::::::::::::::::::::::::::::::::::.:..:::::::::::::::::::::::::::::::::..::::::~::::::: ::::::::::::::::::::::::::::::::~::::::::::::::::::::::::::::::::::::::::::::::::::.~::::::::::::~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::.::::::~:::::: ::: :::::::::::::::::l: ::l:':::l:::::::::::::::::::::': :: :::::::::::::::::::::::::::::::::::::::::::::::: .) '1" I:~ i...llE S; I..I E3-- S; E: ~-~ C: 0 U IR S; E C: 0 kl R S E: D 3:3 .-.. I... E: 1'3 "1-0 'l- ~ I .... Ivll:::~:~l:;I...ll::~J::[I V[:::['~"I" :l: :::: ~::L. VE:R'I" I I:::[~k I N(::L. I NA'I" l I::IN KI I REC:T I tIN I~;E:V[:::]:::]: ']"Y I:~EC:"]"[i~I',] f: I...II....~:~F~ I::::l::ll::ll:~[ :[ N l:~ 'i" J:: l::; V[::[::: ] :[ : :::::::.:: ::::: ,:: : ::::::: :::: ::: ::::::::::::::::::::::::::::::::::::::::::::::::::: :::: :, :.,: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::: .............. :.--:::.'~.--- 7'("} ('j ..... Z --::£ ~ 4,~- '. ,~.?:'(:' .............................. :::::::::::::::::::::::::::::::::::: ............ :':: :''I: ................. ~'} ........... ] ........................ : :l : ~] ............ ~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::/] :i l:, [ :::::::::::::::::::::::::::::::::::::::: t..~ :BOO 799 ,, '79 '70:3, ':;"P 0 :3:3 '.S 69. :30 E O. 4:3 2.61 :E; O, 6'7 ~,,i 0 ,, :3:3 ':?('~0. _ :B'::?'::;' ,, ,:x.?.... 8('):3. . ':~':'.. 0 :34 ._,':' :::~?_.. 50 E ('~.. .... ]:'('~ "::',., '78 :::; o_. 2,9, IS :i ,, 7:3 ..... · ... : ....... -;.,:~.. ,'~, .... ~ ....... ; ;, ..... ; -: .... ~ .... :.~. ...... ? .... ~ :.. ,.~, .., .................... ~ ................... · · ::: :' :: ~::':: ~' :::::::::::::::::::::::::::::: ::? ? :::'~,';: :::. ;~?F~;:::~::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::: : ' : ' 7[ S ' ::::::::::::::::::::::::::::::::::::::: .:~ l: ::::::::::::::::::::::::: ' [:: :[:~ [~i::::::: ~ l~ : ::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::) .............. ~.._,= "" ,, ':::'"':' ':::' 4 ',::'::~. E~: '.:'~ ~:,'::J. 1500 14'?'? ,, '::% 140:3. '?6 0 1:3 N 1 ~. E~0 ~ 0. :36 2.7':3 S; 4. ::',4 E: ::::~. f5.5 ............... ~.'--i' e~:~~~;' c~~O:3 ~ :.::~,~.: :::::~: :.::~ .: .: .:::G:::<:~: ~ ~Z:::~ ~.:::~: ::: ::~::~:?:~ :Z:.~ ~:~::~:.~:~:~:~,~::~::::~:~::~ ~:: ~ '.::.: :::.:: ::: 0:~ ':~::~ '::.: ::::::::::::::::::::::::::::::::::::::::::::::.? 2 ~ (~,~:~: ,: :'::~,. :.::::-:?:::,: :.:: ::::::-:':: ::::~:~ q, 2. ~: ::: :: .:: ::..:..:':~ "~ ~.::~ 4-. ·: , --'_ .-_ ::..:: :' :::.' ...... ::':.,~,.,.. g~ ~:. :':: :[:.~: .: ::::: ,4~:~::~::::J~,:~: :::::::::::::::::::::::: ?:.::: ":~'::::-:~:?:~::: ::::: ~::'~::.':. :::: ::::" ::~: :f::::~'~'~':.'~ ::~::~::'::':'~'~:::'~'::'~::~'::':.'~ ~.:: ?':::' :::~:::~:~ :.:~:::::~ ::': ? :~. ~:~':::::~ ~,~ ".:::~ :::::::~:~:::::: ~[ ::~:::::::::::::::::::::: ~:~:':~: ~'::~ ~: :'::: :::::::::: ::::::::::::::::.: : .:':: 'W::: ::: ::::.:.t'~ .: ~ ,~. >.' ::~..: ::.-~: :~::b ~:~:: :..': ~: :::~" ,::, ." ::'. ' : .~,~ ,: ~ ~ ' ~ :': ~: ::.: :' ::::::::::::::::::::::::::::::::: ~:::~: ::~::::: ::: ::~::' ::?:~ ?::::::::~ :::: ;,:?':::~:~:~::: ::::::::::::::::::::::::~'::'~::':.:~::~ :~':/:~: :.:::::::::~:.:.: ~::::::::::::::::::::::::~:::~::~h?:~::~'::.:~: ~:~ ::?~ :?': :~ :~:~:~:, ::.: ~ :.~::~:~?:~?.:?~:?.~:' ~: ~::: "::: 'F:~: :: :::': :::? ::~" :.:~:::::::.~:~ ~: ':': ':~,~:~: :': '::~: :': ~::::. ~.: ~ ::~:~::'~ :~::::: ~ ....... ' ................ '" : 1 ,-,O0.: ..: ~/~ .' ~., 4:.: :::: :.:::~:7~.~:,:~ ..: ::::: .. :.::~..:::~ ::::::::::::::::::::::::::: ..~:::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::.. ::.::: 1: ~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::.~'!::6~ o: ...'~?:.:: : E. ~.:~:::.: ::.... ::::: .::~:~: ~--' ::::' ~R~0 ' ~ ~::R:~";~0 ~ 80'3, 90 '1~ ' "4 ~ '" N''''~ 7'~"':i'C;' E ........0: 27 J:: :37 'S ~ F': 57 E:. '.>': ]. :2~ ::::000 1 '~?':?':::' ,, ::361903, :?,6 1 2',:: N ',::4. :E',O E . 0, :34 2100 20'F":; ,, 84 2 C) 0:3, E: 4 1 C) '.S 7' 7, ::: 0 E 0, 61 0, 94 S; 12, 42 1::: i O, 9':? ................. ':~'::'~: ":': '::>':~ ;'-~ .......... :-"':::>i'sJ%~'~"~:2 .... -~-::"-'"'::-::6 ': ............. :~ ..... ':: ~: :30 :::: ~ ..................... :' l~. ;':~ .... ............ .......... s, O':~-::F: :.- ...... : .:... ::' -. ~: ~ ~. '-:, ~:'.. :"-:' · ~ :<.-:~' ~ ...... ~ . ~ .' ' - ~ ~ ..~ ~.. ,~ :.::::. ::. ..... :~::'::::.:::':.:':: .:.'~. '.::. :~*~' · ~"> .:.::"..' :::::::::::::::::::::::: :'" :. · · '? ~ '~'~,:~,:F~ ~ :':: ...... :::~:~:~'~ ~ ~ :::' · '.~:~::: :' ::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::: .: ::::'~:: : :%:~,:::: :::.~:::~::::?.~::~:~::':~ .'.:' ::: ============================================================= ::':::/: .'"~. ' ::::::'~ ~:':': : ?:'::~::::'~:~','::': .... 4 U O:: :.~ ~ ..... 7.4: ::.: ::.:::.~ ~'0~,., :74:::.: :~: :.::.: : ::.:::::: .:::::~ ::::::~:.: :,~.4::.::..:. :: -:::::..~:,:. :':~,:~.~:~:~:-::~::::::::::::::::::::::::::::::::'::.:: :"~: ~5'L,..~ :Z4-??~:2 ~4-0~. 52 " 4 ' 4:3 :5 ~5, ~:'~ '~: 2, ~0 7: ~..7:' :~ 2 i ,, ./? i:. ..:~ :2600 25'?'::'., 0:3 250:3. O~E', 5 5:3 '3 ~'.6. 10 E: i. 18 ~:',~ 07 '.S :31. ,:':~ :1. t~ ':0,4':? :270() 2,<'.'::~'.:::~. :32 '2,~ 0'2. :32 ~E', 7 '.~ ~B:E:. :'3'~ E 2. :2.~5 ~',. 6:2:3 4:3 .. 1 ~:', I: ~ 1.06 .............. :~BO0'":'-: ........ :~:'6' ....'~ .... ~ ...... ~ - '"" ~- ........... :~ : .... :: ,:~=. : ~ m ........................................ ~.~..~: ............... :~ ..~ ..-: .... ,~ ...... .......... ~o ~ Z L~.,~ ::.::::: :: ::::: .: .:.:~::~ :~.~:~':::~,.~:~..::::~ ::::::::::::::::::::::::: :.: :~ F: ~ :~::':~0~'] .-,,-,,,., .. ,.:,z ::::::::::::::::::::::::::: ::~:.::::::,~;,~:~:~:::~::::::~ ':::"~, :::::::::::::::::::::::::::::::::::::::::::':'::.'~::~:'~'~':~'~,~:: :~:~,~'~:~: :: .. ::::::::::::::::::::::::: .. :~ o :~- ,~ .~. !'~ ,~ ~..~. ~,~, ~ :~ ~:::~: ~ :. :~:~::~::..: ~.::~`~::~::~:?.::~`:::~::~:~::~:::~::.:::~:.:~.:~..:::::::~`.~:.:::~:~:~:.::.~:.::.:~:~:~::~::~:::~.~::::~:::~:~::~:~:::..:..:' ::.: ::::J~:~,:: ~:~ :.::.:.::: :,, :l:l: 1 Y --- 5 ( :5; E C 0 _'1. T :t :1. I',I I::;: 0 'ii2 Iii:: ) C 01¥1F' L.I 'T'& T ;[ I.'-~ N l.:l ............. ¢.:~ 'T' I::: E;{ 0 '.:i; ~!ii; F:i ~./I::;: Iq F.; '" ~"'l F' :[ I:: ::, .... I...l'""l-~ x,' I-:::I_IF'/.hF~LIK F' :[ EL.D .... ILINE /..:,, 1 '?F:::.~!: ,J :).('i:{ NI...li¥1BE:.F;: (.~ l.::: ...-. P O ,,... ::ii: C, O ]5 :1. ::: i: ::: ::!:i:'!';!'~ili i:!t' :. i:: ii:i.i i:ii!':ii:: i '!iii!iiii;: ii':iii::i?i~;: ::i!: ::.:: .:::~ ! i':'::'i":i i'=:=:'.'i'::::i ::'i'i'::!'::::::i'::::::'::::':i'i'::i'i"::.'i':::':'i'i i i'::'::, i':::.'! :'i':?'::;",'::'~ ~'~":'~'~'[": ': ~':,':.'~';": ;':':;".":'~'~";'::'~'::".'::'::":'~'::':.",':: ~':= :'::'::':,~':'::'~'~'=:":'~":'~'~'::':. ~'=.":':;~'~'~".'~'::'~'~'~'~'::~':.'[':;':.".'=:'::'(':;'~": ::';'~'[';'~'~' ':;'=:".".'~'::'~':. ~'~';:'~ :;'~ ;'[ :: :.".'::':;'~ ~'~ '.;~:=: ~'~':'~".':=".'~':='::'~";'::'~",':: ~;:,::.'~'t'~'::::::~ ~:: ~: %!::~;i~ ';; i'!":' i:':'!:?:~j'~i?:~i?~Y':;:":~ii:~i?i:i':"i'i :::!!i';: i 'i: :'::: :. .) '1- I::~ U J:': :i.:; I..I £~ --.- L:; E ~ I::: I::i I..I 1:] :~; E (.'.' 0 kl R F; E D r '_'l .':i-. I._ E G 'l"O"f' ¢.:.~ L. I'"IE:'(.~:i:;I...Ii::~IE D VER "i" :i: i::~.:.~ L VERT ]: C ¢..~L :[ NCL. ]: N i~"F ]: ON D ]: REC:T I FiN F';E VI:.:R :1: T'Y F~EC T .:.~l',.li:il...IL (.~ R CO 01::;: [':1:1: NF'.':'f'E:S VE; :'T' 1: CI.'.~ L. :. : ::. :: ::: ::::: :: :~.,.(~::)~:t ............. '.,:.::~,,,~: '~/:F~::~:,,.~ ............. ' .......... ~.~*,'.~.~.'~:i""~,',~ ............ .............. ~':~ ................... t'.:t.::' ................ ~::.:~,:~,:~::.'~:(t .............................................. ~::: ,~:~:~::,~ ::? ................................. ! ,~ :.:~:~: ..~ ............................... ~?~l.'~:~.~-~:,~ ,. : .::.,.:.:: :: ................... ::.,,,,,::..:~,:..:~,:::~::: ........... .:::,...:~:~,~:~:.~: ....... ::::::::::::::::: :::: ::..:,., .:,:,~,~:,~,:, :~:~,.;. ~::.:;.,~.::: ..:::;:::~:,~:~:~:~:::,:~::~::::::~ .,~..~:..:~,~ ............ ,.,.: ............ ~.....,.~ ........ ,_,.,;~::~:.~:, .............. ~ ............. ::,::~ ................... . .......... . .......... ~,:,~ ..................................................................... :IL.,~;;~:~:,~:~..:.:::.~:::::,~:::~.~,,:::~L~.::~:~:,,,:~:~:,,.. :J: ':: : :::.':::::::.: :. ::::.::': ;~..:::: :::.::;f.~. ;4..: ;.,. 4.:~'.:. :::%;i,~':i: ii:i:i:i!!i!:i i:i!.::;:!:!!i;¢:~¢;i~.;.¢:!;i~?.. ::,~i¢:~k~ !i! !ii:i :!i!ii:i!h '.:?..:ii~!!; i.~i::.:iiiF :~i: '.;:! :iii: ::i::::i!i:i:i ii ::!:~:! ii i:i:'.~:i::::::i:!!:!;i:i :::::'F'.:;13i:!:i:!:'.::':~2:i:::!..!:!3~:i:i'.i::i..!:i:::::::i::~i:!': :::::::::::::::::::::: ::::!::¥ :ih. i i !:i i: i ;::: ::::::::::::::::::::::::::: h:i:i': !:::: :::: :.:~::. :::.:::.'::' .......................................... ~:5"~::, '.:.,~:~ ~;,:.,, 2: ~: ....: .:~ '.~;:z.',;'Z.Z ........ ,~. ~ ~.~: ~ :.~;' "~;,,'F;"', 'A i"~';' "~:'.~ L~. i' 7,;' ~"i ;:::; :::; ....... "" "' ";; ~"::~i: :j :':;' :%.'.,' :':':: ::::::::i:O0 :3 :[ S'":t., 7"~ :30:"--::~:, '74 1 !.:'5::i:~, ::.:; :"'"~7./::,0 E 0 ,, '74:, :L 7.4.0 :::; 157 ,, :.-:':'? :3:.'.'~0(:1 ?",2',::i~(.'~ ,, S/_", :.?.': :l :'_::4., :::i:/_', 16, 2.':.: 'S :-::7. :[ '? '" 0 ,, :E~(::~ :1. ',.:i: ,, ,'~,~""; :i!!; 1 ',F::4, ?.?zl. ¥?:: : ::' :i i:~: !:: :i:: ': ';~!~ :i!:'~ ~..t~.J( I ~ ::iii:;!ii:': :iii"iiii~i ......... ~':i/. ~ :., :i::~ ,,{.) :i:i :,;-~i:;:i ?ii.:.?. ...................... :iT' : ii ~'!!jii;~;?:':": ¢~" ~ ~ .... ' "~!;'~ ........................... :'ih-:':? :?i':ii:' i ;' :; ~;~ ii':'' i i i ::' :: ii~ ~ii;; :' ! :' i'!i:: iii::i':!it[~ .............. ~'t'~', .................... ::' ' !:~![':::i :~!~:~i!:: ?'"'i'::;~i'!!~i:~ ........ .2~ .~i...~:~..) ......... ...... : ............................ "~'~':: ............. :i: :i:i !: :! :i i:ili ii i!: ?.!:?ill!ii i~i?i! :: ??~:: i i ': :: i i ! i i ! :. i :. :: ! ! ! ~i!~:: :i: :i :':. ::: i~ ~ :: i ': :: ': :: :: :: '. :: :: [; i!: :: :: i '.~ :.!!;~'?'?: '.~::i ':::;: '. i ~ ~ :~ ~:i:::::;::i::i?:i! ?:i ??:iii :::::: ::ii:::. i::::i': :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ?:::?i:!ili!ii!il :::: i ~i:i!:i:iiii!i::: i:iii: !?:!~i !~: h ~fi: i!~: !iiii:!:ii:i:::i::: ~::: !~! :!!ii .~i !!~:~ i. :~i:ii: :!i~: i::i::ii ~.~ :':~ i~ i~ :! !¢:!: ~ :: ::.i: :':, ~' :!::i::::~:::':;i: :::: ii::!~ ii:!;i~i ;.!~!!i~!:~!:i'.!'!~!~::::ii~:.::?:i: ::.iii:: !~i!~:!F:' j::; ~!:i!~!'.l~:=.i!ii~?.??~!iii:.i::ii!ii::ii!i!=:?:i i!~i:: ~[~i%~?:~:i:.~i:.~==i=.:=??=?~=~iiii:iil;ii:i:i::::i?.~;ii~=?:??,~:: ~::::i:::i?>:i:?:¢:i! :.,.~!.=:?:ii¢i~==~4i==~::ii~iii~.:.).'::: ~?i:: :=::: =:i=:ii::i:i=:~i~:. :: ~" ii?~! ?::=iiii?: ==iii=:: =::ii ?: i?: i;qi~;~Fi:.:!?::~ :~: ?:::i :i ?;?:::::;i::i~ii~i~:~i=.! !~ :;:= :i~: ~?: :i :3~i":.~00 :::',7:::?7 ()':~ :3/:,41 0:.:.~ :3:::" '-"= S /-,',::~. ::~':..) -' ::',7':~, :;.:."('~ I:.:i: ,, ~.-, 4., ('~ F.; ,'"', :':::, ~"~ :':: ~:':; ":"? 7 ('1. :'::,"::.; () c"~ :::.:: :::: :;2 () ,, :':20 3 7 :.24-, Z 0 :35 1 S ~:, ._ ........ ' .... ....... '"'"~ ./:,'?; .': "::' ¢~0 :i::-.'.'l. 7:t ::'; 4.::::0, ::.i:::.!: Ii!:: ~..~ '-::,, 4.:1. "1.4.00 42:..'3::..i:, 14 413/'-,. 14 :3::', 10 :5; /_-,4. 1 '~.) E ('~, '7 l 2':'~,'"', ,, 0',:-:: :!.'".': (':, :'-'i: /::, . :2.::':;' E , :::';'i':;. !57 4. Fk'~q~_.. 4:!~ 1;':, , ('~ .... 42.-"2('~ . ()4. 32 4.5 S /_-,,-I- . ('~_ E ~-~.. 4:i; '..32':'.?, L:;.~; :~i; -"- ';:~ ,,/ .:,._ :::'.".'1. I: '':;.3, ,:.~,3 -- .. - .-...: : ::-- .: ~ .... : _ . , ...... ........ .~ '~.~ ~ ~ %' - - '~, ~ ::,::7-.,. -?',-- ~-- .... ~ -: " · ~ ~'.' i::':::.'::': : : ....'- .::::': : .: '. :~ .i: ... .. :rr. -::... ... .............. ::.: .:...:.: ..................... ,~,......:.~:~ ............... :.-: ...... · ........ ..:.~ .... ............................... .,-. ........ .~...: ........... ....... .,...:,.., ,., .L . Z.:.~ ~ .... L.' '~ ' "::::' ~ ,,- ,n · ~' ~.~ ,-~'i~.~':~.::::::- =============================== :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::: ~:.~i::: :': ::.:~;:::i:~ ~'!:::::.t::!:i::.~!~!:i:~!:ii!;ii:!~:.~..: .. : ~ =====================================================: ..::~:: :..:: .i.' :: .::: :"i:::::: .!: ::' :i:. ::-: · ()~)~ · -t. ..... ~! .: ~ ~-~ ........... ~ : .....................................~. ~ --~ .... ~ ~,,~ :. ~ ..--~ .............. ~ .... :~/ ....... ~4,., ~, .,..~ ......::~.',~,~,-:-,,~.:. :' .............. '..:..,~,'~: ............ ~,~ ~.. ~,~.~-~.~.. ~ ................. ~.~, .~-..~ .................... · 7. Z , :~. ~, ..........., ~ ~..~ F ~ ~:.~...', : :, · , ::: :':' "" ' · ',:-"- ,":: ·: ::::: ::, :::,: :::~. :,:.' ::: ' :::~ ::,::. ~.:,:: ::::::::::::::::::::::::::::::::: .. ,.-::::.,. ::::::::::::::::', ,, ':::::':::::::::::::::::::::::::::::::::::::: :::":':...., + .,..':.,::::',,...':2 ::':::':'":',., :::::::::::::::::::::::::::::: .':: ":. ,:, ~.... -". r~, ,.. -'.'.: :.:.:--:-:.:.:.:,:-:.:-:.:,:.:.:.:.~. -. : ~ ~,~ *..~ ..:.: .:.:,:.: :, :,:-: ,,:.:.'.:,:.:- .:: ~-~ ~;.~ ~,, ~ ,,4~:, :..~,~: ...::,:, .:., ..:.: ,:,:. :....:;,: ,. , ,.~.. · ~. i~ ' ~:"~ · ]::~ ..... ¢~ ¢~ ¢~ 4 7 ,'-'I. 0 ,, '? ?-: 4/_:, 4. 4 , ':~.. ~q_ :q_ c~. 27 ._,':' ;-, .... ¢~ . !50 E <~ , '--~: .q.. ..... .-,.'-' ':-"',..."" ,, .~:': ...../-., :-.-.; '? F, ',.':~ , ".27 E: '1.: ,: ':, ,.'.., , ~ ¢~.. !.51. O0 4::::2?'. 4::: ".].7.'_::1,4.',_-':: 2'.-;,' 4/_-, :E; ~,0,3? E o, ,'Z,':;' :::7'/:', :::0 :E: 1 (-~ 1 1, 'i:.; :':."'. E 1.., :::;,."-,, 2 .t ' ~ .... ' ............. ' : .... · ................. ' ..... ,' -"' .... .......-," ' ....... -- '*" .:.~ ~ "'¢~ '~ "' .- · .,.. ~ ...:.~: ...~ :-:..:..,.: · .:....:. ,: ? r~ :.. ,..~ -,~:.:.:..:.- :...:.:.:.-:.:.::?:.:..:.::.:~.~:.~.:.. ~ .,~:. ~.,.:..:..~.~.:...-..: .: *~, ~ ~ . .......... .:. ::-'.~ ,~.~,.~ ~ ~ %,~ '4,,'.... -,. · .~. ~~, ~. ¢,~ ~ ~,.,~:*~,~ [.^, ..:: .... . ..~ . ~ -~ ( )~ ) ~( ~ "- ~ ) "2 ~, ~ -Z ~, : ............. ........ ?~. : .......... . .......... ~ ......... ~ :. , ~.-~, '-::~-~i:":'.i.::::... :::: i:-:::" ::r,,~i~. ::..' ,~,:,'~ :. i~::::.;.::::. ::, ............ ,; · ~, .... ~,~ ~ ~. ~,. ~ ................. ,.....--..~,.,..,..-:,~'..~ ........... I; ,. ,~ ~ .................. ~.~ -~..,--,- .~_, ......... 1~ .-,, -~ ......... ~ ,:';',~,:::~z~: ..... - :.. ..: . : · .:. ·.... '' ::: :: :.: ~': .::.:: ...:: '::.: '!:...:::::'.::::: .. ,::::: . ::....:..: .::. :::.:..t · .'tr.-....-: ::::::::::::::::::::::::: .... ~ :. "~ ',~ .. ~ :.:.....: :~. ~ ~.. x~ ~ ~ ~ -la,~a~' .~ "'-~;. ,~ . _ ....a' : ~ .. _ '~ - :'' '"': :" '~ ~:'"" ':'":":": "!:!: ============================================================= ::':': ''. ":'i: :"' ': ::::::::::::::::::::::::::::::::::: ':: :i::.':: ' ' :::':' ::': :: '::: :::i: ':::' 'i ':.. ,:, ::.: " ~ ~)(~ .""~J ,-.It") /" -d);- ' '-.' '."~'~ '-'/- '-' '"~ '-'-? - ' ' '"' Z 7': z~ '~ -' · ': ~ ':, -- -' .................... '~ · / ............. / ...... I: ]. · q ..' I., ... , ..,-~ .......I 1 7 .....[ .... i::. ]. !::; ,:', (') ¢) ....... 5270 ., ::"::/-_ .=;1'74 .... . ::::/-, '-'~'-..' ..., 4'..~ S ._'--',F~._ · ~,0 E ¢~., 7'.::;' '~'i:'~:, . :3¢)_ :"-'; 1207. . , ._.,:'":?, I"": 1 ' :iii:.'::,, ::2,0 !157":")(:) '::'""" ;I. (').=; F; ' .:' /-, .~ (')!5 :2~; 2:~: S 54. 10 E" ('~ ~,':7.' F;2.':'1 :[ '- '::' " .... -:"-'- .................... ,'. ..... 1:244 ~ :"".': .'.1. .... :,00 ._,~.': .1. , ~'-/,: ~;~.-,m~ ~..':~'-.~ :::.: :..: ~::.: '~.i:~::::.::: :::::':::' ~:;"::":~*~i':'.:::::::.:~::)::: ~:':.':::': ........... · 'T): '.~n~:~:'~:::::~: :'::::.~ '~': ~.-':'::::::" ': ........ :. ~:~.~ c;,,':.' p- : '. . · ..:: .... ............. · ............................. . ~ .................................................................... ~ ....................... ~ ............ =========================== ....................... : ................................ .,::.:....:.:.~.:., .................................... ~ ........ ~,.:~ ...,? ....... ~ ..................................... ~.~.,~?,... ......... ..,,..~ .............. : .... ............. :i. :~:~i:ii: ~;~::;~ :':~: :1:1:1 Y---~""~ ( F:L::CO 1 T 1 1 hi R0915:' ) ['::[ U [::'~':~ I::i U I'::i F:;' I E L El C 0 M F:' LIT .F..~ T :[ 0 N D (4 T Ii!." J LI NI':Z ./:,., 1 ';'~i.:~:':~ . I I..~ I..., ~:::. S I..I B '- 1--; E A J:": 0 I..I F;~ 15;-E F:: 0 LI R S E I': i'.] I.'ji-. L F:': G T 0 "1' A L HI:F'AS .ll::;:li::_'FVEI::~T :1: C (-.~L VERT -'f C:~L T hlCL I hl~'..~"l' :1:. ON D ]' RECT I ON '..::;IE V EFt: I "I'Y RI'"::E 'l'A Nr-:il. II..(~R CO01::;:D I NA'T'ES VEl':. 'I" :[ C(~I .... i:': ~ ~::,:i:: :: ~ i:,':~: ~: :}ili:!,i:!!::ili:~i':!!i:: i; ~:,'iil ~ ::,i: g;!i:i:iS::i!;:.ii:,ii'.'.i::::':iiii::':ii~¢:ili!;i ~:,!;} :;...! ~}:~ '.! !::!5 g:~' i~ii~!:i ii:~i: :~':::ii:i`~:2~iliS!iiii:: ~iiiit!::!i~ii:*~!~':~:'::i::~,)::!iiii:::':~i::~i~i *~:.!~i!~=.~} '::.~i:i';.'.,.~iii::i:'i ~ :,:;,~=;:.;~, =. ~;*-:-=;=~=:::~:~:-~=====.:=='~==?:?~::-=~:=~:~:~=*~:~?-~::-:~*~-~`~-:`~:~?~**~`*~*~ :::~?,~,~,==,?==;=;~~ :~ ~"~:., ~:.:=I~.;::=:::;¢:.~=:,;?==;=;?;=;~.===~.;~:=;:;~=:::::~.~ ~?~-~r`~=::=:==~=:===:.=::~::==-~:*:=~:-~-=:=~-~:~:~:~::~:~::~`:~-:`~*~-~*~-`~::~='~=~ ~:~:~:"::~:*[:~:~:"~=:~='::~:~'~:~:~~i~ ==,~==~: '"~: ::"'::~ ......... :=: ....... 7~-'-:~'~::':'::";"::':~'"'"::':"':'?~:;::'~:~E:"'~""! ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::... / ':"":"":::":::::::'~:::::~ ..... .......... ' ...................... ::::::::::::::::::::::::::::::::::::::::~..+. ,.:,u .................. ~_-~ .......................................... : ............ u.'::: ..... / ~"-:'::' ................... ' ............................... ,.:,.:,::::~ ............../. ,':.'200 !::iKF.:O:i:i', ~'""::' ~57:12 ='"'" 27 4F.: S 4:B /_-,0 E 0,'i71 670 09 .::, ................ :: ....... "" 14.1 ~'~ 3 :/ E: :1 .... ':! ':~ ...... /:, 30 () :' '" - '" "- · .,,:',':,,'-, '77 !::~::::00 77 :,."::: :1.7 S 42.10 E o. '"":::' 704-F',/:., S lzl. 4'::' ........... . ...... . .. ~.~.'~ ...I . ..... ~... ,, ...,, . I ~ . . ......... ~ ...... ...... ~"': .... :Z ~ :~--'[~.,;¢),'-'~"~["-',-t~ ~'~.~. .~:tr'~ ~ ~. :~;,~T.~ ~:~.:~ :::::::::::::::::::::::::::::::::::::::::: ::::::~,-.:: :.:::.;~. ............. :::::-:::.: · ...... ~:~.~.~ ..:~ :::!.::::t. :~.:? .... ~.m:~.r.::!'::::::::.:::::::.iiZ~.i:~:;;:~7:i:: .~: ::"~'~:~%' .:' "':~ :.?: . ."' ::: ':':"': ....... ' ...... :' ............. "i::~, ~:',:% .......................... :": ............ ~:::::~:::::i ......... ~::' ........... ............... i;~ .......... ~i ii~: ~ ~ ::~ ...... ~ ....... ~i :'~ i~:: :: ::': ".~/r.O~_i:: ~::' :::: ~":i:i:::"~::, i.i ::::'::,o...._. :,:~"'*"~L'~:'~'~:::~:~:~:~:~:/. ,::,...:. ::~'~:: ~, 1 G 1. ,:,.:- .:, -I- ~...:, ............. '::::~:::"':':~::::'~':::"~:~.:, ............ Zl.O~:'::?~:~:~. ................ ():::::::::::::::::::::::::::1..' ................................... ........... ::::::::::::::::::::::::::::::::].. C-,O :: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::,:, /.':, :'1::':"::. ,.-.', ..:," ::~ ':': ;~?.:", ........... ::::':':'"::::'~::::;::!"::"~:'::':1 ...., ? 'j~:~''~; . .~:: i'2:? :"T.': ..................... ' ............... 1 =':. :'~::' .._,~ ~::'. ':':~::'i;;()L) ........ .... 6800 /:,:5: I ? ,, 1:5: /.:,_723, 1:2.: :B/.:, 27 :-:: :B::::, 8() E 1 ,, 87 ':.-'O&, :::i:0 ,':,900 6:_::'.-::"!i;' ,, :'_:',0 6:'-':0:_--:. :E:O ::::6 .'5/:, ::"; 3:::. 0 E" ('~, 68 !.-'/.g 3, 64. S 1/:,53, :,-38 lie 1 'i. :~,:!:, ,, 7'7 · HEft:;: I Z ON"f'AI_. [::l I :'2;F'L.£-~L-:EMENT = '.--.' 11/-,. :2:1 FEET (~T :--;I-II_l'l-I--I !];7 DE~:]i, :5:0 M_'[ N ,, EAST ~..4."1" MD := '72,'.!:,,./::, KUPARLIK FI EI_B .. I_1 i'". :..'2, I'" I...I "l"i'-=,' U E ::.::U B- iii;E A TO T A L.. I':::LIF'(~F~LII<] F: ]; ELD C F)I~'IF' L.l"r' A "1' I 0 N D A"I' E ,J UI",IE 6, 1 '.--;':~: :3 "I'F( i...llE :BI..IB- .'.::; E F4 'I'O'I'~:iL :, ~.~ ~.~, ~..., ~~~ t.:, ..' ,"-,, ..::, ::~r 'Z." / ...'i (.':.~-.".'~. / C' I:::. .::; / / ,, ..Zi '~'1' .L .,::: ,. t..l~ / ./:, 1. ~i: F.:; D 7 ? 6 ,, 0 c) ti:.: 700, 00 6.6 ~.:.'~, :3 (.~, ':.:_"i? !]~ ':::i':" :;' .': ,, ()0 ':'"-' ¢' . , ............... ::,,:, .~c-~. O0 7c'.~Zl. 2./_'., ::: .t 44::;', C~O E ,1,0:3. :L 2 :[ :::, :;..::::3 : ........ : ....... m ",; '::: '::-6 4 'J:-~',';:~:::'~n~f~? ~r,:-~ta~:, :~ r'~i~) : /-, ,::.,,~:~ ............ :.::,~:¢::t .... .,., .'l.l~:~ ........................... ~,::~::~.:'.:'::~:~0 .................................. ~.~.~:~..t..:.1 ..... ~:~ .................... ~......~:~:.: ,,:...:.:,~~~:'./.~ .......... E.:::: ..................... [..,~.~...] ~ t:.:."'.f.'~,..,:...~... ,~.~ .... . : :: :. ~,~ ','~. ~t~, :.t~ :::::::::::::::::::::::::::::::::: .~.. ~':' ,,~. : .~, .::. -. ::':.::::' :::::::::::::::: ::::..r¥.:~.:. <~. :....::i:~.¥:4t::::. :::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::: .:::...1::::¥: ..:::::::::::.. ::::::::::::::::::::::::::::::::::::::: .':.~.::.. :::~..::~:::...t~.:. ~:.i:i:::!:?~:';:!::: .:~ d::: .::::..:::::..::::::::::::::::::::::: ::::::. :': r:::: .::::' ::::::::::::::::::::::::::::::::::::::::::::::: :::~.::!:.~k ::.~ ::;::::;:: ::::::::;: :::::::::::::::::::::::: :.::::::::::::::: .":'¥.:': ::::::::::::::::::::::::: '::: ::::::::::::::::::::::: ': :: :::.: e, c'.. ~, ::::. :~'~?~:~:~:~':~L: ..~ ,.:, .,~': (:!~,:! :?...:.::?~:~ :~:::~:~:~:~::~:c:~:~:~:~:(i:~:~:::~:?~::~::~:~:~:~:~::~:::::::::~:~::?~r~:~?~?:~:~:~:~:~?~:~:~:~::~i::~:~:: :..~ ~:~::.~: ::'.:~:~:~:::~:~ &:~C!:~:::.~ ?~?::~:r ~:F,~?~:~.~:::.::;:': ':::::::::~ ~:?::: ~]~z~?.~:~:~:r :~::::~:::. r~:~.'. ~::.::: ::~:~.~.::::::~:~:~:~:~:~:~:~:?.:~:~.:l;:~:~.~:~: ::t)~:~¥~::::::::::::::::::::::::::: ~:.'.::~:::: '.~:~:::~::~. ~::.::~.:?~;:~ z.~ ~?.~:? ~:::~::~: :::. :::.:: ::~:. '65~7 .t.~:"":'"":~6:.-.'".?'.r.'.~-;;a 0 .... : .... ':' ~;:ZO"O' Cl ~'P 3 ::':'4,!.'7i"'"S ~'"&'O"..ff;': ~:, :Er 4'? Z~", 2zi. 2:2,: 0 ~ ........... .6::3'i~;'F-'i /:,.'.'~:'.::;',.!:,. O0 6300 ,, O0 7():;?.t c'-,4'.~;',~,, (')0 6,.I. 00. O0 J.O].:;::, :.'.i:'P '.:; 1677. '.?2" E .~:.;:2!5,/.:,'.~ :2!5, 77 THE N[-~."F~l:?E'.iii;'i" 20 FOOT HD (FROH R~]D'rUS ~'"~.F'-L-:LIF;~k/{.~TI_IF-?E) F'OZl;4"I".i:: 0 © 0 ,~ 0 e 0 STR~':.~T I .. i:,,r-~l' H I Ii: '.:£:1 iI'"IMP~I:';:",; KIEF:R];VE:I:I IJ.':':;II',,.ll]i [.'il Il._ I:dE F" "I" H F:: ¢ll',,lI:l Sl:::'liiilj:~:F;~",/ '.iii:l...ll'.,l :iii;I...Ij::;~'l:.~Y . ~.__..~...~ ...... ~:~.~.::::::r:::. :,: :,',: >:,,. ..... ::,':: :":': :'">:: xI ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: -":: :::::::~::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::'u ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :~¢k:;::::~.. :::,4~i~:'.,.. :.k,::.:':::r:: >:;: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ,'..;::'~,~, :: ;.~:r.~::.a.~ ::.:uzx :..', :,~ .... :"': ~: _. t'~r...[t l.~l'.,l .... ::,LJ~-'"....,L..I.-I ML'-I \ t J.L..i-tL ~. i.21"\ / L.~ .L 1\t ..... ....~/1..:,J\lJ... ]. ::, ) SI.Z F': 0 ;I. "1" I 11 I',.I IR C: ., Arco Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-30051 Well: ~l-Y5 (SEC01TllN R09E) Kuparuk Field North Slope, Alaska Survey Date: June 5, 1983 Operator-Samec Scale: 1" = 500' -50~..00 TRUE NO~TH Surface Location (0571SNL 1971EWL) ~oo~. oo ~o1~. oo ' --~oo. oo ~5~o ~ --1000. O0 ~721~5 .-1SO0. OO HORIZONTFIL PROJECTION Arco Alaska, Inc. Our Boss Gyroscopic Survey Well: ~l-Y5 (SEC01 TllN R09E) Kuparuk Field North Slope, AlaSka '~' Survey Date: June 5, 1983 Operator-Samec Scale: it' = 1500' 0.00 500. O0 3000. O0 4500. O0 SO00. O0 7500. O0 ~ ~72S6 2116.31' @ S57° 30'E ~sbo. oo Soho. oo VEBTIC~4L PF~OJECT ION Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · 'Operator, W~i Name andF Reports and Materials to be received by:. .Required Date Received Remarks cCmPletion Report Yes ~el 1 History Yes 7 _Samples .,~r-?/ · ' '~-'' . · , ~u~ ~.o~ . ,/I~C ,i21 d/'.?,... .Core Chips --- //'~/k'e~ *'*: , Core Description Registered Survey Plat _. x~s -.zq~/F~--~:_~ ~,.~, < / Inclination Survey * -- /h-~,~' _Directional Survey -, PrOduction Test Reports V " / . , .- · .., Digitized Data / KUPARUK ENG i NEERI hE; TO: William VanAlen RCM: D.W. Bose/Shelby Jo Matthews Transmitted herewith are the following- PLEASE I',~~- FILM, T- TAPE, PC- PHOTOOOPY P. O. ~X 100360 Alaska. O~l & ~,, uons~ ~~~E, ~. 99510 Anchorage KUPARU:: DC I NEERI big TRAN~.4 ! ~-FAL TO: DATE.: William VanAlen Ff'<~A: D.W. Bose/Shelby J. ~tthews Transmitted herewith are the fei lowing. PLEASE IkEFFE: 13L - BLUEL! NE, S - SEP IA, F - F i ~ PC - FHOTO33PY' DAT~- ' j ij L "' ~ ARO0 ALASKA, INC. Alaska 0il & Gas Cons~ Commission Anchorage A~: ~iE~Y J. ~tB~ - ATO/111 5-B P. O. ~X 100360 ~~E, ~. 99510 ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 28, 1983 Mr. C. V. Chatterton Commi ss ioner State of Alaska. Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Subsequent Sundry Reports Dear Mr. Chatterton' Enclosed are subsequent sundry reports for the following wells- 1Y-4 1Y-5 If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. VanDusen District Dr_iii.lng Engineer PAV/GRU3L58:sm Enclosures Alaska Oi! & Gas Cons, Commissinn .Anchorage STATE OF ALASKA ALASKa, .~iL AND GAS CONSERVATION C _.,,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER [] 1. DRILLING WELL [] COMPLETED WELL ~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-87 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20966 4. Location of Well Surface: 571' FNL, 1971' FWL, Sec. 1, T11N, RgE, UN 5. Elevationinfeet(indicate KB, DF, etc.) 96' RKB 12. 6. Lease Designation and Serial No. ADL 25646 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-5 11. Field and Pool Kuparuk River Field Kuparuk River 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 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). ND adapter flange & master valve. RU Dresser-Atlas mast. Ran CBL/VDL/GR/CCL f/7126'-2150'. Ran gyro f/surface-7100'. RD Dresser-Atlas. NU adapter flange & master valve. Secured well. Accepted rig ~ 1430 hfs, 06/11/83. ND adapter flange & master valve. NU BOPE & tstd - ok. Ran 3-1/2" completion assy w/tail ~ 6286', pkr @ 6267', & SSSV @ 1781'. Ran GR/CCL. ND BOPE. NU tree & tested to 3000 psi - ok. Disp well to diesel. Pressured up tbg to set pkr. Dropped bar & perf'd the following intervals: 6381'-6472' 6603'-6607' 6618'-6638' 6657'-6670' Dropped ball, press, up, sheared tbg release @ 1600 psi diff. released rig ~ 1530 hrs, 06/13/83. Closed SSSV. Set BPV. Secured well & EEE VED .JLiN 2 9 Alaska 0il & Gas Cons. C0rnmissi0rl Anchorage 14. I hereby cert~y that the foregoing is true and correct to the best of my knowledge. Signed//!/~J.~,/~ (~,/~ Title Area Drilling Eng,neer The space ~ow~or Co~ission use Conditi~ of Approval, if any: / By Order of Approved by COMMISSIONER the Commission Date j Form 10-403 Rev. 7-1 ~0 GRU3/SN29 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 15, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells' * West Sak SWPT #1 * Ciri Wolf Lake 1A-4 1Y-4 1Y-5 1Y-6 1Y-7 1Y-8 1E-14 2Z-1 . 2Z-2 2Z-3 2Z-6 2Z-7 2Z-8 * Due to please Thank you. the confidential material contained in these reports, handle and file in a confidential manner. Si ncerely, P. A. VanDusen District Drilling Engineer PAV/SH7'sm Attachments JUN 2 o Alaska Oil & Gas Con~. Commission Anchorage ~--STATE Or: ALASKA ~- " ~- ' ALASK .... AND GAS CONSERVATION (. ,VIISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wellXt~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well 571' FNL, 1971' FWL, Sec. 1, T11N, ReE, UM at surface 5. ElevatiOn in feet (indicate KB, DF, etc.) PAD 67 ' , 96' RKB 6. Lease Designation and Serial No. ADL 25646 7. Permit No. 83 -87 8. APl Number 029-20966 50-- 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1Y-5 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of May ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1000 hfs, 05/24/83. Drld 12-1/4" hole to 2250'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 7003'. Ran open hole logs. Cont. drlg 8-1/2" hole to 7266' TD. Ran, cmtd, & tstd 7" csg. Displ top 360' of well to diesel. Arctic packed 7" x 9-5/8" annulus. Secured well & released rig ~ 0430 hfs, 06/01/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8", 40#/ft, J-55 HF-ERW, BTC csg w/shoe @ 2205'. Cmtd w/700 sx AS II I & 250 sx AS '1. 7" 26 O#/ft, K-55 HF-ERW, BTC csg w/shoe ~ 7232' Cmtd w/600 sx Class "G" cmt SEE DRILLING HISTORY 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/SP/GR/FDC/CNL/Cal f/7000'-2203' BHC/Sonic/GR/Cal f/7000'-2205'. 10. DST data, perforating data, shows of H25, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED L-/.~~ ~ / '/~ TITLE DATE ~ NOTE--Repo~on {his f~m is required for each calendar month, regardless of the status of operations, and must be f~d in duplicate with the Alaska Oil and Gas~onservatio~Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~04 HI LL/NR27 Submit in duplicate 1Y-5 DRILLING HISTORY NU 20" Hydril & diverter & tstd same. Spudded well @ 1000 hrs, 05/24/83. Drld 12-1/4" hole to 2250'. Circ & condition hole. Ran 56 jts 9-5/8" 40#/ft, J-55 HF-ERW, BTC csg w/shoe @ 2205'. Cmtd 9-5/8" csg w/700 sx Arctic Set III & 250 sx Arctic Set I. Bumped plug w/2000 psi - ok. ND 20" Hydril & diverter. NU FMC 7" csg head. Tstd - ok. NU BOPE & tstd to 3000 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.1 ppg EMW - ok. Drld 8-1/2" hole to 7003'. Ran logs DIL/SFL/SP/GR/FDC/CNL/Cal Run #1 f/7000'-2203'. Ran BHC/Sonic/GR/Cal f/7000'-2205'. Cont. drlg 8-1/2" hole to 7266' TD as of 05/30/83. PBTD 7151'. Ran 185 jts 7" 26#/ft J-55 HF-ERW, BTC csg w/shoe @ 7232'. Cmtd 7" csg w/600 sx Class "G" cmt. Bumped plug w/2000 psi - ok. Instld FMC tbg head & tstd to 3000 psi. Displ top 360' of well to diesel. Arctic packed 7" x 9-5/8" annulus w/250 sx AS I. Secured well & released rig 0430 hrs, 06/01/83. HILL/DH21 06/13/83 ARCO Alaska, In( Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Hay 27, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1Y-5 Dear Mr. Chatterton' Enclosed complete Si nce we earliest questions is a Sundry Notice for the subject well. We propose to this well with our workover rig. expect to start this work on June 10, 1983, your approval will be appreciated. If you have any , please call me at 263-4970. Sincerely, JBK/GRU3L18' sm Enclosures RECEIVED JUN 1983 Alaska Oil & G;~s Anchc~ra~te ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -' ALASKA OIL AND GAS CONSERVATION Cu,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER I~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-87 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20966 4. Location of Well Surface: 571' FNL, 1971' FWL, Sec. 1, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 96' RKB 12. 6. Lease Designation and Serial No. ADL 25646 9. Unit or Lease Name Kuparuk River' Unit 10. Well Number 1Y-5 11. Field and Pool Kuparuk River Field Kuparuk River 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 J~X Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~X 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 complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2 #/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated start: June 10, 1983 RECEIVED Alaska 0il & Ga.s Cons bu~unlss~0~ Anch,:~raf4~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~'~~ ~/~ Title Area Dri]]in§ Engineer The sp ow~o use ission Conditi~s of Approval, if any: Date Approved by COMMISSIONER /~pproved Copy Returned By Order of the Commission Date Form 10403 Rev. 7-1-80 GRU3/SN10 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate .I. LOCATE D IN PROTRACTED SEC.I.TWp.. IIN;I.,R,G.E;9 E:I .tJM!,A.T .M, ER.!D!AN? . RESERVE 'PIT RESERVE PIT RESERVE. PIT 180' ' , PHASE. II Y.597§115. ;5;5 X= 5;5146024 LAT. 70° LONG. 149° 44'40.818" 211 ' FNL, 1792' FWL Y=597511 5.50 X= 551520.06 LAT. 70° 20'55.0296" LO .I~G. 149°44' 59.070" ZII FN L,.1852' FWL Y- 5975115. ;54 X' 551580.12 LAT. 70° 20' 55.0275" LONG. 149°44':~7. ;515" 2 II ' FNL, 19!?..' FWL _--__ , , , ,_,,J,i I · 4. Y~ §975115.44 X= § ;5164'0.4§ LAT. 70° ~-0' ;55.0P. 60" LON (3. 149°4'4' :~ §. 5157.,' .THIS SU['~VEY I O.8. A NOTES' VICINITY'MAP' 5 cole': I%lml. .I. ALL Y 8, X COORDINATES ARE ALASK$ STATE PLANE,ZONE 4. 2 I1' FNL, 1975' FWL ; _..,,_. ...... X= 53164~,45 , ' X, 5~158~1 -, ~ 3'~ Kup~ru~ ~'ro~ect .._ North Slope Drlllln9 LAr 70°20 3~.4esz ~. .LAT. m°zo a~.4eoe' LON& 14g ° ~ 3B.Bg7 '~ ~Ne. I~°~5~,110' 571' FNL, 1971'FWL ~, I '~71' FNL,18BI' FWL '" AS EUILT LOCATIONS e.Y, sez47~.~a .'· e. Y,~e147~.4e ~ . PHASE I X' 531580.41 , X' 531460. B~ ~T. ~0° 20' 31.4881" .' LAT. ~OOZO'Sl. 4891' [ eate: ~Ar~.' 198~ ~ ' " ' 8~ !'~'"' , ,,o0 LONG. 149°44' 57. ~1'' LONe. 149°~'40.8~4'' 571' FNL, 1911' FWL . 570'~ ,FN L,1791' FWL [ drawn by :J.O. ' II dwg. no.9.05 '05.12d28 ............... .L''"" ' "' *'~'~_ ~. DISTANCES' TO SECTION LINES ARE GEODETIC. 3. SEE REF. DWG. 229'88, SHl'. 7Y-12-~OGI,REV. 7A. 4. DRILL SITE AND Y 8~ X COORDIt~,%TE$ ARE BASED ON MONU:.'.Z. NTS I'Y EAST AND' I'Y MIDDLE BY LHD ASSOCIATES. §. EL. BASED ON MON. I'YMIDDLE BY t.~D a$90C. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPE. RLY REGISTERED AND LICENSED TO PRACTICE LAUD SURVT_YIN~3 IN ,THE STATE OF ~, ALASKA, AND THAT THIS PLAT'REPf~"-SEN'r8 A'SURVEY MADE UNDER MY DIRECT SUPERVISION, AND THAT. ALL DETAIL3 ARE CORRECT AS OF' MARCH I, 1983. MEMORANDUM State of Alaska TO: THRU: Lonnie C. Smith ~' C omnis s ioner FROM: BObby Foster ' Petroleum Inspector ALAS~A% OI_~L AND GAS CONSERVATION COMMISSION C. tterton DATE: Hay 26, 1983 - FILE NO: TELEPHONE NO: SUBJECT: Witness BOPE Test On ARCO's 1Y-5 Sec. 1, RllN, R9E UM Permit #83-87 Wgd~esday, MAY:2.5:, 1983: The BOPE test began at 1=30 p.m. and w~ concluded ~t~ ~':-00 p.m. as the attached BOPE inspec- tion report shows. There was one failure. In summary, I witnessed the BOPE test on ARCO's 1Y-5o Attachment: Larry McDowell notified me that the check valve had been repaired and tested. 02-00IA(Rev. !0/79) STATE OF ALASKA ALASKA OII~-~ GAS ODNSERVATION CCMMISSION B.O.,,.E. Inspection Rcpo~ InsDector~ Operator y Location, ~ec Drilling ContractOr Location, General We11 Sign Ceneral Housekeepin~_~ ~eserve pit BOPE Stack' ;'''~'~ '~."!. ':': Test Pressure Annular Preventer': .' . Blind Rams Choke f,ine Valves. Representative Permit # ~~ ~. ¢~Casing .Set · Rig ~-~ Represe ntat ive.~_,: '.~. ' ACCUMULATOR SYSTEM Full Charge Pressure ~/O O psig Pressure After Closurej~'.~ psig Pump incr. clos. pres' 200 psig. - Full'Charge Pressure Attained: ~ Controls: F~:aster~ Remote ~.~J Blinds switch cover / Kelly and Floor Safety Valves · H.C.R. Valve- , Kill Line Valves Check Valve. : / Test Pressure /_ Test Pressure I i Test Results: Failures. . . / Upper Kelly · Lo~r Kelly Ball TyPe / Test Pressure Ins ide BOP / Test Pres sure Choke Manifol_d_~___~est Pressure. No. Valves No. flanges _~_ ~) Adjustable Chokes / }~drauically operated choke / Test TimeL~~__hrs. sec. min.-F~sec. Repair or Replacement of failed equipment to be made within ,. days and InSpector/Ccmmission office notified. Distribution orig. - AO&G2C cc - Operator cc - Supervisor Mr. Jeffrey B. Kewin Senior Dri!ling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Res Kuparuk River Unit 1Y-5 ARCO Alaska, Inc. Permit No. 83-87 Sur. Loc. 571'FNL !971'FWL, ~]ec. 1, Tll~, RgE, Btmho!e Loc. 4195'~R~, 1503'~_., Sec. 1, Tll~, RgE, L~<. Dear }~. Kelvin ~ Enclosed is the approved application for pe~it to drill the above referemced well. ~ coring is conducted, a one cubic inch chip fro~.~ each foot of recovered core is required. ~i~Ies of well cuttings and a log aze not required. A continuous directional survey is required as per 20 ~A.C 25.050(b)(5). If available, a tape eon~a{ning the digitized lo~ information shall be submitted on all !og~ for copying except experimental logs, velocity surveys and dipmete~ surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spa~-ming or migration of anadromou~ fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by tBe }iabitat Coordinator's ~ff~ce,~ ~ De~ar~ent~ of Fish and Ga~e. Pollution of any waters of the State is prohibited by AS 46, Chapter q, Article 7 and the regulations promulgated t~ereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Wate~r Pollution Control Act,~ as a~epded. Prior to co~enczn~.~ operations you ~_ay b~ contacted by a representative of the Depart~ent ~ ~nv%ron~ental Conservation.. aid us in h d '-= please notify this office sc .:e~ul~.~$ field '~or?_, . ~ou~s prior to c~mencin? installation of the blowout Mr. Jeffrey B. K~..~.n .- Kuparuk River Unit 1Y-5 -2- May 20, 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Com~mission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Alaska Oil and Gas Conservation Commission Enclosure cc~ Department of Fish & Game, Habitat Section w/o encl. Oepartment of Environmental Conservation w/o encl. be ARCO Alaska, Inc. Post Office B~,.. J60 Anchorage, Alaska 99510 Telephone 907 277 5637 May 11, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1Y-5 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1Y-5, along with an $100 application fee. o A ~iagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity plat. o A diagram and description of the surface hole diverter system. o Diagrams and description of the BOP equipment. Since we estimate spudding this well on May 23, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, ~A~ ~~~ngineer JBK/JG:sm Attachments Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanlicRichfieldCompany · ?'~-. STATE OF ALASKA ~'-. ALASKA C,._ AND GAS CONSERVATION CO~,..,41SSION PERMIT TO DRILL 20 AAC 25.005 lb. Type of well EXPLORATORY [] SERVICE [] STR~GI~IIC DEVELOPMENT OIL ~ SINGLE ZONE U DEVELOPMENT GAS ~ MULTIPLE ZONE ~ 9. Unit or lease name la. Type of work. DRILL REDRILL DEEPEN 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. BOX 100360, Anchorage, Alaska 99510 4. Location of well at surface 571' FNL, 1971' FWL, Sec. 1, T11N, RgE, UN At top of proposed producing interval Target (~ 6131ZTVD; 3760' FWL, 1320' FNL, Sec. 1, T11N, RgE, UN At total depth 4195' FWL, 1503' FNL, Sec. 1, T11N, R9E, UN Kuparuk River Unit 10. Well number 1Y-5 11. Field and pool Kuparuk River Fie]d Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 96', PAD 67' I ADL 25646 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 32 mi. NW of Deadhorse 1Y-6 well 60' @ surface feet 16. Proposed depth (MD & TVD) 7531' ND, 6822' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT2700 feet. 21 14. Distance to nearest property or lease line miles 3309' FEL @ surface feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 34 o (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 05/23/83 2521 2982 psig@ GO°F Surface psig@ 5974 ft. TD (TVD) SIZE Hole ! Casing ~4" 16" ~ 2-1/4" 9-5/8" 8-1/2" 7" Weight 65# 40. O# 26# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 PEB J-55 BTC HF-ERW K-55 BTC Length SETTING DEPTH MD TOP TVD 80' 29' I 29' 2171 ' 29' I 29' I I 28' I 28' 7503' MD BOTTOM TVD 109'11 109' 2200'12200' I 7531'16822' I I QUANTITY OF CEMENT (include stage data) +200 cf 750 sx AS I11 &250sx AS I 308 sx Class "G" neat 213 sx Class "G" extended ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7531' MD (6822' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2521 psig. Pressure calculations are based on latest reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be ]eft in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon comple- tion of the job. 1Y-6 will be 60' away from 1Y-5 ~ the surface. There are no closer wellbores anywhere downhole. Top of cement for the production string will be placed ~ 2347' MD, approx. 500' MD above the West Sak sands. 23. I hereby certify~J;)at the foregoing is true and correct to the best of my knowledge // SIGNED / /./j/~/~~~ TITLE Area Drilling Engineer · es. ce CONDITIONS OF APPROVAL Samples required I~YES [~O Permit number APPROVED BY Form 10-401 GRU3/PD25 Submit in triplicate Mud log required I Directional Survey required APl number []YES [~NO ! ~YES []NO 50-- (3 l-4- 7/0 ~,(, Approval date /) 0-'~/83-'~ ,~ i SEE COVER LETTER FOR OTHER REQUIREMENTS ~''-~"//')///'/ ,COMMISSIONER DATEMay 20,1983 ~/~/~ by order of the Commission ~ j ~. F~~ ';~ ~ ~ .... ' ' ' ' " ~~~ i ~ ~ ~ ' : ~ , i I I I ', ~ I '. i ~ I I , ' · , : : ~ ; ~ . i i ? ~ ~ . , . ~ . , . . , , . , ~ . . ~~ ..... , . . . , i : : ~T i ! ' . ~~l ~ : : '~~,, ! : : : ' : :~~ ' ' -~ ~ ~~ : , : :. · ~ ~ ~ : . ,: , i ' .. ~ . ' - , .~ i :' ~ i ! i ! i I i I I I I I J ~ J : J ~ ; I I J ~ ~ ~ ' I ~ ~ ~ ~I ~ ~ ~F ; ~ , [ : [ i ~ I , . ~ .... ~ ~ , ~ .... ~ ~ ~ ~ ~ ~ , . ~ ~ . . , , ~ . i i ~ i i i i ! i ) , · ! [ : i i , · , I , i , i , , , · ': ~ j~ i ~ i i ! ! i I I i i I I~, J ! ~~~~~~ ~ , : ~~~~ ~ : ', I ~ ' ~ ' ~~ ~ { ~ , : :v~~ ~:, ,~-I i ~~_ i -~ ~ i ' ~ ~ , I : i~~m ' : . ~ . : I . I i , ' : l , ,,, : .... ,l , , .... _ . . , ~~~~ ........ , ~ ~ ~ : , ~ . ~ ~ . ~ .......... L Surface Diverter S~,s:em . 2. 3. 4. 16" - 2000 psi Tankco starting heao. Tankco quick connect assy. 16" x 20" 2000 psi double studOed adapter. 20" 2000 psi drilling spool w/!O" side out'lets. 10" ball valves, hydraulically actuated, w/10" lines to reserYe pit. Valves to open autonmt'ically upon closure of annular preventer. 20" 2000 psi annular'preventer. 20" bell nipple. ~aintenance & Operation Upon initial installation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines 'every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. DO not shut in well under any circumstances, i 16" Conductor Alaska Oil & Gas Cons. [;ommissiop Anchorage ANNULAR PREVENTER Ci ~ BLIND RAMS 8 ( . ) L < - PIPER.a2~S · 7 ) ) £. PIPE ARMS ) S CSG HD · a~,(a Oi! & Gas Co.~s~ Commission Anchorage D[AGRAM 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11' - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8' - 5000 psi blind rams '9. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PS! WITH 1S00 PSI OOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY ANO RECORO THE TIME AND PRESSURE REPAINING AFTER. ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORO ON NAOC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE, 13-5/8' BOP STACK TEST 1. FILL BOP STACK ANO MANIFOLD WITH ARCTIC DIESEL. 2. ,CHECK THAT ALL HOLO DOWN SCREWS ARE FULLY RETRACT- KO.. PREOETERtiINE DEPTH THAT TEST PLUG WILL SEAT ANO SEAT IN WELLHEAO. RUN IN LOCK OOWN SCREWS IN NEAO. 3. CLOSE ANNUl_AR PREVENTER ANO CHOKES ANO BYPASS VALVES ON MANIFOLO. 4. TEST ALL COMPONENTS TO 2S0 PSI ANO HOLO FOR MINUTES. ' '- 5. INCREASE PRESSURE TO ~1~00 P~ANO HOLE FOR lO MINUTES. BLEEO TO ZER 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE 7. INCREASE PRESSURE TO AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED OOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, . WITH 3000 PSI UPSTREN~! OF VALVE ANO ZERO PSI DOWNSTREAm. BLEED SYSTEM TO ZERO PS~. g. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RA~S. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEEO TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLINO ILAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEEO TO ZERO PSI. 12. OPEN BLIND RAPS .AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN ANO SENO TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE OAILY. g ANNULAR PREVENTER BLIND RAHS' ) :o PIPE ARMS ) 9 ( D IAGRAN .~2 i3-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-1/16" - 3000 psi tubing head 4. 7ol/16" - 3000 psi x 11" - 3000 psi double studded adapter 5. I1" - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi drilling spool w/choke and kill lines g.. 13-S/8" - 5000 psi pipe rams 10. 13-5/8" - 5000 psi blind rams 11. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1o CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI OOWNSTRFJ)~I OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD TIlE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. £ PIPE ARMS 7 C I HD 2 ~G Alaska Oil & Gas Cons. Commission. AnchOrage ' 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTI.C DIESEL. ~-. CHECK THAT' ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERJ4INE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HE~. 3. CLOSE ANNULAR PREVENTER AND m. CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO ~ AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PiPE MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTE}t TO ZERO PSI. g. OPEN TOP SET OF PIPE RAMS AND CLOSE BOl"rOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO .ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAJflS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RA/4S AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCi TIONALLY OPERATE 8OPE DAILY. CHECK LIST FOR NEW WELL PERMITS Lease & Well No. ITF~ APPROVE DATE (2) Loc ~'~ ? .......... , (2 thru 8) (9':thru 11) (12 thru z. 0)-- (5) BO PE ~.~-~. ~i ~-~r'u '24)- 1 Is the permit fee tt ched · a a eeeeeeeeeeeeeeeeleeeeeee.eeeeeeeeeeeeee · 2. IS well to be located in a defined pool ......... 3. Is well located proper distance from propert: 1~; iiiiii' ''i[ii[!ii 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 ...................... ;;it ~ '' ' ' 8. Can permit be approved before ten-day .......... '' . '.' .... . 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YE S NO REMARKS Does operator have a bond in force .................................. (,< .... Is a conservation order needed ...................................... Is administrative approval needed ................................... 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 o., ......... Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ~i~' ~ Does BOPE have sufficient pressure rating - Test to _~ ; 11 Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional. requirements ............................................. Additional Remarks :~ o ~o Geology: Engineering: HWK LCS ,.~.::~/' BEW ~ WVA~~ JK~ HJH rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 7; ,~-..c'. //' "O O &/ 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. ~T~IS TAPE ~VP O]O,HO~ VERIFICATT['I{,~ LISTING PAGE TAPE HEA.DE[~ ** ~ERVICE NAME :8CRVIC )ATF. :~3/06/27 }RIGIN :0000 )~,;v'IOI~S TAPE : ]ftM~ENTS :LIBRarY T~PF EOF I,:* FILF ~T'iADEP ";;', '~' C ~RSION ~ ~.~X~Mltl~ L.,~NGTN I 1024 FILM TYPE', ~REV ~'O!IS FILE "'U .. ARCO aLASKA FN ." KI.!PA~UK row~: ~ F, C 'r ~ 1 ,".TRY: Ut,tiT TYPE CATE: SIZE CODM 000 000 016 065 000 000 O04 065 000 000 008 065 000 000 002 065 OOO 000 004 065 000 000 002 065 000 000 008 065 000 000 0O6 065 000 000 004 065 VP 010 ~{¢)2 VERIFICATION ~,ISTI~(, PAGE 'YPh~ FLUID ~IT SIZE E,N$ITY .ISC t)$ I TY 'LUID LOSS = 3,11,0 ~ ~4,0 DF = ,920 ~ 4,0 DF : ,840 8 $4 0 DF SANDSTONE ********************************************************************************** ,VP OlO,B02 VKRIFICa, TI©!'~ LISTI~G PAGE, * SC[,'{I,,~U~BERGER~ LOGS INCLUDED WIT~ T~4IS ~AGNETtC TAP~]{ * * DUAL FOCUSED LO~ fDIL) * MOR~:~H.O[~h.~ (.,O~PE, NSAI~O LOG (B~C) * * MrJ~ATIO'~ DEN:SITY: CO~P~I~MATED :LOC; (FDC) * * GAM~A ~,AY bOG (GR} * )ATU~I SPECIFICATION BLOCKS 4NEE SERVICE, SERVICE Ut~IT ~Pl API AP1 AP1 FILE SiZE PROCESS SAMPLE REPR ID ORDER # LOG TYPE CLASS ~OD )MPT FT O 0 O 0 0 4 9FLU DIL 0~-~ 7 0 0 0 0 4 rLD DIL 0~ 7 12 ~6 0 0 4 ~ P D I L N V 7 J 0 0 0 4 ;~ ~I[, GAPI 7 31 3~ 0 0 4 )T BHC US/F 60 52 32 0 0 4 LEVEL0 1 C~E 0 ! 68 0 1 68 0 1 68 0 0 I 68 0 1 68 4.12.. 4 2 4 ~ ~ 4,4 ,42, 0 2 0 0 4 0 t 0 0 4, 0 9 2 0 0 4 0 93 0 0 4 0 3 0 O 4 0 3'2 0 0 4 0 i 0 0 4 0 f~ 0 0 a 0 1 68 1 68 1 68 1 68 ! 68 I 68 1, 68 * D A q' A * * , EPT .p PHI 'C N L ,IEPT P PHI CN .L ~F, PT ;p lpg4 T 'CNt, )gPT' IPH 1 ) F.7 P T ;P ~'p}q lr 7020 -19 06000 38 719 561 5O00 3 5469 70 o o 000 o -1,8 5000 38 964,8 561 5000 3 54t%9 6900, o0o0 22.015~ 31.543o 803 000o '3: 09o6 6., rio, OOOO ~24,03~3 44.° a,r. 42 466,2500 3,9277 6700,000 O . 28.0~169 36,279 3 68.2. 000<': 3.335q 6600,00()0 -28. 5000 41.1621 538.0o00 3.9551 fi~O0 0000 ,31 ~ t,')156 26..'$64~ 1016.5000 2.74~1 ,S P D R Fl 0 C a LI: S F I., b D g H SwLU GR C.,~ I,., I S F L tt SFT, U GP SF!.,!I ¢:; P CaLl 0{)7 8.50 ¢) 0 2,726& ,7500 ,2 0 0 '7 8,2813 4,0859 94,3125 0.0327 8,7813 2,g047 105.7500 0,09~6 9,92!0 5,1484 9!..3750 0.0195 9,4766 2,4766 ~8,4375 0.t) 557 9.7422 !2.007~ 54,7188 -0,0142 9,0703 1, '1:,, D T GR PT :[ L m D 'r G P. I 'b N k H 0 t:'.~ GR [) T GR DT G~ I I... ~t PT 2,5625 I L D - ¢99, 50 GR 2, 55 NC, Nb 97. 7500 NRAT O0 q~ 551 nCNt. 97,7500 NRAT .3,5996 R9,5000 2,4824 NCNL 04.3125 NRAT 2.4414 :IT.,D J, 06.6875 GR 2,441~ ~CNL 1,05.7500 NRAT 4,6680 .I!,D 06,6250 GR 2,3'770 NCgl ~1,3750 ~RAT 2.7656 ILD 96.1875 GR 2,4785 ~CNb 98.4375 ~;RAT 8,8906 IT,D 91.1250 GR 2.4336 54.71.88 2000,0000 -999,2500 1992,0000 3 ,2324 2,3477 '9464,~000 199~, 000 ,2324 3,4395 86,2500 2490,0000 2,8652 2,3438 1.09,6875 1832,0000 3,6914 4,5586 87,9375 2276,0000 3,1816 2,8340 101,6250 2'128.0000 3.474'6 8 0469 57;5313 2792,0000 2,5508 CNL P CN L 'FPT .P PHI ~P I ;:, H I IEP'T ;P IPHI 'CNL tfCRA ;P 'CNL ;P ~CNL ;P IPHI 6300 000o -25 343~ 44 O430 436 7500 3 9805 C,a,.LI $ F L U GR CALf 6100,0000 21 ~ a750 -gq9 2500 -999~ 250o caf.,I -999.2500 5~00.000() SPLII ~36.~750 GR -.99.25(')n DPI4R -999.250o CALl -ggg, 2500 )EPT ]~.()0, O000 8F'I,i~ '~P 37. 9062 GP ¢PHI 999.2500 ,"CNI, -999 2500 CALl ~r:~A, '999~ 2500 49 375O 48 3750 ('_) O225 ~ 7500 1,5,.34 q ' 5625 0.(1483 9,9687 0 ~.12 30~. 10 2813 ] L Nt DT R HOB DT DT 2695 2, , 245,625C q, 125 4 3320 1:58 ~ ,] 750 I) -999,2500 PH 10.3750 ~.;~ 4.0 (t 7 r~ I. 109.6875 -999.2500 !0.4766 GR 3,4551 ILi¢ 170.6~75 DT -909.2500 RNOF 9,1797 GR 164,0000 '9':~9,2500 I o. 0625 (.; 25.5313 I 1.. O 86,6:250 Ga ~, 5998 4,8 · 3 75, , 237] iLO .3125 GR 12~,3594 NCNb 119'5625 NRAT 2 3789 , It 113,8125 1$0,3125 GR -909.2500 NCNL 245,6~50 N~AT 2,9648 ILD 11,3,5625 GR -999,2R00 ~58.3750 MRAT 2.5R4.5 1.1.4,5625 -999,2500 125,3125 NRAT 3,0801 I:I.,D 109.6875 GR -999.2500 g~CNL 109,6875 NRAT 2.0254 ILD ;15,1875 GR -999.2500 NCNI, ~.20.6975 N~AT 3.1797 I[,[I~) 4,6250 GR -999.2500 NCNb 4,0 00 0 I~ P A "1' 37 0000 63,8750 2284,0000 2,7910 21,1543 ,80750 ooo 3,65.23 2,3359 1[4.4 , O0 ],7617 1,839~ 21~ 7500 99 ~2500 ~999,250o .,3 39 -999,2500 -999,2500 2,5723 115,5000 -999,2500 -999,2500 3 091a 113~6875 -999,2500 -999,2500 1 9600 115' ,0000 -999,2500 -999,2500 3,0957 154.8750 -999,2500 -999,2500 ..vP 010.H02 V'[!~RIFICATIO~ L. ISTIN(.; PAGE 6 ) E P T {P ~PNI 'CNI, )EPT iP ~IPHI )FPT ~P ~PHT ~CNL ) E P',I" ½P ~CNL )[<PT ~P ,'¢'N 5 ~P ~PHI rCNT, rCNL .~P ~PH l ?CML, 45,68:75 GR 1:19,1875 DT -999,2500 DRH{} -999,2500 R.~OB -999,~500 CALI ~1,3750 GR '999,2500 5400,0000 S F 1.. [.I 4,39 B 4 I b ~'~ -38,9067 GR 162,0000 DT -999, 500 DRanO -999 2..~.~0 R~Q~.~ -999. 500 CALI ~0, ........~ C., '9q9,2500 530 0000 '2~ 5000 -999 250O -999 2500 -99q 2500 GR 130.31 0': r~RH[) -999,2500 CALI 9,5859 52.00 0000 $F'1'.~] 1, 1,. lb I~,~ -32... 0000 CR 00,0000 DT -999 2500 DRN['] -999,2500 RH[)~ -999 2500 CALI 1,0,1484 GR -999. 2500 5100,0 O00 . 36.6'875 -999, ~500 2500 -999,2500 500o 0000 -40;0625 -q99 2500 -999,2500 4900 0000 -36:6563 -999.~500 -999,2500 -999,2500 48¢)0 0000 - 3~: -999 2500 I -9q9,2500 llO0.OO00 .42,1250 999.25C0 -999,2500 -9q9,2500 SFLU 2,1973 GR q0. 5000 [') R FI f,..! - 99 q, 2500 CALI 9,789l SFL~] 2,7930 GR 140.5000 DT ORHO -999,2500 ChbI 9,9687 GR $~'I..,i) 2 3320 GR 109i5000 DT D~HO -999 2500 C~LI 10,2734 G~ 3,!.777 .II, I.) 109,3~25 GR -999,2 O0 NCNL 1.19,1875 N~AT 3 681.6 I01 ~87 .... -9~9 2500 1.62 0000 1.1650 11,4,5625 -999 2500 1.30,3750 I LD GR NCN[, NRAT I LD NCN1, NRAT 1,7373 ILD 107,6~75 GR -099,2500 NCNI.., 90,00:0{1 NRAT 2,7793 I:bD 97,9375 GR '999,2500 MCNL 90,5000 NRAT 2,R652 ILD 104,7500 GR -999,2500 NCNL 140,5000 NPAT 2,4R05 ILD 104,3750 (;R -999.2500 NCNb 99,9375 NRAT 2.406] II,D 107.8750 GP -999,2500 NCNb 109,5000 NRAT 2,3770 II, D 1.10 3125 GR -999:250n NC~.I[., 112,8750 ~RAT 12~ '2109 ,1875 -999,2500 -999,2500 3,722'/ :999 '2500 ,2500 1,1787 145. 1250 :999,2500 999,2500 1 , 7432 -.999. -999,2500 2,947~ 104,375 -999,2500 -999,2500 2,9355 125,0625 ,,.999.2500 -999,2500 2 5156 95,8125 -999,~500 -999,2500 2 466a 1.07,9375 -999,~500 '999,2500 2,4297 116,1~50 -999, O0 ~99,2500 VP 010,H02 VERIF'TCATI[.}tu I,,,T'STI~(; P~GE 7 P -35 PHT -999 Cr~ I.., -999 NRA '999 E P T P PHI CNL EPT ~ N L PHI 'C'NL ~PT PH~ ;P ~': P T ;P 'C~L ;P !PPT 'C~,~ L 0000 SF[,U 93?5 GR 25()0 DRHO 2500 C A L ! 250 o 4 ~ 00,0000 38,0625 -099, ~500 '909, 500 '999,2500 4400 -3,4 -999 -999 -999 4300 -42 -999 -999 -999 4.200 -999 -999 -999 .4: '1, 00 -34 -999 -999 0000 3750 250 o 2500 2500 0000 9062 2500 2500 250 o ,00 () 0 ,0313 2500 "2500 ,2500 0000 2500 2500 25O 0 , ~500 39,5 999,~ '999.~ 3900 0 =36:4 -999.2 -999,2 -999.2 -37.3. -999.~ '999,2 00o 000 5(} 0 5O 0 $ 00 000 063 500 500 500 00 0 750 5 o. 0 500 5 o 0 SFLt..I G~ D R I4 Q CA[.I SFLU (,; R D R tq [) C A I., 1 SFI.,U D R H f't CALI SFI..~II G~ D R H 0 CALl $ F L t.l D R H 0 CA. bi SFL~ GR D R H C) GR I)RHC~ CALI ,9375: [),F -999,2500 RHOF~ 1. 0,0313 G ~ ,.q, 7,0 8 ... 8 I L r4 60 ;5625 DT 2500 R~aOB -999" "' 10,28~1:3 GP 2,4922 73'1250 DT -k~99,2500 i 0,7344 GR 7~.5176 tf.,~ .9375 D'r -9qq.2500 RHOB 1.0.7344 GR 3, I 4,06 I.[..,~"'1 104.~25 DT -999, .,00 RHUI4 10,5547 C;,','~ 2 6777 I[,~ 113!00O0 PT -999 2500 RHOF! 1.2.039! (;R 3.1a36 If,~ 92,0625 DT -909.2500 R~..lO~ 10.234a GP 3.121~ 102,2500 1.1,67!9 CP 2.2988 ILD 107,8:750 GR -999,2500 NCNL 87.9375 NRAT 2,2207 ILD 1,08,~2t25 -999 ~ 500 ~9..2500 ~RAT 2.5~17 ILD 108,5000 GR -999,2500 NCNb 73.1250 NRAT 2.6523 ILO 107~750 GR -999~ 50~ ~CNh 75,9375 ~R.AT 3.0'781 1!2,4375 -999,2500 ~.04,3125 NRAT 2,8535 IL, O 117,6250 GR '999,2500 NC~L 113,0000 NRAT 3.5137 II~D 116.4375 GR -99q.2500 NCNI.~ 92,0625 NRAT 3.3.43~ IbP 1!7,1~75 =999,2509 102.25(!0 3926 9 -99 -999 2500 2,289~ 78,6~50 -999,2500 -999,2500 5371 67, '75 '999, 00 -999,2500 2,6035 7t'7500 -999,2500 '999,2500 81,31 '999,2500 -999.2500 3,2285 92,3750 -999,2500 -999,2500 3 0039 112:5625 -099.2500 -999,2500 3,789! 93,1875 -999.2500 -999.2500 3 5723 113~8125 29999.2500 · 99,2500 ,EPT -PHI ,EPT -pHT 'CNL ,P PHl 'CN ~EPT ;P 3600,0000 SFI, U -37,~500 Gr~ -999 2500 [)PH[~ -999' .2500 CA[.I -9~g.2500 -ggg -999 -999 3 ~O0 36 519 3 000 0 $ F L U 2500 D R ~.{ [] 2500 CALl 2500 0OO0 312 5 G'R 000 C A L I 5~] 9S i~<PT ',.'].:]no, 0000 ;P -.40 o0000 IPHI 45,3125 "CNI, 488,2500 CALI ~-~R ~ 3.a672 ) E P T ~PHI PCNL :]200,00()0 ., 42.7500 GR 49,2187 424.0OO0 CALl 4. 3008 )~':pT 3100 0000 SFLU }P -53".2187 GR {PHI 41 259~ DRNO, ~C.k' L 507: 5O00 CALl 2900,0000 -45,9062 38 , 2~ 13 ,! 97 , 9.500 3,6621 ~P JPH! rCNI, ]P ~1 P H l 5,0000 llta 74.6250 DT -g99,2500 R[,IOB 11,781.3 GR 3,3848 .ILa ~6,5625 DT 0,0513 RHOR 12,1484 GR 3,~066 76. 250 DT 11. 266 GR 6.3906 IbM 76,8125 DT 0.0278 RHO)i 11,3203 G~ 14,6094 59.4063 UT 0 0151 10:164.1. GR 44.8125 ll_,~ 57. 8437 0 0005 }2:7266 fir 7.&719 73.1250 0.0234 12.0391 I,:1~ 34,77 4375 -999.2500 96,7500 4,2734 1:t4,4375 -999,2500 100;4375 5,51,95 . , 7,500 · ,2500 74,6~50 4,4570 i14,31.25 ,2207 ,5625 3,5'162 120,2500 2.1975 76,1.250 6,3867 14,4,5000 2.~.777 76.81.25 16.9{87 1~6.6250 2.0977 59.4063 41.~250 140.7500 2.0391 57.8437 7.6719 127.5000 2,2070 73,1250 1: I., D NRAT I !, D NRAT ILl) GR ,~ . ~,t C,. N 1., NRA. T I LD N C N [, NRAT N C N NRAT I bD G~ NRAT GR NCNL NRAT i GR N C bt L NRAT I t,, 1", P R A T 3 6035 9 B 3 7 $ 0 -999 ..2500 -999 2500 4,7227 '9.. ' 6875 .999 ,2500 ,2500 7~,$1 -999,25 0 999,2500 4,9141. 69,0000 1864,0000 3,3438 3,~926 76. 1889.0000 3.7969 6,~961 76, 875 1824.0000 4.0156 1.8,9375 59.1562 1893,0000 3,5137 49 5625 60' ,5938 1869,0000 3,8223 8.7500 73,8750 1821,0000 3,425~ LVP OlO,H02 VERIFICaTIO!'.! I.IST!NC; DEPT 2800 SP -46 NPHI 44 FCNt. 432 0000 SFLU 9375 GR 0430 DRHO 7500 fill 3320 DEPT 2700,0000 SFLTI SP -53,9375 GR NPHI 43,3105 DRHO FCNL 524,5000 CALI RNRa 3,7949 DEPT 2600 FCNL 434 RNRA 4 DEPT 2500 SP -59 NPH! 43 FCNL 35~ RNRA DEPT 2400 SP -62 NPH! 49 FCNL 3584 RNRA D~PT SP NPHI FCNL DEPT $P NPHI FCNL RNR~ D~PT NPHI ~CNL 0000 SFLU 8750 GR 4902 DRH{) 7500 CALI 2617 0000 SFLU 5938 GR 8477 DRHU 7500 CALX 382R 0000 SFL. U DRI-IO 250 CAt, I 66002 2300,0000 -50;6875 51,§1 ! 3 DRHD 3:36 ;:75:00 CA 4,2656 2.~00,0000 SFLU 38,1875 i~R: 8 1953 IbM 60:2187 DT 0,0063 RHOB li,1953 GR 13.4531 IL~~'~ 79,8750 DT 0 0073 RHOB 16.1562 II.,M 44,9375 DT T0,03~7 R~OB 1,1328 GR 1],453~. IbM 40,0938 DT ,0~64 12.8359 GR , q 1.2,~5~4 IbM 61,:4063 DT 1.4'632~ UR 6.5039 ,:96~7 DT 11'2734::: 2000 0 0 0 0 I L ~ RHO~ 9:6'09 ~R -999 2500 I'L~ ~5:0:0 GR 8,1484 128,0000 2.2051 60.2187 IbP GR NCNb NRAT 11,96~7 12.3,1250 2,2090 79.8750 NCNL ~,~R A.T 13 7031 137~2500 1,8721 44.9375 GR HCNL NRAT 13.3594 135,1250 2,0547 43,0938 ILD GR NCNb NRAT 14,2~22 136,3750 1.9'736 61"4063 ILD GR NCNb NRAT 6,8828 1311'62'50 GR ,,05~7 NCNL 61.9687 NRA? 2000 41 0000 GR N CNL '999,2500 '999,25 -999. 2500 NRAT PAGE 9,3516 59,6875 1875,0000 3,7246 12,6328 69.1250 1991,0000 ,6758 13 2969 48:8125 1854,0000 4,1914 14.8828 40,1250 1571,0000 ,7559 15,5391 55,~5'63 1670, 000 4,'0977 8,8047 63 ~)25 ,1.4 21,9844 39,218:7 1410,0000 4,152~ 2500 906:2 2500 2500 FIL~: TYP~ : NEXT WILE NAME : ********** EOF ********** P~C~F 1 0 ** TAPE TRAIbER ** SERVICE NAME :SgRVIC OATE :8)/06/27 ORIGIN ~0000 TAPE ~'A,~F :8333 CONTINUATION ~ 101 NEXT T~PE MANE : COM~EMTS :LIBRARY TAPF ** REEl, T~AILE~ SERVICE I~AMM DATE ORIGIN : REEL ~A~E CONTINUATION # NEXT ~EEL NAME COMMENTS :LIBRARY TAPE EOF
