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Home My WebLink About184-139MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2G-03 KUPARUK RIV UNIT 2G-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/12/2024 2G-03 50-029-21165-00-00 184-139-0 W SPT 5955 1841390 1500 2750 2750 2750 2750 120 120 120 120 4YRTST P Adam Earl 5/1/2024 4 year MIT-IA 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 2G-03 Inspection Date: Tubing OA Packer Depth 830 1810 1780 1780IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240501195823 BBL Pumped:0.9 BBL Returned:0.9 Wednesday, June 12, 2024 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Monday, May 11, 2020 S �) �� Zti� P.I. Supervisor SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2G-03 FROM: Guy Cook KUPARUK R1V UNIT 2G-03 Petroleum Inspector Src: Inspector Reviewed B--y�::-� P.I. Suprv�J'��` NON -CONFIDENTIAL Comm I Well Name KUPARUK RIV UNIT 2G-03 IInsp Num' mitGDC200508162725 Rel Insp Num: API Well Number 50-029-21165-00-00 Inspector Name: Guy Cook Permit Number: 184-139-0 Inspection Date: 5/8/2020 ' Monday, May 11, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2G-03Type Inj bV TVD 5955 Tubing 2185 - 2186 2185 2185 PTD - 1841390 Type Test SPT �TQSt - psi 1500 IA 375 3000 2945 2935 BBL Pumped: �� 2.5 .,BBL Returned: 2.4 OA 110 120 125 � 125-7 Interval � 4YRTST PIF— P -. - Notes: Testing performed with a Little Red Services pump truck and calibrated gauges. ✓ Monday, May 11, 2020 Page 1 of 1 S • Wallace. Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Friday,June 8, 2018 2:48 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 2G-Q3.fp Q 184-14 Suspect IA pressurization Attachments: KRU 2G-03 Schematic.pdf; KRU 2G-03 TIO Plot 90-day.docx Chris, Kuparuk injector 2G-03 (PTD 184-139) is showing signs of suspect IA pressurization. Initially,the IA experienced a pressure increase explained by the significant temperature change that accompanied a change of injection service an rate, but a recent IA pressure increase that occurred when the well appears stabilized is suspect. CPAI intends to monitor the well and send DHD to perform a diagnostic MITIA, packoff tests,and an IA DDT. Based on the results oft e diagnostics,we will update you with a plan forward. Attached are a schematic and 90-day TIO plot. Please let me kno if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED JUN 2 0 LU i 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 28,2016 TO: Jim Regg )� / P.I.Supervisor ice-lei 71.4,(c, SUBJECT: Mechanical Integrity Tests !! CONOCOPHILLIPS ALASKA INC 2G-03 FROM: Johnnie Hill KUPARUK RIV UNIT 2G-03 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry TYi2- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2G-03 API Well Number 50-029-21165-00-00 Inspector Name: Johnnie Hill Permit Number: 184-139-0 Inspection Date: 6/21/2016 Insp Num: mitJWH160626223855 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ---------Well 2G-03 Type Inj W"TVD 5955 - Tubing 2610 • 2610 - 2610 - 2610• PTD 1841390 Type Test;SPT Test psi 1500 • IA 420 1810 1750 - 1740 - Interval INITAL P/F P 't OA 95 100 - 100 100 • Notes: 1.lbbls diesel used - SCANNED NOV 2 22016 Tuesday,June 28,2016 Page 1 of 1 STATE OF ALASKA ' AKA OIL AND GAS CONSERVATION COMMSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations 1 Fracture Stimulate r Pull Tubing F Operations Shutdown Performed: Suspend E Perforate E Other Stimulate E Alter Casing E Change Approved Program E Plug for Redrill fl Perforate New Pool I Repair Well F Re-enter Susp Well E Other:install stack packer 17 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory E 184-139 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21165-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25656, KRU 2G-03 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 8644 feet Plugs(measured) None RECEIVED true vertical 6396 feet Junk(measured) None JUN 1 4 2016 Effective Depth measured 8448 feet Packer(measured) 7953,8059 ,OGCC true vertical 6245 feet (true vertical) 5880,5955 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 116 116. _ SURFACE 3202 9 5/8 3240 2748 PRODUCTION 8601 7 8637 6390 SCANNED OCT 31r Perforation depth: Measured depth: 8142-8160, 8250-8262, 8278-8312 True Vertical Depth: 6015-6028,6094-6104,6116-6141 Tubing(size,grade,MD,and TVD) 3.5, L-80, 8036 MD,6390 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER 4782 FHL RETRIEVABLE PACKER @ 7953 MD and 5880 ND, PACKER-CAMCO HYDRO SET PACKER @ 8059 MD and 5955 ND SSSV: NOINE 12.Stimulation or cement squeeze summary: Intervals treated(measured): None Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1660/125 1300/150 Subsequent to operation 0 0 2380 1400 2512 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development E Service F Stratigraphic Copies of Logs and Surveys Run fl 16.Well Status after work: Oil r Gas E WDSPL 1 Printed and Electronic Fracture Stimulation Data E GSTOR r WINJ F WAG 1- GINJ E SUSP fl SPLUG E 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: 316-241 Contact Sara Heskin (M94 .265-1027 Email Sara.Heskin(a�conocophillips.com Printed Name Sara Heskin Title Assoc. Wells Engineer Signature O '/ . . Phone:265-1027 Date [ I(r/ I 1!„ ``J\ 65 /`1 1 {`1 6�F V`71 �i /2 /l4 Form 10-404 Revised 5/2015 RBDMS �V IA lb 2016 Submit Original Only • • Operations Summary (with Timelog Depths) e .:" 2G-03 Vilitti C.onociorniiti 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 MKS) End,Depth(ftKB) 5/8/2016 5/8/2016 2.00 MIRU MOVE MOB P Disconnect satellite camp,pipe sheds, 0.0 0.0 08:00 10:00 rockwasher,boiler,motor complex and pit complexand stage on 1J pad 5/8/2016 5/8/2016 1.00 MIRU MOVE MOB P Move sub base off of 1J-107 and 0.0 0.0 10:00 11:00 stage on pad 5/8/2016 5/8/2016 5.00 MIRU MOVE MOB P Move satellite camp,rockwasher, 0.0 0.0 11:00 16:00 boiler,motor complex and mud pits to 2G pad and stage 5/8/2016 5/8/2016 4.75 MIRU MOVE MOB P Move sub base to 2G pad 0.0 0.0 16:00 20:45 5/8/2016 5/8/2016 0.75 MIRU MOVE MOB P Spot shop 0.0 0.0 20:45 21:30 5/8/2016 5/8/2016 1.50 MIRU MOVE MOB P Spot sub base 0.0 0.0 21:30 23:00 5/8/2016 5/9/2016 1.00 MIRU MOVE MOB P Lay mats and spot pits 0.0 0.0 23:00 00:00 5/9/2016 5/9/2016 1.00 MIRU MOVE MOB P Spot Pump,Motor and Boiler 0.0 0.0 00:00 01:00 complexes. Spot Rockwasher 5/9/2016 5/9/2016 1.00 MIRU MOVE MOB P Spot pipesheds. 0.0 0.0 01:00 02:00 5/9/2016 5/9/2016 5.00 MIRU MOVE RURD P Make up interconnects between 0.0 0.0 02:00 07:00 complexes.Complete Rig Acceptance Checklist. Spot enviro-vac and airheater. Accept rig at 07:00 hours 5/9/2016 5/9/2016 5/9/2016 5.00 MIRU MOVE RURD P Spot tiger tank and choke skid. R/U 0.0 0.0 07:00 12:00 hard lines to cellar and hook up to IA and tubing. Blow air through lines. Fill lines with water and pressure test to 1000 psi. Blow down lines to tiger tank. 5/9/2016 5/9/2016 1.00 MIRU MOVE WAIT T Wait on brine 0.0 0.0 12:00 13:00 5/9/2016 5/9/2016 1.50 MIRU WELCTL MPSP P Make up lubricator and test to 1000 0.0 0.0 13:00 14:30 psi. Pull BPV 5/9/2016 5/9/2016 0.50 MIRU WELCTL RURD P Rig down lubricator 0.0 0.0 14:30 15:00 5/9/2016 5/9/2016 1.75 MIRU WELCTL KLWL P Kill well by circulating 298 bbls 9.6 ppg 0.0 0.0 15:00 16:45 brine down tubing @ 3 bpm taking returns up the IA. FCP=400 psi 5/9/2016 5/9/2016 1.50 MIRU WELCTL OWFF P Shut in and observe well for flow. 0.0 0.0 16:45 18:15 Tubing pressure increased to 140 psi and IA pressure increased to 170 psi. 5/9/2016 5/9/2016 1.50 MIRU WELCTL KLWL P Kill well by circulating 283 bbl 9.6 ppg 0.0 0.0 18:15 19:45 brine down tubing @ 3 bpm taking returns up the IA. ICP=560 psi. FCP =425 psi. 5/9/2016 5/9/2016 1.75 MIRU WELCTL OWFF P Shut in and observed well for flow 0.0 0.0 19:45 21:30 while waiting for truck to haul off wellbore fluids. Well static(TP=0 psi/IA=0 psi) 5/9/2016 5/9/2016 0.50 MIRU WELCTL OTHR P Empty tiger tank 0.0 0.0 21:30 22:00 5/9/2016 5/9/2016 0.50 MIRU WELCTL CIRC P Reverse circulate 990 bbl 9.6 ppg 0.0 0.0 22:00 22:30 brine to clear tubing. 5/9/2016 5/9/2016 0.50 MIRU WELCTL OWFF P Shut in and observed well for flow. 0.0 0.0 22:30 23:00 Well static Page 1/6 Report Printed: 5/19/2016 •AltiV • Operations Summary (with Timelog Depths) 2G-03 Conocc.Whillips 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) 5/9/2016 5/9/2016 0.25 MIRU WHDBOP MPSP P Set Type"F"BPV with lubricator 0.0 0.0 23:00 23:15 5/9/2016 5/9/2016 0.25 MIRU WHDBOP PRTS P Pressure test BPV to 100 psi in 0.0 0.0 23:15 23:30 direction of flow for 10-minutes 5/9/2016 5/10/2016 0.50 MIRU WHDBOP OTHR P Rig down lines 0.0 0.0 23:30 00:00 5/10/2016 5/10/2016 1.50 MIRU WHDBOP NUND P PJSM-Bleed off control line pressure. 0.0 0.0 00:00 01:30 Nipple down tree. 5/10/2016 5/10/2016 0.25 MIRU WHDBOP NUND P Prep hanger.Verify lock screws run in. 0.0 0.0 01:30 01:45 Install test dart.Plug control line port. 5/10/2016 5/10/2016 1.50 MIRU WHDBOP NUND P Nipple up BOPE. 0.0 0.0 01:45 03:15 5/10/2016 5/10/2016 4.50 MIRU WHDBOP SVRG P PJSM-Perform BWM on BOPE. 0.0 0.0 03:15 07:45 Change out top seal on driller side lower pipe ram. 5/10/2016 5/10/2016 0.50 MIRU WHDBOP OTHR P Mobilize completion equipment to rig 0.0 0.0 07:45 08:15 floor. 5/10/2016 5/10/2016 0.50 MIRU WHDBOP SVRG P Service rig. 0.0 0.0 08:15 08:45 5/10/2016 5/10/2016 1.00 MIRU WHDBOP RURD T Change out 3 1/2"test joints.First test 0.0 0.0 08:45 09:45 joint had a collar above the donut. Changed out with a test joint without a collar.Sim-ops/Rebuild accumulator air pump. 5/10/2016 5/10/2016 2.75 MIRU WHDBOP RURD P Rig up to test BOPE with 3 1/2"donut 0.0 0.0 09:45 12:30 test joint.Perform dry run with test joint measuring component distances. Purge air from system. 5/10/2016 5/10/2016 0.75 MIRU WHDBOP RURD T Perform body test.Choke hose flange 0.0 0.0 12:30 13:15 and 13 5/8"x 7 1/16"DSA leaking. Retorque hose flange and DSA. 5/10/2016 5/10/2016 0.50 MIRU WHDBOP BOPE P Test BOPE w/3 1/2"test joint 0.0 0.0 13:15 13:45 250/3500 psi for 5 min each.Test#1: Top rams,CV 1,12,13,14 and manual kill valve 5/10/2016 5/10/2016 2.00 MIRU WHDBOP OWFF T Observe flow from inner annulus 0.0 0.0 13:45 15:45 valve. Install pressure gauge on annulus and monitor pressure. Pressure increased from 42 psi to 275 psi in 90 mins.Bleed off pressure to tiger tank. 5/10/2016 5/10/2016 3.50 MIRU WHDBOP BOPE P Test BOPE w/3 1/2"test joint to 0.0 0.0 15:45 19:15 250/3500 psi for 5 min each. #2: Upper IBOP,HCR kill,CV 9,&11.#3: Lower IBOP,CV 5,8&10. #4:Dart„ CV 4,6&7. #5:FOSV and CV 2. #6: HCR choke&4"kill line Demco valve, #7:Manual choke valve&HCR kill. #8:Annular preventer.#9:Lower pipe rams.#10:Blind rams and CV 3. Accumulator test:system pressure= 3000 psi,After closing=1800 psi,200 psi attained after 43 sec,full pressure attained after 179 sec,Five bottle nitrogen avg=2025 psi.Performed drawdown test on manual and hydraulic chokes.PVT and gas alarms tested. BOPE test witness waived by AOGCC Rep.Bob Noble. Page 2/6 Report Printed: 5/19/2016 .E � • • Operations Summary (with Timelog Depths) rpt-„ 2G-03 C€nocoPhillips Rig: DOYON 141 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code, Time P-T-X Operat+an (ftKB) Ertel Depth(itKB) 5/10/2016 5/10/2016 0.50 MIRU WHDBOP RURD P Rig down test equipment and blow 0.0 0.0 19:15 19:45 down lines. 5/10/2016 5/10/2016 0.50 MIRU WHDBOP MPSP P Pull test dart as per Vetco Grey Rep. 0.0 0.0 19:45 20:15 5/10/2016 5/10/2016 1.50 MIRU WHDBOP WAIT T Monitor well while waiting on 10.8 ppg 0.0 20:15 21:45 brine to arrive from 1B. SimOps: Work on MP2's and clean rig. 5/10/2016 5/10/2016 0.75 MIRU WHDBOP COND T Load the pits with 240 bbls of 10.8 ppg 21:45 22:30 brine. 5/10/2016 5/11/2016 1.50 MIRU WHDBOP WAIT T Wait for second load of 10.8 ppg brine 22:30 00:00 to arrive from 1 B. SimOps: Continue to work on MP2's and clean rig. 5/11/2016 5/11/2016 2.25 MIRU WHDBOP WAIT T Wait for second load of 10.8 ppg brine 0.0 0.0 00:00 02:15 to arrive from 1B.Bleed off pressure at 300 psi. SimOps: Continue to work on MP2's and clean rig. 5/11/2016 5/11/2016 2.50 MIRU WHDBOP KLWL T PJSM-Displace well from 9.6 ppg 0.0 0.0 02:15 04:45 brine to 10.8 ppg brine pumping down tubing taking returns up IA to open top kill tank. 1.5 bpm, 130 SPP.Hold 100 psi back pressure. 5/11/2016 5/11/2016 1.00 MIRU WHDBOP OTHR T Offload open top kill tank. 0.0 0.0 04:45 05:45 5/11/2016 5/11/2016 1.25 MIRU WHDBOP KLWL T Continue to displace well from 9.6 ppg 0.0 0.0 05:45 07:00 brine to 10.8 ppg brine pumping down tubing taking returns up IA to open top kill tank. 1.5 bpm, 130 SPP.Hold 100 psi back pressure. 5/11/2016 5/11/2016 1.00 MIRU WHDBOP OWFF T Monitor well.Static.Blow down lines 0.0 0.0 07:00 08:00 5/11/2016 5/11/2016 1.00 MIRU WHDBOP MPSP P Rig up T-bar.Verify 0 pressure below 0.0 0.0 08:00 09:00 BPV.Attempt to pull BPV. Not able to unseat BPV. 5/11/2016 5/11/2016 0.50 MIRU WHDBOP OTHR P Mobilize Weatherford tongs,slips and 0.0 0.0 09:00 09:30 elevators to rig floor. 5/11/2016 5/11/2016 1.25 MIRU WHDBOP MPSP T Make up 2 ea.5'and 10'lubricator 0.0 0.0 09:30 10:45 extensions for extra weight and pull BPV. 5/11/2016 5/11/2016 0.50 COMPZN RPCOMP PULL P Make up landing joint to hanger and 0.0 8,023.0 10:45 11:15 top drive to landing joint.BOLDS. Unseat hanger w/85K.Pick up 3'. 5/11/2016 5/11/2016 1.00 COMPZN RPCOMP CIRC P CBU.6 bpm,750 psi,36%FO 8,023.0 8,023.0 11:15 12:15 5/11/2016 5/11/2016 2.50 COMPZN RPCOMP PULL P PJSM-POOH laying down 3 1/2"EUE 8,023.0 6,222.0 12:15 14:45 8rd tubing,spooling up control line to 6222'MD. 5/11/2016 5/11/2016 0.50 COMPZN RPCOMP RURD P Lay down SSSV. Rig down control line 6,222.0 6,222.0 14:45 15:15 spooler and remove from rig floor. Page 3/6 Report Printed: 5/19/2016 . • Operations Summary (with Timelog Depths) thck 2G-03 ConocoPhiflips 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 MKS) End Depth(ftKB) 5/11/2016 5/11/2016 4.00 COMPZN RPCOMP PULL P Con't to POOH laying down 3 1/2" 6,222.0 0.0 15:15 19:15 EUE 8rd tubing f/6222'MD.Lay down total of 251 full jts tubing, 1 cut jt tubing.Recovered 33 steel bands and 1900'of stainless steel control line. Calc disp=25.2 bbls Act disp=28.9 bbls 5/11/2016 5/11/2016 0.75 COMPZN RPCOMP RURD P Clean and clear rig floor.Mobilize 0.0 0.0 19:15 20:00 hanger to rig floor. 5/11/2016 5/12/2016 4.00 COMPZN RPCOMP PUTB P PJSM-PU overshot,DS nipple, 1 jt 0.0 4,178.0 20:00 00:00 tubing,packer/PBR assy, 1 jt tubing and GLM as per detail.PU and RIH w/3 1/2", L-80,9.3#,8rd EUE-Mod tubing to 4178'MD. 5/12/2016 5/12/2016 3.75 COMPZN RPCOMP PUTB P PU and RIH w/3 1/2", L-80,9.3#,8rd 4,178.0 8,000.0 00:00 03:45 EUE-Mod tubing to 8000'MD as per detail.PU 86K SO 69K Calc disp=27.1 bbls Act disp=26.7 bbls. 5/12/2016 5/12/2016 2.00 COMPZN RPCOMP HOSO P Locate overshot on stump at 8027' 8,000.0 8,032.0 03:45 05:45 MD.Set down and observe bobble at 10K wt.Set down 15K.Unsure of shearout.Rig up circ line to tubing. Attempt to confirm pack off placement circulating with charge pump.No pressure increase observed.Pump with mud pump at 2 bpm, 125 psi. Observe 250 psi increase in pressure. Slack off to 8032'MD and locate No- Go. 5/12/2016 5/12/2016 0.75 COMPZN RPCOMP CRIH P PU to 8026'MD.Spot 10 bbls inhibited 8,032.0 8,026.0 05:45 06:30 10.8 ppg brine to cover area between packers 5/12/2016 5/12/2016 0.25 COMPZN RPCOMP PACK P PU to next tubing connection.Break 8,026.0 8,031.0 06:30 06:45 out connection and dropl.3"OD ball and rod.Make up connection and position packer at 7953'MD.Overshot at 8031'MD,one foot from fully located. 5/12/2016 5/12/2016 0.50 COMPZN RPCOMP PACK P Pressure up tubing to 2600 psi to set 8,031.0 8,031.0 06:45 07:15 packer.Allow to stabilize aty 2290 psi. Hold pressure for 10 min. 5/12/2016 5/12/2016 0.25 COMPZN RPCOMP PRTS P Maintain 2290 psi on tubing and test 8,031.0 8,031.0 07:15 07:30 casing to 3000 psi/10 min(charted) to verify packer is set. 5/12/2016 5/12/2016 1.25 COMPZN RPCOMP HOSO P Bleed off IA pressure and maintain tbg 8,031.0 7,926.0 07:30 08:45 pressure at 2290 psi.Pick up and shear seal assy from PBR.Sheared at 99k wt. Lay down jts#253,252 and 251.Mick up pup jt(6.20'),jt#251,x- o and hanger with pup jt. 5/12/2016 5/12/2016 1.25 COMPZN RPCOMP CRIH P Circulate 280 bbls inhibited 10.8 ppg 7,926.0 7,926.0 08:45 10:00 brine.5 bpm,575 psi,34%FO. 5/12/2016 5/12/2016 0.50 COMPZN RPCOMP THGR P Drain BOPE.Land tubing.RILDS.PU 7,926.0 7,945.0 10:00 10:30 86K SO 69K.Seal assy 7.37'from fully located. Page 4/6 Report Printed: 5/19/2016 0 • .,, xN- Operations Summary (with Timelog Depths) 2G-03 co occiPhiltmlps 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 (EKE) End Depth(itKB)', 5/12/2016 5/12/2016 4.25 COMPZN RPCOMP PRTS T Attempt to pressure test tubing. 7,945.0 7,945.0 10:30 14:45 Unable to test.Add additional block valve and attempt to retest. Unable to test.Verify surface equipment not leaking and attempt to test again. Unable to test.Suspect leaking SOV. 5/12/2016 5/12/2016 1.00 COMPZN RPCOMP SLKL T PJSM-Mobilize slick line tools to rig 7,945.0 7,945.0 14:45 15:45 floor 5/12/2016 5/12/2016 1.00 COMPZN RPCOMP WAIT T Wait on slick line tools. 7,945.0 7,945.0 15:45 16:45 5/12/2016 5/12/2016 1.25 COMPZN RPCOMP SLKL T Rig up slick line. 7,945.0 7,945.0 16:45 18:00 5/12/2016 5/12/2016 1.25 COMPZN RPCOMP SLKL T Run#1.Set junk catcher on top of ball 7,945.0 7,945.0 18:00 19:15 and rod. 5/12/2016 5/12/2016 1.00 COMPZN RPCOMP SLKL T Run#2.Change out tools and RIH 7,945.0 7,945.0 19:15 20:15 and pull SOV.Lower seals damaged and missing three upper seals on SOV. 5/12/2016 5/12/2016 1.50 COMPZN RPCOMP SLKL T Run #3.Change out tools and RIH 7,945.0 7,945.0 20:15 21:45 and set dummy valve. 5/12/2016 5/12/2016 0.75 COMPZN RPCOMP PRTS P Rig up and test tubing to 3500 psi/30 7,945.0 7,945.0 21:45 22:30 min(Charted).Test good. 5/12/2016 5/12/2016 0.75 COMPZN RPCOMP PRTS P Test IA to 3000 psi/30 min(Charted). 7,945.0 7,945.0 22:30 23:15 Test good.Rig down test equip. 5/12/2016 5/13/2016 0.75 COMPZN RPCOMP SLKL T Rig up slickline and RIH to pull dummy 7,945.0 7,945.0 23:15 00:00 valve. 5/13/2016 5/13/2016 0.50 COMPZN RPCOMP SLKL T Continue POOH with dummy valve on 0.0 0.0 00:00 00:30 slickline 5/13/2016 5/13/2016 0.50 COMPZN RPCOMP RURD T Rig down slickline and laydown 0.0 0.0 00:30 01:00 landing joint 5/13/2016 5/13/2016 0.50 COMPZN WHDBOP MPSP P Set BPV and test IA to 1000 psi for 10 0.0 0.0 01:00 01:30 to test BPV in direction of flow. Concurrently L/D tubing tongs and slips 5/13/2016 5/13/2016 0.75 COMPZN WHDBOP OTHR P Blow down top drive, Blow down 0.0 0.0 01:30 02:15 choke and kill lines and drain the BOPE stack 5/13/2016 5/13/2016 1.25 COMPZN WHDBOP NUND P N/D BOPE stack and set on stump 0.0 0.0 02:15 03:30 5/13/2016 5/13/2016 3.25 COMPZN WHDBOP NUND P Nippled up tubing adapter. Replaced 0.0 0.0 03:30 06:45 R-46 ring gasket between adapter and tubing head with RX-46 ring gasket to prevent adapter from bottoming out on the tubing hanger. Replaced RX-35 gasket between adapter and tree with R-35 gasket to allow full thread engagement on studs/nuts. Tested the tubing head adapter void to 5000 psi for 5 minutes 5/13/2016 5/13/2016 0.50 COMPZN WHDBOP MPSP T Attempted to pull BPV with dry-rod. 0.0 0.0 06:45 07:15 Unable to do so becaue of pressure under BPV 5/13/2016 5/13/2016 0.75 COMPZN WHDBOP MPSP P Make up lubricator and pull BPV. 0.0 0.0 07:15 08:00 Install TWC. TP=325 psi. 5/13/2016 5/13/2016 0.75 COMPZN WHDBOP PRTS P Fill tree with diesel and test to 250 0.0 0.0 08:00 08:45 psi/5000 psi. 5/13/2016 5/13/2016 0.25 COMPZN WHDBOP MPSP P Pull TWC 0.0 0.0 08:45 09:00 Page 5/6 Report Printed: 5/19/2016 • • :`,:, Operations Summary (with Timelog Depths) ct W, 2G-03 ConocoPhiilips 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(fEB)'. 5/13/2016 5/13/2016 0.75 COMPZN WHDBOP FRZP P R/U to freeze protect well 0.0 0.0 09:00 09:45 5/13/2016 5/13/2016 1.50 COMPZN WHDBOP FRZP 'P PJSM, LRS pump 76 bbl diesel down 0.0 0.0 09:45 11:15 IA taking returns up the tubing through the gas buster 5/13/2016 5/13/2016 0.75 COMPZN WHDBOP FRZP P Put IA and tubing in communication 0.0 0.0 11:15 12:00 and allow fluids to U-tube 5/13/2016 5/13/2016 1.25 COMPZN WHDBOP FRZP P Continue to allow fluids to U-tube. 0.0 0.0 12:00 13:15 5/13/2016 5/13/2016 0.50 COMPZN WHDBOP MPSP P Set BPV 0.0 13:15 13:45 5/13/2016 5/13/2016 1.25 DEMOB MOVE MOB P Secure well. TP=0 osi IA=0 psi,OA 0.0 13:45 15:00 =240 psi.Prepare rig to move to Shark tooth 2S-05 Page 6/6 Report Printed: 5/19/2016 KU 2G-03 ConocaPhillips Well Attrib Max AnglOVID TD Alaska Inc `' Wellbore API/UWI Field Name Wellbore Status ncl(3 MD(ftKB) Act Btm(ftKB) conocohhid/ps 500292116500 KUPARUK RIVER UNIT INJ 52.07 6,800.00 8,644.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 20-08 6/8120162.48.05 PM SSSV: NONE Last WO: 5/8/2016 34.98 8/18/1984 Vertical schematic(actuail......... Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,283.0 5/18/2016 Rev Reason:PULLED CATCHER,BALL/ROD, pproven 5/17/2016 RHC,CATCHER,RB-PLUG and TAG „r... _nu"uuuuuuxu.o.uur".wtu .i.t,uunr 1y HANGER;34.9 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 116.0 116.0 62.50 H-40 WELDED Casing Description OD(in) -ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I.. Grade Top Thread SURFACE 9 5/8 8.921 37.4 3,239.6 2,7482 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...'Grade Top Thread PRODUCTION 7 6.276 36.0 8,637.0 6,390.3 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING RWO 2016 3 1/2 2.992 34.9 8,031.4 5,935.2 9.30 L-80 EUE 8rd Mod 1 ; f Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Indy) Item Des Corn (in) 34.9 34.9 0.03 HANGER GE S-218 35 EUE 8rd tubing hanger.6.97 OD.3"H 2.992 BPVG 7,922.2 5,858.0 45.78 LOCATOR Baker Locator Sub 2.950 7,923.2 5,858.7 45.76 SEAL ASSY Baker 80-40 3.000 7,929.9 5,863.4 45.67 PBR Baker 80-40 PBR SHEARED 3.000 M CONDUCTOR;38.0-116.04.-4-"-^-Ak 1M--- 7,953.0 5,879.6 45.33 PACKER Baker 4782 FHL Retrievable Packer(60K shear ring) 2.930 8,006.5 5,917.5 44.58 NIPPLE Camco 2.813"DS Nipple SN:3651.25 2.813 8,024.1 5,930.0 44.39 OVERSHOT Baker Poorboy Overshot with Packing(6.36'Swallow 8 1' 3.590 up from fully located) Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft../Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection ORIGINAL 57/8 2.940 8,026.0 8,089.7 5,977.2 fI COMPLETION SURFACE;37.aa,2396-- l Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl('I Item Des Com (in) 8,041.2 5,942.3 44.21 PBR CAMCO OEJ PBR 2.940 if 8,059.0 5,955.0 44.02 PACKER CAMCO HYDRO SET RETRIEVABLE PACKER 2.870 GAS LIFT;7,885.3 8,077.5 5,968.4 43.82 NIPPLE CAMCO D NIPPLE 2.750 8,088.9 5,976.6 43.70 SOS CAMCO SHEAR OUT SUB,ELMD OF TTL 8099'- 2.960 3/4/2002 Perforations&Slots Shot Den Top(TVD) Btm(TVD) (shots) LOCATOR;7,922.2 • Top(ftKB) Btm(ORB) (ftKB) (MB) Zone Date ft) Type Cent 8,142.0 8,160.0 6,015.2 6,028.3 C-4,UNIT B, 3/4/2002 6.0 APERF 2.5"HSD PJ Chgs;60 2G-03 deg ph,random orient SEAL ASSY;7,9232 'nr:' 8,250.0 8,262.0 6,094.8 6,103.7 A-5,2G-03 9/18/1984 4.0 IPERF 4"Schlum.Casing;90 Ant�� deg.Phashing PBR;7,929.9 la tel 8,278.0 8,312.0 6,115.7 6,141.3 A-4,2G-03 9/18/1984 4.0 IPERF 4"Schlum.Casing;90 PACKER;7,953.0 deg.Phasing Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(0KB) (ftKB( Make Model OD(In) Sero Type Type (in) (psi) Run Date Corn 1 7,865.3 5,818.6 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/17/2016 Notes:General&Safety NIPPLE;8,008.5 End Date Annotation h''' 11/26/2001 NOTE:WAIVERED WELL: T x IA ANNULAR COMMUNICATION 10/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 OVERSHOT;8,024.1 PBR;8,041.2 -h- PACKER;8,059.0 NIPPLE,8077.5 SOS;8,088.9 � ` I APERF;8,142.08,160.0- $ T IPERF;8,250.08,262.0 i. IPERF;8,278A8,3120-:. PRODUCTION;38.0-8,637.0 ,OF ? • • .gam.-„I//��-6. THE STATE Alaska Oil and Gas M of Conservation Commission ,, ALASIc:A ;in 333 West Seventh Avenue '1% '. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ��h Main: 907.279.1433 OA., ,m+_ ALAS''' Fax: 907.276.7542 www.aogcc.alaska.gov Sara Heskin Associate Wells Engineer J. t. ConocoPhillips Alaska, Inc. �� ` `' P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-03 Permit to Drill Number: 184-139 Sundry Number: 316-241 Dear Ms. Heskin: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0,0a4e.,J2—...„ Cathy P. oerster Chair DATED thiso ay of April, 2016. RBDMS i,v APR 2 9 2016 • • RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 0 2016 APPLICATION FOR SUNDRY APPROVALS !K-S 41441(4, 20 AAC 25.280 AOGCC 1.Type of Request: Abandon H Plug Perforations❑ Fracture Stimulate H Repair Well RI Operations shutdownL Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing E• Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. • Exploratory ❑ Development ❑ 184-139 ' 3.Address: Stratigraphic ❑ Service ❑- 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-21165-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a ,/ KRU 2G-03 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025656 s Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8637' • 6396'• 0' 3020 8072' Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 116' 116' Surface 3196' 9.625" 3240' 2747' Intermediate Production 8601' 7" 8637' 6390' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8142'-8160' , 6015'-6028' 3.5" J-55 8089' 8250'-8262' . 6095'-6104' 8278'-8312' - 6116'-6141' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV: OTIS FMX-TR SAFETY VALVE(LOCKED OUT 7/13/1996) • MD=1898' TVD=1793' PACKER-aeaw 'COSi t 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑✓ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/2/2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG E, GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown H 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 Sara Heskin Email sara.heskin(c�conocophillips.com Printed Name Sara Heskin 907-331-7514 Title Associate Wells Engineer n Phone Signature ��(,1�/�,�it•�kL Date q( Q l I (pCOMMISSION USE ONLY / Conditions of approval: Notify Commission so that a representative may witness Sundry Number: t"--(�VIZ. � Plug Integrity ❑ BOP Test Mechanical Integrity Test Er Location Clearance ❑ Other: BOP tt5-71— Ye 35-00 `^J S t q Avf "ViarnrCvert )-rr 1-r -f fc, z50v Ps ��t,rC w, �hz5` 5,ee .tet cT-/A r-Td after S/4b;lip-Ci /ii << f1GY1 Post Initial Injection MIT Req'd? Yes No ❑ J Spacing Exception Required? Yes ❑ No R Subsequent Form Required: /Q - 4 04 RBDMS I,i, APR L c 2016 p APPROVED BY ,...U...4 Approved by: // COMMISSIONER {THE+COMMISSION Date: �6-1(_ 41 /2 /'- 7 Q I12.J//Co Submit Form and Form 10-403 Re ised 11/2015 O �°� r iNcAtvalid for 12 monthsfrom tie date of approval. Attachments in Duplicate v ('t llb • • ConocoPhillips Alaska COVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 PR 20 2016 April 19th,2016 Commissioner Cathy Foerster AO 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 workover Kuparuk Injector 2G-03 (PTD# 184-139). Well 2G-03 was drilled and completed in August of 1984 as a Kuparuk A-4&A-5 single completion producer. After well testing and fracture stimulation the well was produced for 13 months from October 1984 to November 1985.The well was then converted to an A-sand MWAG injector in 1985. The injector alternated between water and gas injection into the A-sand formations until April 1996 with a total gas injection of 2.8 BSCF. In April, 1996 the well was shut in due to TxIA communication while on gas injection and 2G-03 was waivered to water injection only in March of 1997. In 2002 the C-4 sand was perforated to pressure support offset producers and decrease injection into the A- Sand. The AOGCC approved temporary MWAG injection for diagnostic testing. This determined that TxIA communication still existed while on gas injection and the well returned to water injection only. Well 2G-03 failed two inner annulus draw down tests (IA-DDT) in May of 2010.The well tests were repeated with AOGCC witness.The inner and outer annulus mechanical integrity tests passed(MIT-OA&MIT-IA)as well as the IA-DDT.The AOGCC confirmed that the well was in compliance with the original administrative approval for continued water injection only. In 2011,2G-03 failed a MIT-IA and the well was shut in to present date. Diagnostic work performed indicates a tubing leak at an unknown depth. The proposed rig work-over will consist of pulling the existing tubing&reinstalling new upper completions, including a packer and polished bore receptacle.This will enable 2G-03 to return to normal MWAG status. This Sundry is intended to document the proposed work on KRU 2G-03 to pull tubing and repair the well and to request approval to workover 2G-03. If you have any questions or require any further information,please call me at 265-1027 or email me at sara.heskin@conocophillips.com. Sincerely, 3aAkk ljeA Sara Heskin Associate Wells Engineer CPAI Drilling and Wells • • • ConocoPhillips 2G-03 Proposed Workover Pull & Replace Tubing Original PTD: #184-139 General Well Information: Well Type: Kuparuk A& C-Sand Injector MPSP: 3,020 psi using 0.1 psi/ft gradient `✓ Reservoir Pressure/TVD: 6/26/14: 3,630 psi at 6,099'TVD Equivalent MW:11.5 ppg Wellhead Type: McEvoy/Gray Gen III 5K BOP Configuration: Annular/ Pipe Rams/ Blind Rams/ Mud Cross/Pipe Rams MIT Results: 7/2/2014: MIT-OA, Passed 2012: MIT-T& MIT-IA Passed, IA-DDT Failed 2011: MIT-IA Failed Earliest Start Date: 5/2/2016 Production Engineer: Sydney Autry Workover Engineer: Sara Heskin (907) 265-1027 sara.heskin@cop.com Current Well Status: Well 2G-03, a Kuparuk A-84C-sand injector, has been shut in since 2011 after failing a MIT-IA as a result of a tubing leak when on water injection. Scope of Work: The objective of this proposed RWO will be to return 2G-03 to injection by replacing the upper completion.The scope of this proposed RWO will be to fix the tubing leak by pulling the upper completion to the pre-rig tubing cut and installing new tubing. The current packer and PBR will remain down hole and a new 3-1/2" upper completion will be run from surface. A new retrievable packer and PBR will be set via a poor-boy overshot. Summary of Proposed RWO Procedure: Proposed Pre-Rig Work: 1. MIT-T& MIT-IA. If Tests fail, combined MIT-TxIA. 2. DDT-T& DDT-IA. If test fails, combined DDT-TxIA 3. Pull 1-Y2" DMY-RM from GLM #5 and leave open for circulation point 4. Cut 3-Y2" tubing at 8,026' MD 5. Lock out SSSV 6. Set BPV • • ConocoPhillips 2G-03 Proposed Workover Pull & Replace Tubing Original PTD: #184-139 Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. Pull BPV. Circulate KWF. Obtain SITP &SICP; if pressure is observed at surface, calculate new KWF and repeat circulation if necessary. Verify well is static prior to proceeding. 3. Set BPV, ND tree, set blanking plug, NU BOPE, &test BOPE to 250/3,500 psig low/high. 4. Pull blanking plug, pull BPV, screw in landing joint, BOLDS, & unseat tubing hanger. 5. P/U on tubing& pull tubing hanger to the rig floor. Verify well is static&TOH laying down 3-%2" upper completion to pre-rig tubing cut at 8,026' MD. 6. If casing conditions warrant, perform casing scraper run. 7. M/U &TIH with new 3-'/2" upper completion as per design to just above the tubing stub. 8. Spot corrosion inhibited brine in IA to just above the new FHL Packer. 9. Fully locate poor boy overshot and pick up 1'to space out. 10. Drop ball and rod and pressure up to set FHL Packer. 11. Pressure test IA to 3,000 psi for 5 minutes to verify packer is set properly. 12. Shear seal assembly from PBR, slack off to fully locate and space-out seals into existing PBR, mark-pipe at surface. 13. Lay-down two joints, space-out with tubing pups, M/U tubing hanger. 14. Spot corrosion inhibited brine in IA, land hanger, & LDS. 15. Pressure-test tubing to 3,500 psi & IA to 3,000 psi. Bleed the IA&then the tubing. Ramp up the IA pressure to quickly to shear the SOV. 16. Back-out landing joint& install BPV. 17. ND BOPE, install blanking plug, NU tree, & pressure test tree. 18. Remove blanking plug and BPV. 19. Freeze protect well through SOV. 20. Set BPV. 21. RDMO RWO Rig. Proposed Post-Rig Work: 1. Pull BPV. 2. Retrieve ball and rod. 3. RIH and set catcher on top of RHC Plug body in 2.813" DS Nipple 4. Run gas lift design &swap SOV for DV. 5. Retrieve catcher then retrieve RHC Plug body 6. Pull 2.75" CA-2 Plug 7. Reset well house(s) & re-attach flow line(s). 8. Turn well over to operations. • McEvoy/Grey Gen III • ^^_O 11"x 7-1/16"Tbg Spool L V s ConocoPhillips Kuparuk A&C-Sand Injector [_-- Current Status:Shut-In 16"62.5#H-40 WLD,116'MD-1► 1 ; 8089'MD,3-1/2"9.3#J-55 EUE-8RD Tbg Ca 4 1898'MD,Otis ID 2.81"FMX-TR SSSV Locked out 7/13/96 Mil 4 2063'MD,Camco 3'/z"x1"KBUG DMY 9-5/8"36#J-55 BTC,3240'MD ►4 s 11111-4 4221'MD,Camco 3'/s"x1"KBUG DMY MI 4 5839'MD,Camco 3-1/2"x1"KBUG DMY --41 7174'MD,Camco 3-1/2"x1"KBUG DMY 11110- 8003'MD, Camco 3-1/2"x1"KBUG DMY w„,_,...— G ut I� I�- 8041'MD,Camco 5-7/8"2.937"OEJ-10 PBR 'R I 2000 psi shear F e 8059'MD,Camco Hydro-Set 5.937"2.867"Retr. 11- ...„0__—Packer [11 8077'MD,Camco 4-1/2"2-3/4"D Landing Nipple 2-'/."CA-2 Plug Set 26-June-2014 f8089'MD,Camco 4'/z"2.937"Shear-Out Sub 3500 psi shear Kuparuk C-4 Perforations 2002-8142'-8160'MD 6/26/14 Last BHP Measurement: Kuparuk A-Sand Perforations 3630 psi at 8256'MD 1984-8250'-8262'MD 1984-8278'-8312'MD I I 7"26#J-55 BTM,8637'MD—T Date: 14-April-2016 1 Drawn By: Sara Heskin . *Please Note+/-5ft de screpancy. 3 KUP Reference current well epatic for depths 2G-03 • ConocoPhillips 01 Well Attributes Max Angle&MD TD AIBSka,Inc Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) cnroaSPhinips 500292116500 KUPARUK RIVER UNIT INJ 52.07 6,800.00 8,644.0 Comment H2S(ppm) Date Annotation [End Date KB-Grd(ft) Rig Release Date Well Con(P:-2G-03,7/10/201212:22:51 PM SSSV:LOCKED OUT Last WO: i 39.98 8/18/1984 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 8,135.0 4/22/2012 Rev Reason:WELL REVIEW osborl 7/10/2012 Casing Strings ---- ____- Casing Description String0... StringID...Top(ftKB) Set Depth 1...Set Depth ND...StringWt...Ston StringTopThrd MEM NW i 9 P P ( P ( ) 9 HANGER,30 CONDUCTOR 16 15.062 38.0 116.0 116.0 62.50 H-40 WELDED ? $ Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 9 5/8 8.921 37.4 3,239.6 2,747.4 36.00 J-55 BTC I Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 36.0 8,637.0 6,390.3 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(TVD)... String Wt...String...String Top Thrd TUBING 31/2 2.992 29.9 8,084.7 5,973.6 9.30 J-55 EUE8RD I Completion Details Top Depth (ND) Top Incl Nomi... Top(ftKS) (ftKB) (°) Item Description Comment ID(in) 29.9 29.9 0.04 HANGER MCEVOY TUBING HANGER 3.500 1,893.3 1,789.4 36.15 SAFETY VLV OTIS FMX-TR SAFETY VALVE(LOCKED OUT 7/13/1996) 2.810 CONDUCTOR, 8,036.2 5,938.9 44.25 PBR CAMCO OEJ PBR 2.940 38.116 8,054.0 5,951.6 44.06 PACKER CAMCO HYDRO SET RETRIEVABLE PACKER 2.870 ., 8,072.5 5964.8 43.87 NIPPLE CAMCO D NIPPLE 2.750 SAFETY VLV, 1,893 8,083.9 5,973.0 43.75 SOS CAMCO SHEAR OUT SUB,ELMD OF TTL 8099'-3/4/2002 2.960 Iii Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) GAS UFT. - 8,072.5 5,964.8 43.87 PLUG 2.75"CA-2 PLUG 4/22/2012 0.000 2,059 ME Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment 8,142.0 8,160.0 6,015.3 6,028.4 C-4,UNIT B, 3/4/2002 6.0 APERF 2.5"HSD PJ Chgs;60 deg ph, 2G-03 random orient 8,250.0 8,262.0 6,094.8 6,103.7 A-5,2G-03 9/18/1984 4.0 IPERF 4"Schlum.Casing;90 deg.Phashing 8,278.0 8,312.0 6,115.7 6,141.3 A-4,2G-03 9/18/1984 4.0 IPERF 4"Schlum.Casing;90 deg.Phasing . [ Notes:General&Safety SURFACE, End Date Annotation 37-3240 11/26/2001 NOTE:WAIVERED WELL:T x IA ANNULAR COMMUNICATION ir 10/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT, _ ---- 4,216 I GAS L,8IFT,35 5 1 GAS LIFT, 7,169 I GAS LIFT, 7,998 PBR,8,036 PACKER.8.054 II NIPPLE,8.072- PLUG,8,073 I 1 SOS,8,084 APERF. IIIIIIIIMI `'' 8,142-8.160 Top Depth Top I Port (ND) Incl Oo Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) 1') Make Model (in) Sere Type Type (in) (psi) Run Date Com... 1 2,058.8 1,917.0 42.63 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/17/1996 InjPkg 2 4,216.5 3,397.1 49.41 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/16/1996 InjPkg IPERF, 0.zso8,z6z 3 5,834.9 4,501.7 49.47 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/17/1996 InjPkg 4 7,169.5 5,351.6 50.21 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/17/1996 InjPkg 5 7,998.3 5,911.6 44.68 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/16/1996 InjPkg IPERF, 8,2758.312 PRODUCTION. 36-8637 TO,8,644 McEvoy/Gray Gen III 2G-03 411 IP." 11"x 7-1/16"Tbg Spool ConocoPhillips Kuparuk A & C-Sand Injector Proposed RWO 16" 62.5# H-40 WLD, 116' MD 7 3-1/2"9.3#L-80 EUE-8RM Tbg, 8026' MD 3-1/2"9.3#J-55 EUE-8RD Tbg, 8026'-8089' MD 9-5/8"36#J-55 BTC, 3240' MD --110-L -40--. 7870'MD, Camco 3-1/2"x1" KBUG SOV 111 7929'MD, Baker 80-40 PBR LI 1 �La2 7947' MD, Baker 7"x 3 1/2" FHL Retr. Packer �F i -R *No shallower than 7942'MD 2 41-Al- 8014' MD, Camco 2.813" DS Landing Nipple RHC Plug Body Installed 8026' MD—Pre-Rig Tubing Cut -411 8025' MD, Baker Poor-Boy Overshot Tubing Cut Performed Pre-Rig A , 8041' MD, Camco 5-7/8" 2.937" OEJ-10 PBR 2000 psi shear Ov y 1 8059' MD, Camco Hydro-Set 5.937" 2.867" Retr. Packer a -4111- 8072' MD, Camco 4-1/2" 2-3/4" D Landing Nipple 2-A"CA-2 Plug Set 26-June-2014 8089' MD,Camco 4-1/2"2.937" Shear-Out Sub 3500 psi shear Kuparuk C-4 Perforations '947" 2002—8142' -8160' MD Kuparuk A-Sand Perforations I 14111 6/26/14 Last BHP Measurement: 1984—8250' -8262' MD 3630 psi at 8256' MD 1984—8278' -8312' MD I I 7" 26#J-55 BTM, 8637' MD - Date: 14-April-2016 1 Drawn By: Sara Heskin Image Project Well History File' C( Page 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. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scann able) [] Other: NOTES: '[] Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Project Proofing BY: BEVERLY BREN Scanning Preparation BY: VINCENT SHERYL MARIA LOWELl. DATE: /SI BEVERLY BREN VINCENT X 30 = (~. +O~)--= TOTALPAGEs SHERY~ LOWELL. DATE:, i/7/4~ ~'~/S/ Production Scanning Stage '1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: X, YES NO BY: ~REN VINCENT SHERYL MARIA LOWELL DATE://~,/¢~.O~../S/ ~ Stage 2IF NO IN STAGE 1. PAGE(S) DISCREPANCIES WERE FOUND: YES NO ReScanned (individualpage[specialattention]scanning completed) III IIIII IIIII RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, November 09, 2010 3:39 PM To: 'NSK Problem Well Supv' Cc: Schwartz, Guy L (DOA) Subject: RE_ 2G- 034PT &48 430 .L cussion about AA amendment Brent and Martin, After speaking with Guy, I looked back into the history of this well and the IA communication. I think the key item here is that regardless of the mechanism, the well has communication to the IA. I don't believe the administrative approval requirements would change. It is my opinion that it is not necessary to revise AIO 213.014. Tom Maunder, PE � � NO V 1 0 2010 AOGCC From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Saturday, July 03, 2010 3:54 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2G -03 (PTD 184 -139) Discussion about AA amendment Tom, On 05/28/10, the compliance testing was completed on this well. The passing witnessed MITT, MITIA, and MITOA were performed and submitted to the Commission. The original AIO 28.014 was issued under the premise of an intermittent packer leak with similar passing tests. While preparing the well for the compliance testing, the MITIA failed with the well online, however once SI to set the TTP the MITIA passed but the IA DD test failed. The original assumption was this indicated a change in the mechanical condition and was reported as such. Upon further research, this was similar to the situation in the original AA justification that was submitted. The three passing MIT's would indicate 3 competent barriers, would an amendment to the AA be necessary? Currently the well is shut in, ConocoPhillips requests approval to continue water injection only under the original 2B.014. If an amendment is required, please let me know. 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 i Well Supv r 15, 2010 9:59 AM nas E (DOA)' ✓ell Supv (PTD 184 -139) Discussion about AA amendment Tom, As per our discussion, it would appear the mechanical condition of 2G -03 has changed. It is ConocoPhillips 11/9/2010 Page 2 of 2 intention to perform a witnessed MITT and MITIA on Monday 05/17/10. Following the results of the test, a request for an amendment to AIO 26.014 will be submitted. 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 11/9/2010 • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, June 14, 2010 11:08 AM ~ ~~j ~~7lto ~ [ ~_' To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: MITOA -KRU 2G-03 Jim, I apologize for the delay in the testing date. The delay was not intentional. ConocoPhillips understands the importance of the anniversary date and attempts were made in order to complete the testing prior to that date. However due to well conditions and weather conditions, the testing was delayed. Following is an outline of events for the well: 05104/10: Apre-witnessed MITIA failed. As per AIO 28.014, if the MITIA fails, a CMIT TxIA will be performed. 05/10/10: A CA-2 plug was set @ 8076'. A passing MITT was performed. 05/12/10: A passing diagnostic MITIA was performed, but the IA DD test failed. 05/13/10: A passing MITT and MITIA were performed, but the IA DD test failed again. 05/15/10: A phone call was made to Tom Maunder followed by an email explaining the circumstances. There were several days following that Kuparuk pads were in Phase 3 conditions due to blowing snow. There has been 30 weather days thus far for the Wells Group in which we were unable to work which is an usual amount. Correspondence was made daily with the North Slope inspector in attempts to complete the compliance testing. The original plan was to include the testing for this well when 1 C pad was tested and the compliance testing for 1A-04 was done on 05/21/& 05/22 once the weather had broke and the pads cleaned up. I assume there was a delay due to time constraints as to why that well was not completed with the others. Once again, I apologize for the delay in the testing date. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 '~~ ,'~~}""' .j`t~~ ~ ~ ~ ~~ Pager (907) 659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, June 09, 2010 3:36 PM To: NSK Problem Well Supv Subject: MITOA -KRU 2G-03 AIO 26.014 established anniversary date for MITs on KRU 2G-03 (PTD 1841390) as May 14; MITIA and MITOA were completed 5/28/10. Please make sure MITs are done on or before the anniversary date unless you have been granted a time extension from the Commission. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 6/17/2010 • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) ~~ ~ ` ~ ~ Sent: Wednesday, June 09, 2010 3:36 PM To: 'NSK Problem Well Supv' Subject: MITOA -KRU 2G-03 AIO 26.014 established anniversary date for MITs on KRU 2G-03 (PTD 1841390) as May 14; MITIA and MITOA were completed 5/28/10. Please make sure MITs are done on or before the anniversary date unless you have been granted a time extension from the Commission. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~3i{+1 ... i l ~-~ 6/9/2010 • MEMORANDUM TO: Jim Regg P.I. Supervisor ~ rf/9 ~/~/~O FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 03, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2G-03 KUPARIJK RIV lJNIT 2G-03 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV UNIT 2G-03 API Well Number: 50-029-21165-00-00 Inspector Name: Chuck Scheve mitCS100528133935 Insp Num: Permit Number: 184-139-0 Inspection Date: 5/28/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Welj 2G-03Type Inj. ~ T D ~ s9ss ~ IA 21ao 3000 ~ 296o z96o SPT 1841390 P.T.D TypeTest ' 1s00 ~' OA Test psi 0 0 0 0 Interval REQvAR p/Ii' P ~ Tubing ~ 1560 I 1660 I 1660 I66o j J -~ _ Notes: MITIA Thursday, June 03, 2010 Page 1 of 1 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission `~E~ ~ ~( DATE: Thursday, June 03, 2010 To: Jim Regg ~ 1 ~ ~. ~, D P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2G-03 FROM: Chuck Scheve KUPARUK RIV UNIT 2G-03 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~J~-°'r' Comm Well Name: KUPARUK RIV UNIT 2G-03 API Well Number: 50-029-21165-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS100528134201 Permit Number: 184-139-0 Inspection Date: 5/28/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We11~2G-o T ype Inj. N TVD~ - 5955 / IA 2080 2180 2200 2200 P.T.D 1841390 I L ~ TypeTCSt I SPT ~, Test psi L--~ lsoo QA ~ 0 1780 / 1700 - 1700 '- Tubing p/F P Interval REQvAR 1600 ~ 1600 1600 1600 ~ _ ___ Notes: MIT OA ~ ~.:J-O Z~.dl~k Thursday, June 03, 2010 Page 1 of 1 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, June 03, 2010 Toy Jim Regg '~ P.I. Supervisor ~~jCq +~~ (Ip SUBJECT: Mechanical Integrity Tests [ ( CONOCOPHILLIPS ALASKA INC 2G-03 FROM: Chuck Scheve KUPARUK RIV UNIT 2G-03 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I.Suprv~,J~~- Comm Well Name: KUPARUK RIV UNIT 2G-03 Insp Num: mitCS100528133414 Rel Insp Num: API Well Number: 50-029-21165-00-00 Permit Number: 184-139-0 Inspector Name: Chuck Scheve Inspection Date: 5/28/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zG-o3 Type Inj. N ';'TVD 5955 IA 2is0 2200 2200 2200 P.T.D 1841390 TypeTest~T ~ Test psi _ Isoo Op o o ~ 0 0 Interval REQvAR p~ r /Tubing Izoo 300o z9oo z9oo NOteS: MITT with plug set in tubing tail. /~'~' ~. ~~ 14 Thursday, June 03, 2010 Page 1 of 1 Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [nl617 @conocophillips.com] Sent: Monday, May 31, 2010 3:51 PM To: Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv Subject: 2G -03 (184 -139) AA Al 2B.014 Attachments: KRU 2G -03 05- 28- 10.xls Attached please find the variance required MIT Data for 2G -03 184 -139, A NO 213.014. Please let me know if you have any questions about the data. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 SLOW 11/9/2010 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; phoebe.brooks@alaska.gov; tom.maunder @akmka.gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: Kuparuk / KRU / 2G DATE: 05/28/10 OPERATOR REP: Ives / Mouser - AES AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. We112G -03 I T In'. I N TVD 5,955' Tubi 1,200 3,000 2,900 00 2,9 Interval V P.T.D.1841390 T test P Test i 1500 Casi 2,150 2,200 2,200 1 2,200 I P/FJ P Notes: MITT per AIO 26.014 OA O 0 p 0 CA -2 ug set 8076' Well2G -03 I Type In". I N TVD I 5,955 T f 1,560 1,660 1,660 1,660 Interval V P.T.D.1841390 1 Type test I P Test psil 1500 2,140 3,000 2,960 2,960 P/F P Notes: MITIA per AIO 26.014 OA 0 0 0 0 Well 2G-03 I Type In'. N TVD 1 5,955' T 1,600 1,600 1,600 1,600 Interval V P.T.D. 1841390 T test P Test . 1500 2,080 2,180 2,200 2,200 P/F P Notes: MITOA per AIO 26.014 OA 0 1780 1700 1700 WeIll I Type In'. TVD T Interval P.T.D. T tee Test P/F Notes: JOA Well Type In'. I TVD T Interval P.T.D. T test Test i Casi 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 Radioac ive 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 11127/07 KRU 2G -03 05- 28- 10.x1s WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 7, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2G -03 Run Date: 7/8/2009 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 2G -03 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 21165 -00 Injection Profile Log 1 1 Color Log 50- 029 21165 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 13 n l 6900 Arctic Blvd. Anchorage, Alaska 99518 1 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto halliburto corn .te t Date: NOV 0 5 2009 Signed: 31 ska Oil Gas Goim Cos!'r mis$k)i Iknchoregfi 2G -03 (PTD 1841390) State witnessed MITOA per AIO 2B.014 Page 1 of 3 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, June 03, 2008 3:13 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA); Cawvey, Von; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 213.014 Jim, I conducted a review of our waivered injectors and compiled the following list of wells with known TxIA communication that allow tubing and inner annulus pressure to equalize at greater than 2000 psi. Well Prod Casing Prod Casing IYP IA DNE MAOP MAOP %1YP AA # 2C -07 7" 26 ppf K-56 4980 3000 60°7 AIO 28.007 2G -03 7" 26 ppf J -55 4980 3000 60% AIO 28.014 3A-06 7" 26 ppf J -55 4980 3000 60% AIO 28.008 3A -11 7" 26 ppf J -66 4980 3000 60% AIO 28.022 3A -14 7" 26 ppf J -66 4980 3000 60% AIO 28.026 3H-09 7" 26 ppf J -66 4980 3000 60% AIO 28.009 3N -12 7" 26 ppf J -55 4980 3000 60% NA 3N -13 7" 26 ppf J -55 4980 3000 60% NA I also reviewed the history of 2G -03 and verified that in early December 2007 the IA pressure began increasing until ultimately equalizing with the tubing in mid - January 2008. This well has a known history of TxIA communication dating back to 1996 and it seems that this performance is consistent with the provisions in AIO 26.014 and the CPAI internal "Notice of Kuparuk Waivered Well" dated 08/13/06. As a result, CPAI has not performed any work to remediate the TxIA communication. The only wellwork done since the change in performance is an MITIA on 5/2/08 witnessed by John Crisp and an MITOA on 5/15/08 witnessed by Chuck Scheve. Please contact me at your convenience if you have any questions or comments... . Martin Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. NG'y Zulu Office 907 - 659 -7224 Cell 907 - 943 -1720 Pager 907 - 659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, May 30, 2008 4:41 PM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA) Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 213.014 I went back and reviewed a fairly extensive history on KRU 2G -03, including the previous sundry approval 397- 046 that was the precursor to AIO 213.014. The justification provided with the sundry waiver request refers to not exceeding 70% of the production casing minimum yield strength. 'V ' t p e x - 7 11/9/2010 2G -03 (PTD 1841390) State witnessed MITOA per AIO 2B.014 Page 2 of 3 0 0 The AIO 213.014 application (July 2006) makes reference to an approved MAOP without providing any specifics what the actual approved MAOP is. Can't tell from our files what we thought the approved MAOP was. Seems to me there may be some inconsistency in how annuli pressures are being handled, particularly in light of the additional restrictions /surveillance /safety devices imposed by the Commission on wells with relatively weak J55 production casing (published min yield strength is 4980 psi). The sundry waivers and admin approvals we have issued regarding injector integrity do not consistently specify a MAOP for the well - that may be something we need to adjust for future approvals to be clear about our expectations. CPAI's future applications for administrative approval should clearly identify the operating limits intended to be applied. You mention that there are other Kuparuk wells similar to 2G -03 where the tubing and IA are allowed to equalize up to the water header pressure with an upper bound - it would be helpful to have a list of the wells, and include what the annuli MAOP's are. Hopefully all are covered by existing admin approvals. KRU 2G -03 has an interesting pressure history (I have data only back to 2002). The significant pressure increase earlier this year is what surprises me the most after reviewing - has something changed in the well or has there been some decision by CPAI to manage the pressure differently? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Tuesday, May 27, 2008 10:40 AM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 213.014 Jim, CPAI was granted administrative approval to continue water injection in the 2G -03 well with know TxIA communication via AIO 213.014 on August 2, 2006. A subsequent CPAI internal Notice of Kuparuk Waivered Well was approved on August 18, 2006 that allows IA pressure to "equalize up to water header pressure, not to exceed 3000 psi ". The current water header pressure at DS2G is 2678 psi. 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 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, May 21, 2008 3:21 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) 11/9/2010 2G -03 (PTD 1841390) State witnessed MITOA per AIO 2B.014 Page 3 of 3 0 0 Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 IA pressure is 56% of MIYP for the well's 7" (J55, 26ppf) casing. I realize you just completed the MITIA earlier in May - curious why such a high pressure was left on the well. That certainly was not our intent in approving AIO 28.014. What is CPA[ using for a MAASP in the annuli of 2G -03? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com) Sent: Friday, May 16, 2008 11:00 AM 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: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 Tom, Jim, and Bob, Attached is the MIT test form for a variance required MITOA on 2G -03. This test is in addition to the witnessed MITIA that was performed on 05/02/08 for the required testing per AIO 2B.014. Please let me know if you have any questions. <<MIT KRU 2G -03 05- 15- 08.xls>> Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 i 11/9/2010 MEMORANDUM • TO: Jim Regg ~ ~l~J(J`v-' P.I. Supervisor ~~ FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 21, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2G-03 KUPARUK RIV UNIT 2G-03 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~i ~` Comm Well Name: KUPARUK RN UNIT 2G-03 API Well Number' S0-029-21165-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS08051814s042 Permit Number: 184-139-0 Inspection Date: 5~15~2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --- -- - --- Well zG-03 Type Inj. ~' TVD ~! s9ss IA j zsoo i zsso li zsso zsso zsso zsso -- a -- -- ----i- - - _ ~ ---- ~ - - - -- [841390 i - -- SPT - ~ - -- --=- ,TypeTest Test psi I zsoo /pA 600 ~ fs3o ~ n9o n4o nfo Info P.T Interyal_ R>;QVAR P/F _ P -- -- Tubing ~ _~6~s-- -~ --- - - - ~ --- -----L- 'z6~s z6~s z6~s NOteS: 2 Year MITOA P+~.zc Z ~, c; t 4 ~~~~' ~11L %`r c7 ZUIitJ Wednesday; May 21, 2008 Page l of 1 NTEMORANDUM To: Jim Regg ~2~ `~ ~ 13~~'v P.[. Supervisor FROM: Jam Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 07, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA P.VC 2G-03 KLJPARUK RIV UNIT ZG-03 Src: [nspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J ~'= Comm Well Name: KUPARUK RN UNIT 2G-03 Insp Num' mitJCr080504093522 ~~ Rel Insp Num: API Well Number: 50-029-21165-00-00 Inspector Name: John Crisp Permit Number: 184-139-0 Inspection Date: 5~2i2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I zG-os ~~T a In'. T~ s9ss '~ _- - - ~ -- yp ~ TVD IA I z6~o 3?zo 'j 3180 ~; s 160 ~ - --- - - 1841390 ~ p SPT------ .. -- -- - ~ _ _ P.T. ~ Ty eTest ~ ;Test psi 3200 pA 600 '~i 680 6ao 680 Interval REQvAR p/F P Tubing z6zs z6zs ' 26>> z6zs Notes' .6 bbl's pumped for test. T x IA comm. I~C~ ~? ~, ~ ~4 ~~~~ ~~~ ~ ~~ 20U Wednesday, May 07, 2008 Page L of 1 ~/H~~" 03/05/07 Schlumbel'geJ' NO. 4173 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth t1¡\rç ~'7001 SGANNED MAR 3 0 Z007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 (I- (}, Field: Kuparuk (J:I C- ( 15 '-{-/3~ Well Job# Log Description Color Date BL CD 2G-03 11638824 INJECTION PROFILE 02/15/07 1 1R-08 11628971 INJECTION PROFILE 02/15/07 1 1 F-17 11638827 SBHP SURVEY 02/17/07 1 1F-14 11638826 SBHP SURVEY 02/17107 1 1 F-19 11638828 SBHP SURVEY 02/19/07 1 1C-13 11628977 SBHP SURVEY 02/19107 1 1C-02 11628978 SBHP SURVEY 02/19/07 1 2M-02 11628979 INJECTION PROFILE 02/20/07 1 35-26 11638813 INJECTION PROFILE 01/21/07 1 1 C-121 11665391 INJECTION PROFILE 02/05/07 1 1 J-180 11665390 USIT 02/06/07 1 3J-14 11638825 PROD PROFILE 02/16/07 1 1J-118 11665392 USIT 02/22/07 1 1 D-11 11665393 INJECTION PROFILE 02/24/07 1 2M-05 11665400 INJECTION PROFILE 03/01/07 1 2M-04 11665399 INJECTION PROFILE 03/01/07 1 1F-13 11665401 INJECTION PROFILE 03/02/07 1 I Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Ils) . . ~Fts7~lx fd. ~URKO~JSxl, GO?1ERA}OR YHA 333 W. T"AVENUE, SUITE ?OC ~~~~~~~~~®~ ~® ~~~®~ ANCHORAGE. ALASKA 9950' -3539 SHONE (907) 279-?433 EAX x907) 275-7542 :~D.~~I~fISTIZ~TI~'E APPIZ~~'AL. ~®.:~I® 2~.0><~ ~Ir..terrv Dethlefs Problem Nell Supervisor ConocoPhiiiips Alaska, Inc. P.O Box 100360 anchorage, AI< 99~ 10-0360 KE: KRli 2G-03 (PTD l8~-i39j Request for Administrative Approval Dear L~Ir. Dethlefs: ~r`~ ~~ 3~~ ~ 2~~~ On July, 2006 GonocoPhiilips Alaska, Inc ("CPAI"} requested an administrative approval under Rule 9 of Area Injection Order ~':=CIO" 2B to allow continued water injection in service well Kuparuk River L`nit (~`KRU"} 2G-03. The :-Alaska Oi! and Gas Conservation Commission ("Commission"} GRANTS CPAI's request for w~ATER OL L Y' service, as detailed below. 2G-G3 was originally reported to have minor tubing x inner annulus ("T x IA"} pressure communication in 1996. CPAI obtained a Sundry Approval (39?-046} to allow the wets to remain in water only service. Diagnostic testing determined that the IA pressure communication is likely- due to an intermittent teak at the packer. when the welt is operating, pressure induced forces within the tubing are sufficient to affect integrity at the packer; hoGVever when injection is stopped the absence of the pressure induced forces allows T x IA communication. CPaI has elected not to perform corrective action on ZG-03 to restore full integrity. The Commission tends that, based upon reported results of CPAI diagnostic procedures, 2G- 03 exhibits a minimum of two competent barriers to the release of well pressure. .-~ccordingiy, the Commission believes that the web's condition does not compromise overall well integrity and will not result in an increased risk of movement of fluids outside the injection zone. Where freshwater is not affected, 20 AAC 2.450 gi~~es the Commission authority to approve less stringent ~t--ell integrity and operation requirements. ~fJt~tt~±[STRATI~"E .~PPR~L aI0 NO ZB OIL august 2, ?006 Page 2 of 2 Per Mule 9 of AIO 2B, the Commission hereby grants CPAI's request for administrati~~e approval to continue water injection in KRL 2G-0~ on the following conditions: 1. Injection is limited to ~~'ATER OtiLY; ?. CPAI shall monitor and record tubing, inner annulus and outer annulus (T IiO1 pressures and injection rate daily; ;. CPAI shall submit to the Commission admo~~h~y report of well pressures and zn~ection rates including any pressure b1e -~. CPAI shall perform a standard y;Iechanical Integrity Test of the Inner Annulus ti1IT-IA") every tw-o years. If the ~IIT-IA fails, a Combined Mechanical ("~ Integrity Test (Cti1IT) of the tubing and inner annulus (T x IA} will be performe ; ~. 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 he required to restart injection. $. The ~1IT anniversary date is Llay 1-I, 2006. As provided in AS 31.0x.080, within 20 days after w7itten 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 applicarion 4oron hhe Zt'rd d y folgiow' ngothe date ofghis considered timely if it is received by ~:~0 P~ I 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. DONE at 9 ict~orage, Alaska and dated August 2, 2006. I'he Alaska Oi[ and Gas Conservation Commission r ~ ~/:~ Jo o an Daniel T. Seamount, 3r. Cathy ~'. Foerster Commissioner Comr~iissioner ai ~ r_ 1 ~ a, ~ ~ ~._ ~t ~~ ~ ~ ~~ ~`~~ , ~~ 7 ~~~ \ i h j .~. 1 t ~ . c, ,, J . ~ 9-d Maunder, Thomas E (DOA) From: Thomas Maunder [tom maunder @ad min. state.ak. us] Sent: Wednesday, July 12, 2006 1:46 PM To: 'NSK Problem Well Supv'; 'NSK Well Integrity Prof Subject: Re: Phillips Kuparuk well 2G -03 Lets try that again. Thomas Maunder wrote, On 7/12/2006 1:45 PM: • Problem Wells People, • I have received the AA application for 2G -03. Here is the last email • I have on the well. It appears that the well leak MI but not water. • Is that correct? • I note that the well has not injected since about the time this • message was exchanged. Does the IA pressurize when injecting water? • Thanks in advance. • Tom Maunder, PE • AOGCC > Tom Maunder wrote, On 6/27/2002 11:16 AM: >> Jerry, >> Thanks for the information. I was looking at your plot and would >> appreciate a call with a little help to figure it out. I noted the >> legend, but I haven't been able to reconcile it all. You plan to >> return to water only is appropriate. Looking forward to speaking >> with you. >> Tom » r� » f�+Y NSK Problem Well Supv wrote: e1 � NOV >>> Tom: We hit the end of our approval period for MI injection and are >>> returning this well to water injection. The well did just fine the >>> first couple weeks, then the IA required bleeding a couple times. >>> There is an extremely small leak so we will try to figure out what >>> we want to do with it. Attached is a trend plot of the pressures. We >>> will get back with you on this if we want to follow -up on gas >>> injection. >>> Jerry Dethlefs >>> Phillips Problem Well Supervisor(See attached file: 2G -03 Trend >>> plot.gif) >>> - - - -- Forwarded by NSK Problem Well Supv /PPCO on 06/24/2002 04:01 PM >>> - - - -- >>> Tom Maunder <tom_maunder @admin.state.ak.us> >>> 05/23/2002 12:05 PM >>> To: NSK Problem Well Supv /PPCO @Phillips >>> cc: Jim Regg <jim regg @admin.state.ak.us> >>> Subject: Re: Phillips Kuparuk well 2G -03 >>> Jerry, >>> You are seeking approval to begin MI injection for diagnostic purposes. >>> You >>> propose this diagnostic period to not exceed 30 days. You indicate >>> that the well has passed a normal MIT in september 2000 as well as a >>> more recent MIT to 3200 psi and that the wellhead packoffs have 1 >>> demonstrated integrity. 0 • >>> By copy of this email, you plan to begin MI injection for diagnostic >>> purposes is approved. Please keep us informed how the well >>> performs. I would appreciate some information about 10 days or so >>> after the conversion is done. >>> Good luck with your work. >>> Tom Maunder, PE >>> AOGCC >>> NSK Problem Well Supv wrote: »» Tom: Kuparuk well 2G -03 (PTD 1841390) is a well that Engineering »» would >>> like »» repaired and put back on MI injection (Sundry #397 -046). Recently »» we have performed packoff tests that passed and a 3200 psi MITIA »» that passed. We did not see any indications during the MIT of »» leaking off. It also passed its last regular MIT on 9/14/00. I »» would like to put this well back on >>> gas »» for a temporary period to see if it still shows indications of »» communication. If there is any it is extremely small and low rate. »» We should know in a matter of a few days whether it will behave or »» not. The following is what I am planning: »» 1. Temporary MI injection approval, not to exceed 30 days; 2. »» Return to water -only injection if there are indications of T x IA »» communication; 3. Submit a 10 -403 for return to WAG service should »» no problems be >>> evident. »» We should be able to get this on MI over the next week or so. Drop »» me a line when you get a chance. Thanks! »» Jerry Dethlefs »» Phillips Problem Well Supervisor >>> (See attached file: tom_maunder.vcf) >>> -------------------------------------------------------------------- >>> - - -- >>> Name: 2G -03 Trend plot.gif >>> 2G -03 Trend plot.gif Type: GIF Image (image /gif) >>> Encoding: base64 2 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg 12{/(!t{; ~(T3ID4 P.I. Supervisor . DATE: Monday, May 22, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2G-03 KUPARUK RIV UNIT 2G-03 Src: Inspector / \-:?J q \ct0( FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIY UNIT 2G-03 API Well Number 50-029-21165-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060515070510 Permit Number: 184-139-0 Inspection Date: 5/14/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ¡ 2G-03 IType Inj. : N ¡ TVD 5955 : IA I 950 ¡ 3070 , 3020 : 3020 I i I -+------- I ¡ I ,! -I , -- P.T. 1841390 ITypeTest I SPT I Test psi 1500 OA 200 460 I 460 460 ¡ I _..... I I I i i --r i Interval REQVAR PIF P Tubing i 2200 i 2200 2200 I 2200 I Notes This Well has a waiver for Tubing x IA comunication with an allowable IA operating pressure of3000 psi. The waiver fonn indicates a required test pressure of 2500 psi. i/ Ik-'{·· " lAiLl.. V-{¡- :!l 3c7 '\4 . ~rCC - . ( -() I..p I NON-CONFIDENTIAL Reviewed By: -,...,-:;>jZ- P.I. Suprv. \ .f:> Comm c-'" ' (:< innS ~ANN~r .jU1J ~ v ~"" Monday, May 22, 2006 Page 1 of I PH,LLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 April 23, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2G-03 (184-139) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the KRU well 2G-03. If there are any questions, please contact me at 263-4574. Sincerely, Wells Team Leader Phillips Drilling MM/skad RECEIVED ' Anchorage ORI®ii1AL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _XX Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ . RKB 139 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 4730' FNL, 43' FEL, Sec. 31, T11 N, R9E , UM (asp's 508650, 5944135) 2G-03 At top of productive interval 9. Permit number / approval number 1170' FNL, 3620' FEL, Sec. 31, T11 N, R9E, UM 184-139 ! At effective depth 10. APl number 50-029-21165 At total depth 11. Field / Pool 945' FNL, 3842' FEL, Sec. 31, T11N, R9E, UM (asp's 504832, 5947918) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8644 feet Plugs (measured) true vertical 6396 feet Effective depth: measured 8440 feet Junk (measured) true vertical 6239 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 1 16' 16" 240 sx cs, 1 16' 1 16' SUR. CASING 3101' 9-5/8" 900 sx PF E, 370 sx PFC 3240' 2748' PROD. CASING 8498' 7" 380 sx Class G, 258 sx PFC 8637' 6390' Perforation depth: measured 8142' - 8160', 8250' - 8262', 8278' - 8312' true vertical 6015'-6028',6095'-6104',6116'-6141' ~ ~"'/ I.~ ~'~ Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 8090' MD. ~l~l.,~k~. 0i) & Gas (;otIs. ~,nchom0e Packers & SSSV (type & measured depth) CAMCO HYD SET RETR @ 8059' MD. OTIS FMX-TR @ 1898' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or I niection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Injector - Subsequent to operation Injector 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended _ Service _Water Injector XX 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Signed ~ /~//u(,~ Title: Wells Team Leader Date :/~"~/~--.-~ Michael Mooney Prepared b~/ S~aron AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2G-03 Event History O3/03/02 0~0~02 TAGGED @ 8440' RKB, EST. 128' RATHOLE. DRIFTED W/2.65" X 22' DUMMY GUN TO 8200' WLM. [TAG] PERFORATED C-4 SAND INTERVAL 8142' - 8160' W/2-1/2" HSD, PJ CHGS, 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. WHTP FELL FROM 2050 PSI TO 1900 WHEN SHOT. PRIOR TO SHOT TBG & FLOWLINE WERE FREEZE PROTECTED W/50 BBLS OF DIESEL. [PERF] Page 1 of I 4/23/2002 2G-03 Subject: 2G-03 Date: Tue, 5 Oct 1999 07:23:27 -0900 From: "Beck&Zuspan" <N1052~mail.aai.arco.com> To: lori taylor@admin.state.ak.us Good morning Lori, ~ ~. I ~5 ~ When you have time would you look to see if there is a sundry filed for Kupamk well 2G~03. Our records indicate it's on a 2 yr MIT schedule per sundry but we don't have a signed copy of the sundry on file - only a draft. The 2 yr MIT would have been a Commision requirement. Thank you. Sincerely, Mike Beck ARCO Wells Group 276-1215 x7285 or fax (907) 659-7314 1 of 1 10/5/1999 7:26 AM SENT BY :ARCO ALASKA ; 5- 1-BB ; 3:$2PM ; KPS/WF_LLS/CNST/PROJ-+- ARCO Alaska, Inc, Kupamk Operations Post Office Box 196105 ,Anchorage, Alaska 99,519-6105 2G4)3 Monitoring Report 0 ~ CHOKIa N A OR DATE E T % <:JO',' 2'/6 '/o42;# 6/ § SI DATA GAS WATER GAS C 7" 10" LIFT INJ INJ H M O AMB CSG CSO VOL VOL VOL R I D FTP FTT TEMP PSI PSI ~SCF BBLS Mi~SCF S N B 04/01 A PW 100 2840 120 -21 2850W 750 0 0 0.000 0000 0 04/02 A PW 100 2850 123 -13 2850W 750 04/03 A PW 100 2855 124 -8 2850W 750 04/04 A PW 100 2858 123 -11 2850W 150 04/05 A PW 100 2781 114 -9 2600W 550 04/06 A PW 100 2805 105 -4 2600W 550 0 0 0.000 0000 0 0 0 0,000 0000 0 0 0 0,000 0000 0 0 66 0,000 0000 0 0 611 0.000 0000 0 04/07 A PW 100 2817 124 2 2600W 550 04/08 A ~W 100 2834 127 1 2600W 550 04/09 A ~ 100 2842 127 -5 2600W 550 04/10 A PW 100 2849 123 -9 3600W 550 04/11 A PW 100 2043 124 -8 3850W 800 0 604 0.000 0000 0 0 643 0.000 0000 0 0 662 0.000 0000 0 0 689 0.000 0000 0 0 651 0.000 0000 0 04/12 A PW 100 2850 127 -10 2850W 800 04/13 A PW 100 ~857 1.25 -16 2850W 800 04/14 A PW ~00 2863 125 -13 2850W 800 04/15 A ~ 100 2856 123 -6 2850W 800 04/16 A PW 100 2844 125 2 2850W 800 690 0.000 0000 0 718 0.000 0000 761 0.000 0000 0 705 0,000 0000 0 681 0.000 0000 0 04/17 A PW 100 2854 128 6 2850W 800 04/18 A PW 100 2845 130 11 2850W 800 04/19 A PW 100 2840 119 8 2850W 800 04/20 A PW 100 2837 109 8 2850W 800 04/21 A PW 100 2845 125 3 2850W 800 0 716 0,000 0000 O 0 625 0,000 0000 0 0 701 0.000 0000 0 0 721 0,000 0000 0 0 688 0.000 0000 0 04/22 A PW 100 2853 127 -6 2850W 800 04/23 A PW 100 2857 123 -4 2850W 800 04/24 A PW 100 2863 127 -7 2850W 800 04/25 A PW 100 2863 129 -5 2850w 800 04/26 A PW 100 2871 129 -6 2900W 850 0 711 0.000 0000 0 0 730 0.000 0000 0 0 743 0.000 0000 0 0 738 0.000 0000 0 0 771 0,000 0000 0 04/27 A PW 100 2875 129 -4 2900W 850 04/28 A PW 100 2870 130 0 ~900W 850 04/29 A PW 100 2862 130 3 2750W 850 04/30 A PW 100 2809 1.33 19 2750W 850 ARCO Alae, ka. Inc. SCANNED DEC 1 9 2002 0 778 0.000 0000 0 0 743 0.000 0000 0 0 704 0.000 0000 0 0 493 0.000 0000 0 , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing __ Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address Suspend__ Operation Shutdown Repair well Re-enter suspended well __ Plugging __ Pull tubing __ 5. Type of Well: Development X Exploratory __ Stratigraphic __ P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 547' FSL, 44' FEL, SEC. 31, T11N, R9E, UM At top of productive interval 1170' FNL, 3620' FEL, SEC.-31, T11N, R9E, UM At effective depth 945' FNL, 3859' FWL, SEC. 31, T11N, R9E, UM At total depth 945' FNL, 3859' FEL, SEC. 31, T11N, R9E, UM Time extension Stimulate Variance X Perforate Other 6. Datum elevation (DF or KB) 139' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2G-03 9. Permit number 84-139 10. APl number 50-029-21165 11. Field/Pool Kuparuk River Field 'Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8644 true vertical 6394' Effective depth: measured 8448' true vertical 6245' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 116' 16" 3240' 9 5/8" 8637' 7" measured 8250'-8262', 8278'-8312' true vertical 6095'-6104', 6116'-6141' Tubing (size, grade, and measured depth) 3 1/2" 9.3 LB/FT, J-55, 8090' MD Packers and SSSV (type and measured depth) feet feet feet feet Plugs (measured) Junk (measured) ORIGINAL Cemented Measured depth True vertical depth 240 SX CS II 116 ' 900 SX PF CLASS E & 3240' 370 SX PF CLASS C 380 SX CLASS "C" & 8637' 258 SX PF CLASS C 116' 2746' - . 63.90' 0 7 1997 AJ~ska 0~1 & Gas Cons. Commission PACKER: CAMCO HRDP @ 8059, SSSV: OTIS FMX-TR @ 1898' 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch __ VARIANCE TO CONTINUE INJECTION 14. Estimated date for commencing operation 15. Status of well classification as: Gas 16. If proposal was verbally approved Name of a~rover . Date approved Service WAG Injector 17. I hereb¢~e¢ify that the~,~ is true and correct to the best of my knowledge. Signed//~. _/,~ .~?~_,, ./_/¢_///!_~_4.,)~,=z)/~/~ Title Wells Superintendent , FOR COMMISSION USE ONLY Suspended Date Condition.~/of approval: Notify Commission so representative may witness IApproval_No. _ ./ . 'Plug integrity BOP Test Location clearance I Mechanical Integrity Test 2 ~-~,~r.~f~Subsequent form require 10- Approved by order of the Commission David W. UohilJstor! Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT[N TRIPLICATE Approved Copy Returned "t Attachment 1 Request for Variance Kuparuk Well 2G-03 As per Area Injection Order No. 2, Rule 7, ARCO Alaska is hereby notifying the Commission of pressure communication between the tubing and casing in KRU Injection Well 2G-03. As set forth in the Rule 7, ARCO Alaska is requesting Commission approval to continue water injection into this well. As found in Area Injection Order No. 2, the aquifers described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit are exempted for Class II injection activities by 40 CFR 147.102(b) (3) and 20 AAC 25.440(c). As such, continued injection will not endanger any Underground Source of Drinking Water (USDW). In March 1996, the production casing pressure suggested that there was communication with the tubing. The tubing hanger was subsequently pressure tested to 3000 psi on 4/17/96 as described in the attached WSR. The well was shut-in on 4/29/96. Between 4/30/96 and 7/16/96, nine slickline days were spend changing out the DVs in all five gaslift mandrels. Pressure testing indicated that the leak was still present. On 9/27/96 a plug was set in the tailpipe and a simultaneous pressure test of the tubing and production casing to 3400 psi was performed to ensure packer integrity ' (see attached WSR). The pressure testing also indicated that the leak was no longer present and the well was returned to injection on 10/18/96. The Drillsite 2F injection service had been changed to produced water which is substantially warmer than the seawater injection service that the well was on when the communication was first noted. It was thought that the increased injection temperature would seal the DV packing better, however, the communication still persisted. On 11/11/96 the well was shut-in. The source of the communication is thought to be the SBR seals at 8041' RKB. The seals appear to hold in static conditions, but fail in the dynamic conditions of fluctuating operating pressures and temperatures causing tubing movement. On 11/17/96 a plug was set in the tailpipe and the production casing was displaced with 58 BBL of diesel and 153 BBL of 9.9 ppg brine. The tubing and casing were subsequently pressure tested to 2850 psi and 1850 psi respectfully. The pressure test was witnessed by AOGCC representative Chuck Scheve. This test demonstrates that there are no external casing leaks in this injection well and that injection fluids are confined to the Kuparuk River Sands. ARCO Alaska Inc. requests that the simultaneous tubing and casing pressure test performed on 11/17/96 satisfy the 1996 MIT requirement for Well 2G-03. Additionally, an alternative MIT consisting of a simultaneous pressure test of the tubing and casing is requested for subsequent MITs as dictated by the Commission. The well will also be placed on a water injection only status. Casing and tubing pressures will continue to be monitored and reported as per Area Injection Order No. 2, Rule 4 to ensure that the casing pressure does not exceed 70% of the casing's minimum yield strength. ARCO Alaska, Inc. KUPARUK RIVER UNIT ---- WELL SERVICE REPORT ~ K1(2G-03(W4-6)) w,u ,o. soo,. ,o. 2G-03 WELL HEAD MAINT: TEST, REPAIR 0421962316.7 WOrk 04/17/96 TBG HANGER TEST DAY OPERATION COMPL~E I SUCCESSFUL KEY PERSON SUPERVISOR I ~ Yes O NoI ~ Yes O No APO GOLDEN FIELD AF~ C~ DAILY COST ACCUM COST Signed ESTIMATE $ 0 Initial Tb~ Press Final Tba Press Initial inner Ann Final inner Ann ~ Initial Outer Ann ~ Final Outer Ann 2710 PSI 2710 PSI 3250 PSI 3250 PSI~ 325 PSI~ 325 PSI DAILY SUMMARY PRESSURE TESTED TBG HANGER TO 3000 PSI - PASS. TORQUED LOCK DOWN SCREWS TO 600 FI'-LBS. BLED VOID AREA. REPLACED TEST PORT FITI'ING. TIME LOG ENTRY SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL TOTAL FIELD ESTIMATE $0.00 $0.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT A WELL SERVICE REPORT Kl(2G-03(W4-6)) El ]. JOB SCOPE JOB NUMBER 2G-03 STATE TESTING 0920961436.7 DATE DAILY WORK UNIT NUMBER 09/27/96 LEAK DETECTION. INSTALL TEST PORT (TREE) 70356 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I YESI YES HES-FREEBORN SMITH FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTI2~IATE KAWWRK 230DS28GL $2,960.00 $2,960.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann [ Initial Outer Ann I Final Outer Ann 2500 PSI 2250 PSI 2450 PSI 700 PSI[ 300 PSI! 300 PSI DAILY SUMMARY SET 2.75" CRX PLUG W/FILL EXTENTION (TOTAL LENGTH: 42") IN D-NIP @ 8078' RKB. PfF AND MONITOR TUBING AND CASINGPSI FOR FLUCTUATION. MINUTE PSI CHANGE IF ANY. IF LEAK EXISTS, WILL HAVE TO BE PIN-POINTED WITH E-LiNE. BLED DOWNTUBING, INSTALLED TEST PORT IN TREE. PULLED CRX PLUG W/3.5" GS. TIME 13:00 13:45 LOG ENTRY TGSM - MIRU HES/APC. P/T LUBRICATOR TO #3000 PSI. STANDARD (1.875") TS. RIH W/3.5" X-LhNE RUNNING TOOL & 2.75" CRX PLUG W/FILL EXTENTION (TOTAL LENGTH: 42")TO D-NIP @ 8078' RKB / 8076' SLM. SET PLUG. POOH. 14:45 APC PT TUBING TO 3450g, CASING @ 2375#, WATCH 40 MINS. TUBING 3425# & CASING 2375#. RIG-UP APC TO CASING PT TO 340(0. TUBING @ 3500g WATCH 30 MINS. PRESSURES STAYED THE SAME. 17:00 18:00 18:20 18:30 20:00 RIG APC BACK ON LUB. PRESSURE 3500~, BLEED CASING TO 1000~, TUBING TO 3150#, WATCH 30 MINS. TUBING 3100~ & CASING 1000~. HES OPERATOR DECIDES "IF LEAK EXISTS, TOO SMALL TO BE PIN-POINTED WITH SLICKLINE". APC BLEEDS DOWN TUBING TO ZERO PSI. TEST PORT INSTAI,I,ED ON TREE. RIH W/3.5" GS AND EQUILIZING PRONG TO D-NIP @ 8078' RKB / 8076' SLM. LATCHED ANDPULLED 2.75" CRX PLUG OOH. RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $1,060.0b $1,060.00 HAL~ mURTON $1,900.00 $1,900.00 ! TOTAL FIELD ESTIMATE I $2,960'00l $2,960.00 ARCO Alaska, Inc. KUPARUK RIVER UNIT ~' WELL SERVICE REPORT ~' K1(2G-03(W4-6)) 'JELL JOB SCOPE JOB NUMBER ~.G-03 TUBING LEAK: DIAGNOSE, PATCH 1022960630.2 DATE DAILY WORK UNIT NUMBER 1 1/16/96 TUBING LEAK: DIAGNOSE, PATCH 70356 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O NoI (~) Yes ~ No HES-SCHNEIDER SMITH FIELD AFC# CC~ DAILY COST ACCUM COST Signed ESTIMATE KAWWRK 230DS28GL $6,721 $6,721 Initial Tb.q Press Final Tbcl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 2500 PSI 0 PSI 2500 PSI 0 PSII 250 PSII 0 PSI DAILY SUMMARY CIRCULATED 153 BBLS OF 9.9 BRINE INTO 7" CSG-TAGGED FILL @ 844d' RKB = 132' OF RATHOLE TIME LOG ENTRY 07:00 OPERATIONS MEETING @ KIC 08:30 TGSM: CHECK ALL CAUTION TAGS PRIOR TO RIGGING UP. MIRU HES AND LI-i-FLE RED SERVICES 09:30 .DISCOVERED DEFECTIVE AMERADA DURING FLEXING PROCESS STAND BY FOR ANOTHER 10:30 RIH W/3" X-LINE, 2.75" MXN PLUG, SOFT SET & DUAL AMERADAS TOP ELE.-63939, RS-73813, CLOCK -E24744. BOTTOM AMRADA ELE.-70204, RS-75944, CLOCK-E54515 TO SET IN "D" NIPPLE @ 8078' RKB (8084' WLM) POOH PLUG & AMERADAS SET 12:00 RIG DOWN LITTLE RED MIRU APC PUMP TRUCK. 12:30 - PfT LINES AND LUBR. TO 3000 PSI. RIH W/3" OK-1 & 1.25" JD TO PULL 1" DV @ 8003' RKB (8014' WLM) POOH WI VALVE. 13:40 BEGIN PUMPING DOWN TBG TAKING RETURNES UP 7" CSG- 58 BBLS OF DIESEL, 153 BBLS OF 9.9# BRINE- 70 BBLS OF DIESEL 3:00 RIH W/3" OK-1 & 1" DV W/WATER INJ PACKING- SET @ 8014' WLM (8003' RKB)- POOH THIS TEST WITNESSED BY ARCO REPS & STATE- PRESSURE TBG UP TO 2900#- 1900# ON 7" CSG/ ,7:10 18:00 TBG PSI DROPPED TO 2950# & 7" CSG DROPPED TO 1850#- ARCO & STATE MAN SATISFIED- 18:01 RIH W/3" GS & EQ. PRONG TO 8084' WLM, (8078' RKB)- POOH W/PLUG & GAUGES- BOTTOM HOLE PRESSURE ON TOP GAUGE WAS 4906#- BOTTOM GAUGE 4874#- GOOD CHARTS- 19:10 RIH W/2.2 CENT, TEL & 1.6 SWAGE TO LOC TBG TAIL @ 8096' WLM (8090' RKB) TAGGED FILL @ 8450' WLM (8ddd' RKB) = 132' OF RATHOLE- POOH 20:45 RDFN ........ I Aiask¢ Oil & '* r,,...,..,,, r, ..... ~ .... Anchnm,'-jr, ISERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $538.00 $538.00 PC $1,980.00 $1,980.00 HALLIBURTON $3,104.00 $3,104.00 LR-R_E RED ' $1,100.00 $1,100.00 TOTAL FIELD ESTIMATE $6,722.00 $6,722.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: ARCO Alaska~ Inc. FIELD I UNIT ! PAD KUPARUK I KRU/2G DATE: 11/16/96 PRETEST START 15 MIN 30 MIN *P TYPE PACKER REQ TBG TIME TIME TIME WELL *S ANNULUS TVD CASING TBG TEST CSG 'FBG TBG TBG START P F NAME *N FLUID MD SIZE / WT / GRADE SIZE PRESS PRESS CSG CSG CSG TIME 2G-03 S DSL/ 5967 7"/26#/J-55 3.5 1492 1,875 2,900 2,850 2,850 17:10 X 9.9# Brine 8059 1875 1890 1860 1850 COMMENTS: Known tubing x 7" communication. 7" loaded with 9.9# brine/Plug set in tubing @ 8078', filled w/diesel for MIT COMMENTS: COMMENTS: *TUBING INJECTION FLUID: ANNULAR FLUID: GRADIENT: WELL TEST: P = PRODUCED WATER INJ. DIESEL 0.353 Initial s = SALT WATER INJ GLYCOL 4 - Year X M = MISCIBLE INJ. SALT WATER 0.442 Workover i = INJECTION DRILLING MUD Other N = NOT INJECTING OTHER OTHER Distribution: orig - Well File AOGCC REP SIGNATURE CHUCK SCHEVE c - Operator c - Database OPERATOR REP SIGNATURE Eric L. Zuspan c - Trip Rpt File c- Inspector FAXED DATE TIME MIT 2G TO: MR BLAIR WONDZELL (276-7542) Rev. 12/93 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing m Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address Suspend m Operation Shutdown~ Re-enter suspended well Repair well __ Plugging ~ Time extension Stimulate P. O. Box 100360, Anchorage, AK 99510 Pull tubing ~ 5. Type of Well: Development X Exploratory ~ Stratigraphic __ Service __ 4. Location of well at surface 547' FSL, 44' FEL, SEC. 31, T11N, R9E, UM At top of productive interval 1170' FNL, 3620' FEL, SEC. 31, T11N, R9E, UM At effective depth 945' FNL, 3859' FWL, SEC. 31, T11N, R9E, UM At total depth 945' FNL, 3859' FI:L, SEC. 31, T11N, R9E, UM variance X Perforate Other 6. Datum elevation (DF or KB) 139' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2G-03 9. Permit number 84-139 10. APl number 50-029-21165 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8644 true vertical 6394' feet Plugs (measured) feet Effective depth: measured 8448' feet Junk (measured) true vertical 6245' feet Casi~,~ Length Size Cemented Measured depth True vertical depth Structural Conductor 116' 1 6" 240 SX CS II 116 ' 116' Surface 3240' 9 5/8" 900 SX PF CLASS E & 3240' 2746' Intermediate 370 SX PF CLASS C Production 8637' 7" 380 SX CLASS "C" & 8637' 6390' Liner 258 SX PF CLASS C Perforation depth: .. ' i i i.;' --.' '~ measured 8250'-8262', 8278'-8312' true vertical 6095'-6104', 6116'-6141' Tubing (size, grade, and measured depth) 3 1/2" 9.3 LB/FT, J-55, 8090' MD Packers and SSSV (type and measured depth) PACKER: CAMCO HRDP @ 8059, SSSV: OTIS FMX-TR @ 1898' 13. Attachments Description summary of proposal X Detailed operation program n BOP sketch VARIANCE TO CONTINUE INJECTION 14. Estimated date for commencing operation 15. Status of well classification as: Oil Gas !16. If proposal was verbally approved ; ! Name of app. rover Date approved i17. I hereby//~ify that the oz~g~g is true and correct to the best of my knowledge. !/ Signed ( /~'.~/~.v .,//'~~~,-,,,-,' Title Wells Superintendent ~ ' - ,Z/' ' -- FOR COMMISSION USE ONLY Condition~,/of approval: Notify Commission so representative may witness · Plug integrity BOP Test Location clearance __ Service WAG Injector Suspended Date /,~--'3~./~.'-_ ~.,~''~ Mechanical Integrity Test Approved by order of the Commission Subsequent form require 10- ,]aviQ Al. johnStOn Commissioner Date IApproval Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: ARCO Alaska, Inc. FIELD / UNIT/PAD KUPARUK ! KRU !2G DATE: 1 1 /16/9 6 PRETEST START 15 MIN 30 MIN *P TYPE PACKER REQ TBG TIME TIME TIME WELL *S ANNULUS TVD CASING TBG TEST CSG TBG TBG TBG START P F NAME *N FLUID MD SIZE / WT ! GRADE SI71= PRESS PRESS CSG CSG CSG TIME 2G-03 S DSL/ 5967 7"/26#/J-55 3.5 1492 1,875 2,900 2,850 2,850 17:10 X 9.9# Brine 8059 1875 ~ 1890 1860 1850 COMMENTS: Known tubing x 7" communication. 7" loaded with 9.9# brine/ Plug set in tubing @ 8078', filled w/diesel for MIT COMMENTS: COMMENTS: ) *TUBING INJECTION FLUID: ANNULAR FLUID: GRADIENT: WELL TEST: P = PRODUCED WATER INJ. DIESEL 0.353 Initial S = SALT WATER INJ GLYCOL 4 - Year X M = MISCIBLE INJ. SALT WATER 0.442 Workover i = INJECTION DRILLING MUD Other N = NOT INJECTING OTHER OTHER Distribution: orig - Well File AOGCC REP SIGNATURE c - Operator c- Databa ,se ~ OPERATOR REP SIGNATURE c - Trip Rpt File c-Inspector FAXED MIT 2G CHUCK SCHEVE Eric L. Zuspan .~,-,~'~ DATE TIME TO: MR BLAIR WONDZELL (276-7542) Rev. 12/93 Attachment 1 Request for Variance Kuparuk Well 2G-03 As per Area In'ectionj Order No. 2,. Rule. 7, ARCO Alaska. is hereby notifying. . the Commission of pressure communication between the tubing and casing ~n KRU Injection Well 2G-03. As set fo~h in the Rule 7, ARCO Alaska is requesting Commission approval to continue water injection into this well. As found in Area Injection Order No. 2, the aquifers described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit are exempted for Class II injection activities by 40 CFR 147.102(b) (3) and 20 AAC 25.440(c). As such, continued injection will not endanger any Underground Source of Drinking Water (USDW). In March 1996, the production casing pressure suggested that there was communication with the tubing. The tubing hanger was subsequently pressure tested to 3000 psi on 4/17/96 as described in the attached WSR. The well was shut-in on 4/29/96. Between 4/30/96 and 7/16/96, nine slickline days were spend changing out the DVs in all five gaslift mandrels. Pressure testing indicated that the leak was still present. On 9/27/96 a plug was set in the tailpipe and a simultaneous pressure test of the tubing and production casing to 3400 psi was performed to ensure packer integrity (see attached WSR). The pressure testing also indicated that the leak was no longer ]3resent and the well was returned to injection on 10/18/96. The Drillsite 2F injection service had been changed to produced water which is substantially warmer than the seawater injection service that the well was on when the communication was first noted. It was thought that the increased injection temperature would seal the DV packing better, however, the communication still persisted. On 11/11/96 the well was shut-in. The source of the communication is thought to be the SBR seals at 8041' RKB. The seals appear to hold in static conditions, but fail in the dynamic conditions of fluctuating operating pressures and temperatures causing tubing movement. On 11/17/96 a plug was set in the tailpipe and the production casing was displaced with 58 BBL of diesel and 153 BBL of 9.9 ppg brine. The tubing and casing were subsequently pressure tested to 2850 psi and 1850 psi respectfully. The pressure test was witnessed by AOGCC representative Chuck Scheve. This test demonstrates that there are no external casing leaks in this injection well and that injection fluids are confined to the Kuparuk River Sands. ARCO Alaska Inc. requests that the simultaneous tubing and casing pressure test performed on 11/17/96 satisfy the 1996 MIT requirement for Well 2G-03. Additionally, an alternative MIT consisting of a simultaneous pressure test of the tubing and casing is requested for subsequent MITs as dictated by the Commission. The well will also be placed on a water injection only status. Casing and tubing pressures will continue to be monitored and reported as per Area Injection Order No. 2, Rule 4 to ensure that the casing pressure does not exceed 70% of the casing's minimum yield strength. ARCO Alaska, Inc. KUPARUK RIVER UNIT -'~ WELL SERVICE REPORT ~ K1(2G-03(W4-6)) WELL JOB SCOPE JOB NUMBER 2G-03 WELL HEAD MAINT: TEST, REPAIR 0421962316.7 DATE DAILY WORK UNIT NUMBER 04/17/96 TBG HANGER TEST DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes O NoI (~) Yes O No ARC GOLDEN . FIELD AFCff CC-fl DAILY COST ACCUM COST Signed ESTIMATE $ 0 Initial Tbq Press Final Tbcl Press Initial Inner Ann Final Inner Ann I Initial Ouier Ann I Final Outer Ann 271 0 PSI 2710 PSI 3250 PSI 3250 PSII }325 PSI 325 PSI DAILY SUMMARY PRESSURE TESTED TBG HANGER TO 3000 PSi - PASS. TORQUED LOCK DOWN SCREWS TO 600 FT-LBS. BLED VOID AREA. REPLACED TEST PORT FITTING. TIME LOG ENTRY SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL TOTAL FIELD ESTIMATE $0.00 $0.00 ARCO: Alaska, Inc. KUPARUK RIVER UNIT A WELL SERVICE REPORT Kl(2G-03(W4-6)) b-] J J JOB SCOPE JOB NUMBER 2G-03 STATE TESTING 0920961436.7 DATE DAILY WORK UNIT NUMBER 09/27/96 LEAK DETECTION. INSTALL TEST PORT (TREE) 70356 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YES] YES HES-FREEBORN SMITH FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE KAWWRK 230DS28GL $2,960.00 $2,960.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 2500 PSI 2250 PSI 2450 PSI 700 PSI 300 PSI 300 PSI DAILY SUMMARY SET 2.75" CRX PLUG W/FILL EXTENTION (TOTAL LENGTH: 42") IN D-NIP @ 8078' RKB. PFF AND MONITOR TUBING AND CASINGPSI FOR FLUCIIJATION. MINUTE PSI CHANGE IF ANY. IF LEAK EXISTS, WILL HAVE TO BE PIN-POINTED WITH E-LINE. BLED DOWNTUBING, INSTALLED TEST PORT IN TREE. PULLED CRX PLUG W/3.5" GS. TIME 13:00 13'45 14:45 17:00 LOG ENTRY TGSM - MIRU HES/APC. P/T LUBRICATOR TO #3000 PSI. STANDARD ( 1.875") TS. RIH W/3.5" X-LINE RUNNING TOOL & 2.75" CRX PLUG W/FILL EXTENTION (TOTAL LENGTH: 42")TO D-NIP @ 8078' RKB / 8076' SLM. SET PLUG. POOH. APC PT TUBING TO 3450g, CASING @ 2375#, WATCH 40 MINS. TUBING 3425# & CASING 2375#. RIG-UP APC TO CASING PT TO 3400g, TUBING @ 3500g WATCH 30 MINS. PRESSURES STAYED THE SAME. RIG APC BACK ON LUB. PRESSURE 3500~, BLEED CASING TO 1000~, TUBING TO 3150#, WATCH 30 MINS. TUBING 3100~ & CASING 1000~. 18:00 HES OPERATOR DECIDES "IF LEAK EXISTS, TOO SMALL TO BE PIN-POINTED WITH SLICKLINE". 18:20 APC BI .El.DS DOWN TUBING TO ZERO PSI. TEST PORT INSTALLED ON TREE. 18: 3 0 RIH W/3.5" GS AND EQUILIZING PRONG TO D-NIP @ 8078' RKB / 8076' SLM. LATCHED ANDPULLED 2.75" CRX PLUG OOH. 20:00 RDMO SERVICE COMPANY - SERVICE DAILY COST A~2CUM TOTAL APC $1,060100 $1,060.00 HAl I]tlURTON $1,900.00 $1,900.00 ! TOTAL FIELD ESTIMATE I $z,9 .ool $2,9 o.oo ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~ K1(2G-03(W4-6)) "ELL JOB SCOPE JOB NUMBER 2.G-03 TUBING LEAK: DIAGNOSE, PATCH 1022960630.2 DATE DAILY WORK UNIT NUMBER 1 1/16/96 TUBING LEAK: DIAGNOSE, PATCH 70356 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I (~ Yes O NoI (~) Yes O No HES-SCHNEIDER SMITH FIELD AFC~ CC,~ DAILY COST ACCUM COST Signed ESTIMATE KAWWRK 230DS28GL $6,721 $6,721 Initial Tb.q Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 2500 PSI 0 PSI 2500 PSI 0 PSII 250 PSII 0 PSI DAILY SUMMARY 153 BBLS OF 9.9 BRINE INTO 7" CSG- TAGGED FILL @ 84dd' RKB = 132' OF RATHOLE CIRCULATED TIME LOG ENTRY 07:00 OPERATIONS MEETING @ KIC 08:30 TGSM: CHECK ALL CAUTION TAGS PRIOR TO RIGGING UP. MIRU HES AND LR-FLE RED SERVICES 09:30 DISCOVERED DEFECTIVE AMERADA DURING FLEXING PROCESS STAND BY FOR ANOTHER 10:30 RIH W/3" X-LINE, 2.75" MXN PLUG, SOFT SET & DUAL AMERADAS TOP ELE.-63939, RS-73813, CLOCK -E24744. BOTTOM AMRADA ELE.-70204, RS-75944, CLOCK-E54515 TO SET IN "D" NIPPLE @ 8078' RKB (8084' WLM) POOH -- PLUG & AMERADAS SET 12:00 RIG DOWN LI'FR..E RED MIRU APC PUMP TRUCK. 12:30 P/T' LINES AND LUBR. TO 3000 PSI. RIH W/3" OK-1 & 1.25" JD TO PULL 1" DV @ 8003' RKB (8014' WLM) POOH W/ VALVE. 13:40 BEGIN PUMPING DOWN TBG TAKING RETURNES UP 7" CSG- 58 BBLS OF DIESEL, 153 BBLS OF 9.9# BRINE- 70 BBLS OF DIESEL ~:00 RIH W/3" OK-1 & 1" DV W/WATER INJ PACKING- SET @ 8014' WLM (8003' RKB)- POOH THIS TEST WITNESSED BY ARCO REPS & STATE- PRESSURE TBG UP TO 290Off- 1900# ON 7" CSG/ ~7:10 18:00 TBG PSI DROPPED TO 2950# & 7" CSG DROPPED TO 1850#- ARCO & STATE MAN SATISFIED- 18:01 RIH W/3" GS & EQ. PRONG TO 8084' WLM, (8078' RKB)- POOH W/PLUG & GAUGES- BOTTOM HOLE PRESSURE ON TOP GAUGE WAS 4906#- BOTTOM GAUGE 48744f- GOOD CHARTS- 19:10 RIH W/2.2 CENT, TEL & 1.6 SWAGE TO LOC TBG TAIL @ 8096' WLM (8090' RKB) TAGGED FILL @ 8450' WLM (8'!.44' RKB) = 132' OF RATHOLE- POOH 20:45 RDF'N I SERVICE COMPANY - SERVICE DALLY COST ~CCUM TOTAL $538.00' $538.00 PC $1,980.00 $1,980.00 HALLIBURTON $3,104.00 $3,104.00 · LR-FLE RED $1,100.00 $1,100.00 TOTAL FIELD ESTIMATE $6,722.00 $6,722.00! , 26-0,_5 10000 5000I 1000 5O0 100 5O Water Injection Rate (Calendar Day)(bbls) Gas Injection Rote (Calender Day)(Mscf) · · · · · · · · · · · · · · · 10 I--84 I 85 I 86 I 87 I 88 I 89 I 90 I 91 t 92 I 9,3 I 94 I 95-' I 96--t ARCO Alaska, Inc. Post Office Bo,, i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1985 Mr. C. V. Chatter Alaska Oil and Ga 3001 Porcupine Dr Anchorage, AK 9 ton, Chairman s Conservation Commission ive 9501 Dear Mr. Chatterton- Attached in du following wells a We I I Ac t i on plicate are subsequent notices t the Kuparuk River Field- Date Performed on the 1 L- 1 Conve 1 L- 7 Conve 1Q-2 Conve 1Q-7 Conve 1 Q- 11 Conve 1 Q- 1 3 Conve 2B- 5 Conve 2B- 9 - Conve 2C- 1 Conve 2C-3 Conve 2C-6 Conve 2C-8 Conve 2D-2 Conve 2D-7 Conve 2D- 11 ConYe 2D-1 4 Conve 2F-1 Conve 2F-2 Conve 2 F- 1 3 Conve 2 F- 1 4 Conve 2G-3 Conve 2G-3 Conve 2G-5 Conve 2G-7 ConYe 2G- 1 0 Conve 2.G- 12 Conve 2G- 1 6 Conve 2U-3 Conve 2U- 4 Conve 2U-7 Conve 2U- 1 6 Conve 2W-2 Conve 2W-4 Conve rs on rs on rs on rs on rs on rs on rs on rs on rs on · rs on rs rs on rs on rs on rs on rs on rs on rs on rs on rs on rs on rs on rs on rs on rs on rs on · rs on rs ' on · rs on rs on , rs on rs on rs on 11118185 11118185 11117185 11/17/85 11/17/85 11/17/85 11/23/85 11/23/85 11/19/85 11/19/85 11/19/85 11/19/85 11120185 11/20/85 11/20/85 11/20/85 11/21/85 11/21/85 11/2i/85 11121185 11/14/85 11114185 11/14/85 11/14/85 11/14/85 11/14/85 11/14/85 RECEIVED 11/16/85 11 / 16 / 85 .JAN.~~ 11/16/85 11 / 15 / 8~ask~ 0ii & Gas Cons. Oom~l.~:.-::::.,,-, 11 / 22 / 85 A~chora9~ ARCO Alaska, I~c is a Subsidiary of AtlanlicRichfie,,:Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 4. Location of Well SURFACE LOCATION- T11N, RgE, UM 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-139 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21165 548' 44' 31 FSL, FEL, SEC. 5. Elevation in feet (indicate KB, DF, etc.) 1 40' (RKB) 12. I 6 . Lease Designation and Serial No. ADL 25667 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 20-3 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 [] 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). On November 14, 1985 Kuparuk well 2G-3 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into the "A"sand. RECEIVED 0 1986 Alaska 0it & Gas U0ns, Commi:_.:...:=;,; 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~- ~/'~ ~'~~ Title KUPARI IK The space below for Commission use OPERAT IONS COORD I NATOR Conditions of APproval, if any: Date 17/1_R/85 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 g., 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 · Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on september 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 RECEIVED 0~ ¢, Gas Cu~s. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK/~'~'"L AND GAS CONSERVATION C~'~'MISSION SUNDRY NOTICES AND REPORT ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 4. Location of Well N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 99510 6. Lease Designation and Serial No. see attached 7. Permit No. see attached 8. APl Number so- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool Kuparuk Rive Kuparuk Rive r Field r Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [~ Repairs Made [] Other [] Pull Tubing [] Other 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). pursuant to form 10-403, it is proposed that the attached list of~Aproducing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. SEP 2 0 Gas COBS. Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, /¢~-~/~ ~~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Approved Copy .J~,eturned / .... By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 ~-16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK:0092 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 80 85 106 128 132 85- 6 7 20 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177 21176 21157 21169 21135 21134 21183 ~21185 029-21246 21227 21213 21214 029-21058 21063 21062 21065 21032 21035 21048 21052 029-21150 21165 21119 21124 21140 21159 21163 029-21269 21270 21283 21303 21262 21264 029-21037 21041- 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25653 25658 l! 25658 !! 25657 25656 25644 25643 25655 25644 25655 25642 I! 2580 12/15/85 " 10/15/85 " 12/15/85 2579 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 2584 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 2584 12/15/85 " 12/15/85 " 12/15/85 " 12/15/85 2583 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 2582 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 2575 10/15/85 " 12/15/85 " 10/15/85 2574 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 2575 10/15/85 '! 10/15/85 " 12/15/85 2581 10/15/85 " 12/15/85 2573 10/15/85 " 12/15/85 " 12/15/85 " ~/15/85 Oil & Gas Cons, Commission ARCO Alaska, Inc. ' ' Post Office B~,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2G-3 Dear Mr. Chatterton- Enclosed is a copy of the 2G-3 Well History to include with the Well Completion Report, dated 02/21/85. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU6/L74 Enclosure cc: 2G-3 Well File RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -] ~ ~"~ Bill Sheffield, Governor ALASKA OIL A#D gAS COliSEIlYATIIlll.gOffffffl$$JOll soot POIICUPIflE DRIVE ANCflOI1AOE,ALABKA IgsOt~SfI! · ~o, :_ .~. LA.EK/t ~NC. __ . /)-t/-n. ,'=B E C. K y I/ Well ~.oo . _ T ! ! N.- £ ¢__F__...~',,~-. /,., . / We wi~h to bring to your atteution that the Commission has yet received the following required items on the subject, well ~l,icl, our records indicated was completed ~-/?- Article 536(b) of Title 20, Ch.pter 25, Alaska Administrative Code, stipulates that this material shall be filed withiu 30 days after completion of a drilled.well. Please submit the above missing material. Chairman lc~C.024 ARco Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports for the following wells' 2F-6 2G-3 1L-15 1L-16 2H-1 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L46 Enclosures RECEIVED APR 2 5 ].085 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE Of ALASKA ALASKA ~.._ AND GAS CONSERVATION CO, ..~IlSSION -WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISION OIL ~[X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-139 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21165 4. Location of well at surface 9. Unit or Lease Name ~ 547' FSL, 44' FEL, $ec.31, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1170' FNL, 3620' FEL, Sec.31, TllN, RgE, UM 2G-3 At Total Depth 11. Field and Pool 945' FNL, 3859' FEL, Sec.31, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool 139' RKBI ADL 25656 ALI( 2582 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore I 16. No. of Completions 08/09/84 08/18/84 09/19/84J N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8644'MD,6394'TVD 8554'MD,6325'TVD YES [~X NO [] 1898 feet MDI 1530' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, RFT, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 240 ~x CS II 9-5/8" 36.0# J-55 Surf 3240' 12-1/4" 900 sx Permafrost E & 70 sx Permafrost C 7" 26.0# J-55 Surf 8637' 8-1/2" 380 sx Class C & 2~;8 9; PF "C" 24. Perforations open to Production (MD+TVD of Top and B6ttom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8372' - 8288' 3-1/2" 8090' 8059' 8288' - 8278' 8262' - 8250' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.1~ 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 R C[iV£D /~aska 0ii & Gas Cons. C0mmissJ0n Anchorage Form 10-407 JMM2/WC17 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. - 30. ;": .. ' ;:. '--,. .. . ~EOLOG'I'CMARKERS - ' ' ' FORMATION TESTS . NAME Include interval'tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8141' 6013' N/A Base Upper Sand 8160' 6027' Top Lower San~l 8234' 6081 ' Base Lower Sand 8401' 6207' , I 31. LIST OF ATTACHMENTS None 32. ' I hereby certify that the foregoing is true and correct to the best of my knowledge Signed t~) ~ .~J~ Title Associate Engineer Date 4~//°)'-~'~' //- INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in 'item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. Post Office B~,^ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 21, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2G-3 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the 2G-3 Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L180 Enclosures gECEivED Alaska Oil & 8-° - .-'"~, Cons. Commission /~r~cr~o r~, LT_3 ARCO Alaska, Inc. is s Subsidiary of AtlanticRichfieldCompany .---; STATE OF ALASKA .... ALASKAL ~AND GAS CONSERVATION CO /IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operato'r 7. Permit Number ARCO Alaska, Inc. 84-139 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21165 4. Location of well at surface 9. Unit or Lease Name 547' FSL, 44' FEL, Sec.31, T11N, R9E, UN ~~1 Kuparuk River Unit At Top Producing Interval t VF_~iFiFD ! 10. Well Number 1170' FNL, 3620' FEL, Sec.31, TllN, R9E, UM {Surf._~ --i 2G-3 ~ H. "~i 11. Field and Pool At Total Depth 945' FNL, 3859' FEL, Sec.31, T11N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 139' RKBI ADL 25656 ALK 2582 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 08/09/84 08/18/84 09/19/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MI~-TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8644'MD,6394'TVD 8554'MD,6325'TVD YES [~X NO [] 1898 feet MDI 1530' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, RFT, Gyro 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 116' 24" 240 sx CS I I 9-5/8', 36.0# J-55 Surf 3240~ 12-1/4" 900 sx Perma.frost E & 70 sx Permafrost C 7" 26.0# J-55 Surf 8637' 8-1/2" 380 sx ClaSs G · 24. Perforations open to P'roduction (MD+TVD of Top and Bottom and 25~ TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8372' - 8288' 3-1/2" 8090' 8059' 8288' - 8278' 8262' - 8~_0' 26. ACID, FRACTURE, cEMENT SQUEEZE, ETC. 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 OI L-BBL GAS-MCr WATER-BBL CHOKE SIZE GAS-OI L RATIO TEST PERIOD · Flow Tubing Casing Pressure CALCULATED .&, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (tort) 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 R[Ck' VED Alask~ 0il & ~as Cons. Commission Anch0ra~a Form 10-407 GRU4/WC33 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. . .~--~ . 30. ~ G EOI:OG lC-MARK-ERS, - .... -- - :' ' FoRI~'ATION .TEsts . . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8141' 6013' See attached sheet for RFT results. Base Upper Sand 8160' 6027' Top Lower Sand 8234' 6081' Base Lower Sand -8401' 6207' 31. LIST OF ATTACHMENTS PI~T ........ ~=, Gyre~cep,.'~ v_~,,rvey (?,_ ¢op,.'es) 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ ~ ~. Title Associate Engineer Date 2-2J-~' _ 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 (G L) 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". * SCHbUMBERGER * GC? DIRECTIONAb SURVEY .Srut~ ,,:' FOR ARCO ALAS~A~ INC, 2G'] KUIPARUK N, SLUPE~ ALASKA SURVEY DATE{ 28-AUG-84 ENGiNEERt G, JOHNSON METHODS OF COMPUTATION TOOL LOCAl:ION: TANGENT[A[,- averaged devla~.l, n ~ ,d lmuth INTERPOLATIONI LINEAR ", .... ,~,,, ,, , ~ VERTICAL SECTIONI HORIZ, D~ST PROdECTED ON'X'O,~A"~A~ET AZIMUTH OF NOR'I'M 47 DEG 20 M1N W~T CUSTOMER LISTING ARCO ALASKA, INC, KUPARUK N, SLOPE, ALASKA SURVEY DATEI 28-AUG-84 ENGINEERI G, JOHNSON METHODS OF COMPUTATION ., TOOL LOCATION: TANGENTIAL~ averaged devl&:lon~,~,,a(r~d azimuth INTERPOLATION: LINEAR '~ VERTICAL SECTION: HORIZ, DIST,, PROJECTED ONTOi:~::~i~i~AR. GET AZIMUTH OF NORTH 47 BEG 20 ,..ARCO ALASKA, INC, ,.Ne SLOPE; ALASKA COMPUTATION DATE{ 19-SEPT-B4 TRUE SUB-S~.~ii~ATCOIJRSE ":0 00 0 00 -139,,"~ ,OO O0 100 O0 -~9,.. t8~ 00 200 00 61 00 300 00 161: '~'~ "~ 300 400 i.l o DATE OF SURVEY1 28-AUG-B4 KEbL¥ BUSHING EbEVATXONI ENGINEER; G. OOHNSON INTERPObATED VALUES FOR EVEN 100 FEET OF MEASURED D~PTH EG NGULAR COORDINATEs VERTICAL DOG~ITY RECTA SECTION SEV NORTH/SOUTH EAST/~EST P FEET DEG/IO0 FEET FEET F 1000 O0 994 67 855,67 15 42 226,33 27 45 1573,39 33 62 1655,62 36 25 98 ,98 40 o, lO 18 ~ 46 52 78 ~ 7 67 7 45 31 14 2294.14 45 I0 97 2164.97 44 5 16 2436,16 44 27 77 45 27 2652 27 43 54 08 2723 08 45 43 28 285 57 36 2923 36 49 39 O0 2988 00 49 58 29 3052 29 50 0 N 0 0 E 0.00 N 8 15 W 0,06 N 22 14 E 0.18 N 12 54 W 0.26 N 38 56 W 0.44 N 44 35 W 0.91 N 61 7 W 2.24 N 47 24 W ~,30 40 48 W 60.43 4 50 W 124, 6 45 9 W 164,23 45 28 W 208,54 47 4 W 256,55 47 2 W 306,11 46 3~ W 355.01 45 56 W 40.7.22 45 18 W 464.07 44 36 ~ 526.11 43 54 593 t8 43 ~5 N 66~e36 43 18 W 737:.42 43 3 ~ 44 W 953.66 3 W I 0 44 024,,8 44 6 W 44 7 W 166e~? 44 14 W 1236 39 44 19 W 44 29 44, 44 32 W15821 N 45 4 W I ' 2 45 18 W 1890.46 O0 1275 O0 1365 539 62 O0 1794 000,0 00,00 ttoo o,o ooo; o 00,00 433 2503 :~::30:0:0:O0 2575 oo;oo ~ 0~00 29~o :~.t6:~0~:,0:0. 2997 0 .0 62 3127 . oo.oo 0.00 0,08 0.07 0.10 0.20 0.32 3,31 2,99 ,13 ,57 3 24 2 75 3 13 2 98 2 5~ 1 44 2 0{ 2 63 3 19 3 86 3 59 48 0 $7 0 71 0 o 0 48 0 54 0 4 o 0 00 N 0 07 N 0 28 N 0 O0 E 0 02 W 0 0 0 0 1 5 46 N 0 61N 0 97 N 0 67 N 1 32 N 6 79 N 13 49 N 24 E 45.77 N 40 O0 W 93 13 N 121 61N 111 26 ~ 152 84 N 142 74 W 253 289 328 372 733 '/84 94 N 77 52 W 61N 113 W 99 N 32? 90 ' 464 N 37 N 414 76 N 467 12 N 517 95 N 567 16 N 617 N 667 95 N 766 64 N 815 526 58 N W 77 w 98 ~ 811 95 W 663 77 ~ 954 31 W 10~7 O6 76 w 1 89 w 1167 N W . i,:i .ii. N 44 1034 1085 1244 1298 1352 89 N 10 0 27 N 1o49 30 N 11 25 N 1324 W' 1446 59 W 1589 98 ~ 1664 6 ~ 1740 8 W 1816 63 W 1892 80 N 44 14 N 4 W 35 N, W 94 N 44 W ARCO AL, ASKA~ INC. UPARUK N, SIaOPE, ALASKA .. TRUE 4EA&URED VER?ZC DEPTH DEPT 35 4000,00 3~2~ 4i00,00 4200,00 3385 4300,00 3450 4400,00 3516 4500,00 3582 4600,00 3649 4700'00 3716 48oo.oo 4900,00 3 AL VERTICAI~.D~¥'~J~T3[ON AZIMUTH ii D EPT l-it~-~ ~. ~~~ ,,, ,, I N DEG ~IN FEET 0 9 3246.9,~:~',~ 4 50 331 i. S~L~ 3 29 3377.29 t8 37 6 3 3510, ~:{~.~t~t~ ~2 35~7. 44 3645.4~ 47 14 49 3713.49 47 2 55 46 2~ 68 46 45 5000,00 3920 84 3781 84 46 2 5100.00 ~ 4 ,,oo.oo °°oo , o ~il{O0,O0 4543 19 4404,19 49 42 48 i 4727.53 49 39 6600.00 499~.86 4855,86 50 2 $~OO,O0 505 , , ,96 5040.96 59 · '~000 O0 5242 35 5103 35 51 2 36 47 46 O0 5841 14 5702.14 46 6 DEG/IO0 ~'EET FEET FE N 45 17 k 1966.97 N 45 4 W 2043 ;35 N 45 3 . 2119.30 N 45 5 W 2194 N 45 7 W 23;9144 N 44 55 W 2419,24 N 44 57 W 2493,i5 N ~ 0 W 2566.68 N45 4 W 2639,89 N 45 12 W 2712 84 '~857,64 N 44 49 W 2929,42 N 44 35 W 3000~0 N N 44 4 W 3286;~7 N 43 12 W 3361,82 N 41 14 W 1590 47 N 41 0 W 666 07 N 39 38 W ~741 32 N 38 6 W 817 03 N ~8 36 w N 45 20 W N 46 6 w 4206 08 N 46 39 w 428335§ N 48 10 W 4 N 47 4 W 4 N 49 2~ W 4136 12 N 50 57 W 4586 N 52 58 W 465.9 N ~ 49 W 47 57 N 55 W 48u~ 68 0 73 71 o 0 1 05 0 57 0 52 0 46 0 28 0 43 0 20 0 28 0 37 0 48 0 31 0 57 0 52 2 51 0 66 2.~2 o 0 2o i406 459 1513 1567 1620 1673 1725 1778 1830 1881 08 a~ ~3 9.~ : 1969 95 N ,4a3, 2045 6b N 1487,08 W 2121 06 a 1540.65 W 21 9~ 26 N 1593 09 N 1751 78 W 855 65 W 2642 PAGE 2 · PARTURE MUTH G MIN 1933 40 N 1907,40 OlO,li W 111.05 3004 289 30 N 2259 04 W 3216 ~342 32 N 2310 76 W 3290 2396 70 N 2362 98 ~ 3365 2715 91 N 44 36 W 23 N 44 37 W )0 N 44 36 W 68 N 44 35 W 09 54 N N 466 8 22 ~ 08 N ~616 664 86 w 3977 29 ~ 40 6 72 W 41~5 0 36 3029 80 N 2927 64 W 4213 16 N 44 I W 13 N 2983 3 16 N 3039 3457 91 N 3443 49 4290 68 : 4366 4Si9 4665 09 ~ 4736 4808 68 w 4880 17 N 44 52 ~ COMPUTATION DATE: 19-SEPT-84 ARCO'AbASKA~ INC, PARUK N, &LOPE, ALASKA PAGE 3 DATE OF SURVE¥~ 28eAUG-84 KELLY BUSHING ELEVATIONI 139,00 FT ENGINEEE; G, JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGbEG RECTANGULAR COORDINATES H SECTION SEVERITY NORTH/SOUTH EAST/WEST DI FEET DEG/IO0 FEET FEET TRUE SUB-SEA COURSE IEABURED VERTICAL VERTICA~D~,[ATION AZIMUTH DEPTH DEPTH DEPTH~.~,~.IN DEG MIN O: , 3 N 52 {5 W 494b,50 N 49 45 W 5016,1! N 47 32 W 5084 44 N 47 2 W 5!51 05 N 46 41 W 5216 26 N 45 54 W 5280 56 N 45 54 W 5344 23 N 45 54 W 5372 24 53 ½ so 1 91 2 19 0 65 0 O0 0 O0 0 O0 3 500 52 N 3500 72 W 4950 3544 35 N 3554 99 W 5020 3589 76 N 3606 W 5088 3634 99 N }~54 ~ W 5154 3679 52 N 02 60 W 5219 3723 96 ~ 74, 08 ~ $ 8100.00 59 ,00 5844 e oo oo oo oo 6282,98 6143 6393,99 625 ARTURE 0 W 5 w ( #~A~URED V£RTICAL VERTIC~~~TION AZ~MU?H D~H DEPTH DEP~ FEE~ 'o oo o oo .~.~~'""~~ o ~ 1000, O0 994 67 855, 4v 48 W 2000 O0 98 1733e~i~23 N 44 36 W 4000 oo 3255 §) 3116.~:~;,.~:,s6 ~ 4s ::~:.. ,. COMPUTATION DATE) 19-$EPT-84 ARCO AbASKA~ INC, G-~ UP~RUK Ne SLOPE, ALASKA ENGINEER~ Ge dOHNSON INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT VERTICAL DOGLEG RECTANGULAR COORDINATES HI SECTION SEVERITY NORTH/SOUTH EAST/WEST D 0 O0 43 97 PAGE:, 4 DATE OF SURVEY~ 28-AUG-84 sO0 KELLY BU~HING EbEVATXONI 1~,~ : -,~? i' :!" ':," '!:~ ?' DEG/IO0 FEET FEET FE 6O · ~ 5103, N 4 6 W 4206 ?72,36 44 39 N 52 15 ~ 494 0 O0 3 24 3 44 0 54 0 o 1½ 21 0,23 OB 0,36 , .0 0 O O0 N 45 ~7 1~06 1933 40 N 0 O0 f 77 N 40 N 864 1 02 N 2414 ~0 N 292? O0 W 61 75 W 5 84 W 12 96 W 344 64 W ARTURE N U'TH '::' ?~: [ ARCO AbASKA, INC. 28-3 KUPARIIK N, SLOPE, ALASKA COMPUTATION DATE: 19-SEPT-84 PAGE DATE OF SURVEY: 28-AUG-64 KELLY BUSHING EbEVATXUNI 139.00 FT' ENGINEERI G, JOHNSON INTERPOLATED VALoUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE $tJB-SEA COURSE qEASUREP VERTICAl, V£R'rICAL,,.,DEV~ATION AZIMUTH DEPTH DEPTH 0 O0 0,00 -139, " 0 39 O0 39.00 oo oo ~ O0 239 O0 100, i~ 6 oo oo oo. O0 439 O0 639 05 639 O0 500,~ 16 81~ O0 ?00,00 9 5 943 46 1313 939.00 800,00 13 28 2O oo oo.gg oo oo.oo oo ,oo , 92 1839,00 ~.700:00 39 38 9 O0 4 30 O0 4~ 52 O0 45 27 O0 45 6 O0 44 36 O0 44 4 O0 43 43 O0 45 15 8,39 O0 1800 O0 O0 2000 O0 ~,'10,0 o:o h 0 0 E $ 26 50 W N 3 13 E N 18 52 E N 35 5 W N 38 34 W N 55 15 W N 56 2 W N 41 40 W N 38 21 W N 39 43 W N 41 30 W N 43 0 W N N 46 56 W N 47 3 W N 46 26 ~ N 45 44 W N 44 53 W VERTICAl, DOGUEG RECTANGUhAR COORDINATES SECTION SEVERITY NORTH/SOUTH EAST/WEST FEET DEG/IO0 FEET FEET 0.00 0.00 O, 0,32 0 59 46.01 147 88 498 06 2939 00 2800 O0 47 43 N 43 59 W 585,7 N 43 13 ~ 68 N 44 H 8 N 44 1 ~ 1000,62 N 44 6 W ilO1, N 44 11 W 1200,84 N 44 19 W 1298,5'8 N 44 11 W 1394,46 N 44 29 W 1491 N 44 32 W 1596 12 N 44 43 W N 45 1.8 W 1947 22 N 45 IW 2065 $ N 44 58 W 84 N 44 56 W 2407 68 N 44 56 ~ 2517 43 N 45 4 ~ 2625~41 O0 310o O0 3200 O0 33o0 O0 3400 O0 3500 O0 3600 O0 , oo O0 49 54 O0 49 32 O0 49 7 O0 48 32 O0 47 57 O0 47 27 O0 47 3 19 3839,00 3700 0 O0 0,00 0,42 0.10 0,08 0,16 0,75 3,62 I. 4 21 3 47 2 96 2 90 24 1 98 3 5 4 22 3 0 0 23 0 68 0 O0 N 0 O0 N 0 12 N 0 36 N 0 51 N 0 73 N .1,15 N 2,55 N 8,08 N 18,74 N o O0 g 0 O0 E 0 02 W 0 05 E 0 04 E 0 14 W 0 57 W 2 95 W 9 34 67 N 55 81 110 143 180 219 257 301 353 30 61 W 03 N 99 22 N 133 26 N 81 a 2 4 53 N O0 N 35! 46 25 N 41 26 w ~ 249 51 W 362 92 ~ 425 99 W 496 9 W 27 N 44 37 W 29 N 44 50 W 51 N 44 55 N 415 47 N 4 489 94 N 483 716 789 860 930 999 1068 ~4 N 6 46 N 700 18 N 770 48 N 840 58 N 908 N 975 1,82 1143 37 N 1116 84 W 1598 32 N 44 19 W 0,10 1557 1717 1795 1871 N 1365 68 N 1531 50 N 1612 56 N 169 28 N 17618 68 ~ 1845 O0 ~ 1712 42 W 1830 w 1949 ~ W 2068 24 w 2184 10 W 2298 33 W 2410 95 W 2520 38 ~ 2628 67 N 44 72 N 28 N N 44 5 W , ARCO ALASKA~ INC ,.~ ,~hoPg, ALASKA TRUE #~:ASURED VERTICAl., DEPTH DEPTH COMPUTATION DATE: 19-SEPT-84 DATE OF 6URVE¥I 28-AUG-84 KELLY BUSHING ELEVATION{ X39eO0 ET' ENGINEER{ G. JOHNSON INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGI. EG RECTANGULAR COORDINATES H SECTION SEVERITY NORTH/SOUTH EAST/WEST FEET bEG/ZOO FEET FEET FE VER?IC~ DEPT~ 5026, 47 3939.00 3800 41 O0 4000 oo 4439,00 4300 5893,54 4539,00 4400 ~049.21 4639.00 4500 6204.05 4739,00 4600 O0 49~2} 635T.74 4839.00 4700 O0 49 COURSE .~m%TION AZIMUTH .~IN DEG MIN N 45 ] W ,19 ., ~ N 44 41 W 2940.43 . 44 3 . {041.5~ N 44 21W ]243 .50 N 43 19 W 3356,91 N 42 30 W 3475.81 N 41 12 W 3593,53 N 40 29 W 3709,5~ 6512 ?0 4939.00 4800.00 49 55 i~l~ ~ 5039,00 4900 O0 51 5~ I 5139.00 5000 O0 52 oo oo oo oo oo ,.oo oo ,= O0 5800 O0 44 24 O0 5900 O0 42 52 O0 6000 O0 40 58 O0 6100 O0 40 7 O0 39 N 38 2 W 3626 62 N 44 24 W 4075,53 N 46 4 W 420Z,93 N 47 8 W 4322,52 N 47 41 W 4442,45 N 50 28 W 4557.15 N 53 7 W 4664,32 N 53 53 W 4768,78 N 53 53 W 4873,46 N N 47 0 W 5158,35 N 46 25 W 5243'93 N 45 54 W 5326,83 N 45 54 W 5372.24 0,07 0.73 0 o 0 94 2 59 2 45 0 30 0 52 I 68 0 ..'53 I 24 1 58 0 40 1 39 1 O0 I 07 1 63 0 1 ~5 I 63 1 bO 2 O0 0 O0 0 O0 2094 2166 2237 23i1 2393 2480 256B 2656 29 N 2068 35 N 2139 41 U 8O 13 N 2359 63 N 2440 63 N 25!9 71 N 2596 64 W 39 W 77 W 3044 46 W 3460 ' W 2748 73 N 2670 64 W 3832,47 N 44 lO W 2844 13 . 2747 64 ~ }~j,5? N ii 0 W 29]8 09 N 2834 62 W moe~,58 N' 58 W i~ 92 N 2924 65 W 4209,02 N 44 0 W 3332 41 H 3271 91 W 4670'~6 N 44 i~ W 394 55 N 3356 70 W 4773, ) N 44 W 456 59 N 344X 87 W 4877,96 N 44 52 W 32 N 3522 08 W 4977 18 N 3594 45 W 5072 95 N 3660 N 3814 W 5375 63 N 11W 55 N 45 11 W 96 N 45 12 W 351 357~ 3639 3698 3756 3787 ARCO AhASKA~, INC. ARUK N. SLOPg~ ALASKA MARKER TOP UPPER SAND BASF,, UPPER SAND 0 ER SAND TOP bL~WER SAND BASE PBTD ~OTAL, DEPTH COMPUTATION DATEI 19-SEPT-84 II'~'I'ERPUI,,ATSD VALUES [;'OR CHOSSN HURIZON$ .,,:,':~.'~&,.,..,,..,,~,:,~,,M E A S U R E D DEPTH BELOW K B 8141,00 82:t4,00 ~'~?'~..i:~:~,,.'~: 8401. O0 8554.00 · ~ ~,, , ~, ...)4," ..; ¢;~'~,, ,. PAGE DATE OF SURVEYI 28~AUG-84 KELLY BUSHING ELEVATION{ 139~00 FT' ENGINEER{ G, JOHNSON SURFACE O~IGIN: 547' FSL 44' F~L SEC, Il . .~..gE, UM TVD REC?ANGUb ~.;;. ..... . FROM KB SUB-SEA NORTH/~OU WES~ 60 ,67 58~? 67 8~,16 5942 619~,99 625 99 ARCO ALASKA, XNC, 2(;-3 KUPARUK N, SLOPE, A[~ASKA HARK~R TOP UPPER ~AND BASE UPPER SAND OP [,OWER SAND ASE LOWER 8AND PBTD TOTAL DEPTH ¢OHPUTATZON DAT£~ 1g-SEPT-B4 ************ STRAT1GRAPHIC 8141,00 ~ ........ ..~, 8234,00 :~,~:~,,~,~,~', 8401,00 f'INAL WELL LOCATION AT TD; DEPTH TRUE SUB-SEA VERTICAL VERTICAL DEPTtt DEPTH 8644,00 6393,99 6254,99 PAGE DATE OF SURVEYI 28-AUG-B4 KELLY BUSHING gLEVATZONI ENGINEER~ G, JOHNMON SURFACE ORIG1N: 547' FSL 44' FEb SEC. 31:-~ ';'~:" TVD RECTANGOL AR! F.OM K~ SU~-$I~A NORTH/SOUT :~',? 6 g3,99 6254 9g 3787 N'~?i~ ..... flO~IZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 5375,98 N 45 12 W 2G-3 RFT RESULTS Measured 8148 8166 8167 8254 8282 8254 8232 8287 8292 8311 8311 Hydro. 3289 3294 3293 3335 3343 3328 3337 3336 3336 3345 3343 Shut in 2906 3077 3058 3075 3056 3057 3058 SH2/MR 188 ih RECEIVED FEB 2 ~ 1985 Alaska Oil & Gas Cons. Commission Anchorage ARCO OII and Gas Company Well History - Initial Report- Daily Prepare and submit the "Initial R~per~' on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving Inclusive dates only. District Field Alaska lCounty, perish or borough North Slope Borough Lease or Unit . ADL 25656 Title Drill, Complete & Perforate Kuparuk River State Alaska JWell no. 2G-3 Auth. or W.O. no. AFE 901067 Doyon #9 API 50-029-21165 Operator lARGO W.I. ARCO Alaska, Inc. Spudded or W.O. begun IDate IHour IPrior status Spudded 8/09/84 1700 hrs Date and depth as of 8:00 a.m. 8/14/84 The above Is correct 8/10/84 8/11/84 thru 8113/84 · Signature For form pre~ration and/l~strlb-~Jtlo~, see Procedures Manual, ~ctlon 10, Complete record for each day reported 16" @ 105' 1300', (1195'), ND Wt. 9.6+, PV 22, YP 28, PH 8.5, WL 12.4, Sol 8 Accept rig @ 1200 hrs, 8/9/84. NU diverter sys. Spud well @ 1700 hrs, 8/9/84. Drl to 502', Navi-Drl to 1300'. 500', Assumed vertical 685', 3.7°, N45W, 684.87 TVD, 5.97 VS, 4.22N, 4.22W 1013', 14.7°, N43.4W, 1008.56 TVD, 55.56 VS, 40.54N, 38.19W 9-5/8" @ 3240' 6160', (4860'), Drl w/Navi-Drl Wt. 9.3, PV 10, YP 12, PH 9.5, WL 4.8, Sol 6 Drl f/1300'-1465'. Chg to bldg assy. Drl f/1465'-2200', POH. chg to locked assy. Drl f/2200'-3260', short trip (swabbing & tight @ 1675'). Wsh f/1675'-1752', POH, LD BHA. RIH w/81 its, 9-5/8", 36#, J-55 BTC csg. M&P 900 sx PF "E" @ 12.2.ppg, followed by 370 sx PF "C" @ 15.6 ppg. Displ using drlg mud, bump plug. CIP @ 1445 hrs, 8/11/84. Circ 16 bbls good cmt to surf, tst csg w/1500 psi f/15 min; OK. ND diverter sys, NU & tst BOPE; OK. TIH to 3155', tst csg to 1500 psi; OK. DO plugs, FC, firm cmt & FS. Perform 12.5ppg EMW tst; OK. Drl 8½" hole f/3270'-3560'. Navi-Drl f/3560'-5607' and 5910'-6160'. 3868', 49.9°, N44.6W, 3180.93TVD, 1845.56, N1303.19, 1308.75W 4432', 48.4°, N43.9W, 3549.82TVD, 2271.55, N1608.78, 1606.43W 4995', 46.7°, N43.2W, 3929.80TVD, 2686.05, N1909.85, 1892.64W 5530', 44.4°, N45W, 4304.43TVD, 3067.32, N2184.08, 2158.39W 5793', 48.3°, N45W, 4485.93TVD, 3257.43, N2318.62, 2292.92W 9-5/8" @ 3240' 6926', (766'), Drlg w/Navi-Drl Wt. 9.3+, PV 10, YP 5, PH 9.0, WL 6.6, Sol 6 Navi-Drl f/6160'-6926'. 6046', 49.9°, N43.9W, 4651.58 TVD, 3448.41VS, 2455.12N, 2426.83W 6517', 49.9°, N39.7W, 4956.53 TVD, 3805.83 VS, 2721.23N, 2667.64W 6831', 51.8°, N45.3W, 5154.77 TVD, 4048.47 VS, 2900.76N, 2832.15W RECEIVED 56.24% if a W.O. 8/30/84 ITM Drilling Superintendent MAY;2 8 1 8§ -, Alii Alaska Oil & Gas Cons, Commmmon d6 /mnhr_,ra~e - AR(~O Oil and Gas Company ~'~aily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. -1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. r county or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25656 Complete record for each day while drilling or workover in progress 8/15/84 8/16/84 8/17/84 State Alaska IWell no. 2G-3 9-5/8" @ 3240' 7863', (937'), Drlg w/Navi-Drl Wt. 9.4, PV 10, YP 8, PH 9.5, WL 6.6, Sol 7 Navi-Drl & surv 8½" hole to 7863'. 7182', 50.2°, N49.2W, 5375.66 TVD, 4321.25 VS, 3085.92N, 3032.46W 7403', 48.3°, N49.6W, 5519.92 TVD, 4488.56 VS, 3194.87N, 3159.58W 7717', 46.4°, N53.2W, 5732.66 TVD, 4718.93 VS, 3338.95N, 3340.09W 9-5/8" @ 3240' 8264', (401'), RIH w/bit Wt. 10.3, PV 20, YP 15, PH 9.5, WL 6, Sol 11 Drl & surv 8½" hole tp 8264'. 8232', 42', N49-1/2W, 6101.87 TVD, 5077.09VS, 3563.19N, 3620.44W 9-5/8" @ 3240' 8633', (369'), RIH w/RFT Wt. 10.3, PV 19, YP 13, PH 90, WL 5.8, Sol 12 Drl & surv 8½" hole to 8633', short trip, C&C f/logs. rn DIL/SFL/GR/SP/FDC/CNL/CAL f/8624'-3240'. Rn RFT. to cond hole f/csg. RU Schl, RIH w/bit RECEIVED The above is correct Signature For form prepa~tion an'~ ~listr~ution see Procedures Manual Secti(~ 10, Drilling, Pages 86 and 87 IDate r Title 8/30/84 Drilling ARCO Oil and Gas Company Daily Weii"Ristory-Final Report Instructions: Prepare and submit the "Final Reporl" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspen.ded for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Field Lease or Unit I Well no. Kuparuk River ADL 25656 I DS 2G-3 Auth. or W.O. no. Title AFE 901067 Drill, Complete & Perforate Doyon #9 API 50-029-21165 Operator I A.R.Co. W.I. I ARCO Alaska, Inc. Spudded or W.O. begun Date Spudded 8/09/84 Date and depth Complete record for each day reported as of 8:00 a.m. Iotal number of wells (active or inactive) on this, Dst center prior to plugging and / bandonment of this well ~v 056 .24?0 our 1700 hr$ Prior status if a 8118184 thru 8/2o/84 Old TD 0900 hrs { New TD Released rig Oil I Date 7" @ 8637' 8644', (11'), RR 10.3 Brine Drl 8½" hole to 8644', 5 std short trip, C&C, POOH. RU & 4n 221 its, 7", 26#, J-55 BTC csg to 8637'. M&P 380 sx Cl "G" w/l% CFR-2, 5% KC1 & .3% Halad-24. Displ w/10.3 brine, bump plug. CIP @ 0545 hrs, 8/18/84. ND BOPE, NU & tst tree to 3000 psi. RR @ 0900 hrs, 8/18/84. Wait on completion rig. 8644' (8/18/84) 8/18/84 IPBoepth Rotary Single IKind°frig Classifications (oil, Producing method Potenlial test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production ~7',/)O./:.v_ _ ("Or)~ Oil on test Gas per o ~,~ Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and dia~ribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ADDENDUM WELL: 2G-3 11/19/84 11/21/84 FRACTURE STIMULATION SUMMARY Begin Frac Work At: 1256 hrs, 11/19/84. Dowell frac'd Kuparuk "A" sand perf's 8250'-8262' & 8278'-8312' in 7 stages per 11/14/84 procedure using Dowell's YFG)II gelled diesel, 100 mesh & 12-20 sand. Pressured annulus to 1150 psi w/diesel. Tst ins to 5200 psi; OK. 1. Pmp 40 bbls hot diesel w/5% Musol @ 13.5 BPM/4800 psi. 2. Pmp 87 bbls gelled diesel @ 20 BPM/4600 psi (decrease to 3500 psi). 3. Pmp 48 bbls gelled diesel w/2000#, 100 mesh @ 20 BPM/3350 psi. 4. Pmp 90 bbls gelled diesel pad @ 20 BPM/3300 psi. 5. Pmp'd 26 bbls gelled diesel w/2 ppg 12-20 @ 20 BPM/3130 psi. 6. Pmp 41 bbls gelled diesel w/6 ppg, 12-20 @ 20 BPM/3200 psi. 7. Flush w/80 bbls gelled diesel w/added breaker @ 20 BPM @ 3320 psi. Job complete @ 1445 hrs, 11/19/84. Rn temp log f/8430' to 7950' 8451' PBTD Rn 2nd temperature log f/8330'-7950' POOH Secure well Drilling ~uperintendent Su.ggested form to [~ insertcd in each for timely cc. pliance with our ~c~ulations. ' '' ope-rator,'we~ ~ame and Number · _Required Date Received Remarks -- . . , , Cc~p le tion Report ' Yes · ~ ....... / - \ -- , , , , , , , ~re ~ips '' . Core. ~scrlp~on ~~ ~ _ ,~___.. ", ~ , ..... . ..~"~"~°~. · ~~ ,~ ~~. . . , Directional ~ey .Ye3-'H ., · ' ~~ b~ .... ~ . . . , . , $" Wt. ARCO. Alaska, Inc. Post Office Bk_~!00360 Anc.horage, Alaska 99510-0360 Telephone· 907 276 1215 LT4 · . ['j 'f' ]i :'-;' r.', T ;I; ,.. r'..'r' ]: ,..'...' -..' ~ r.) 'r ]: ,.-:.: ,..,r. ,.:.':: L: ./!' I B/R i'.) .i.".'.j; ,'/..' r; 'T,' '" ~ .. .~ ~,"'. ~-'TI ."¢. ,_.- ,'",' T ;i' ,? ;-~ -r' T r, .. (!TI.'T ~.: T T () '!" .'[ .!? · ...' : .L ... ,7. f.) 'i" T .. , .i. ~.:- F' ?:: .'fT. · T, ! I :, 1--, ,?-"' ' , ~'-':i'1" C , ~'...r' F F'.,"I".TU];:-'~Zi"~.6, F"C!r:.: F-'F;,'AC ?H ? T.---'::, T Z C ' F'~-:U £OURCE WATEF: WA:-TH . ,~..o ! -% ! :-.: :J r,: E-ILV ' L T-. . .-_. ~ r-,, !--~ F' 'r, ..r:,,t ;' i., ,_. EIPEkl F'. T ,. TU[': z i',!c.;/F:'R E--I:: R ~ C . F'REF' FOR 'C' ."-..-'f:~i",!f)/,:?,'l'ATIC .Bf.-IF.:' . . F'F:EF' F"OF:,' F-"RAC PULL 'r_'.,V' .¢ /' F:,: L,' il F' 17, T;, I ! : £.: 2 F' Z :",! ?--.,' E F: '~ ' '--.' A i'-.~ ['., ~.. 'C'$AND/,?TATIC ]EII-IF'(!N]:T:[AI_) ARCO Alaska, _Inc..is a Subsidiary of Allan? ,:RichfieldCompany ARCO Alaska, Inr Post office-.-z-_ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4925 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 return one signed copy of this transmittal. BHP REPORTS & SEQUENCE OF EVENTS 2B-lw'> 10/16/84' "Static" SBHP 2B-l~~- 10/17/84 " " 2B-2~ ...... 10/17/84 " " 2B-6~- .... - 6/02/84 " 2B-10~ 6/02/84 " 2B-11~ 6/03/84 " 2B-12NJ 6/02/84 " 2B-14~-- 10/28/84 " " 2B-13y-,~ 10/28/84 " " 2D-5.A ~ 10/05/84~ " "' 2G-l~ 9/21/84 "Static/G. Ring" 2G-2 * '-~ 9/22/84 " " 2G-3 ~ 9/23/84 " " 2G-4 ~ 9/23/84 " " 2G-8 %-- 9/30/84 2F-15~ 4/13/84 2X-13~- 12/18/84 2X-14~ 12/21/84 2X-15 ~. -~ 12/23/84 2X-16)'~'12/21/84 "St~tic/C. Ring/Tag;' SBHP Receipt Acknowledged: 1B-3 ~ ?' ~/26/84 1B-4~"?.~,~6/26/84 · · lB-6 Y ~ .... 7/01/84 1E-2 ~ 6/22/84 1E-7 % ?~/14/84 1E-4 ~-- 10/15/84 1E-12~,~- 6/24/84" 1E-20~-- 6/23,22/84 1E-22f~-4/23/84 1E-25g,~ 6/23/84 1E-25~ 11/09/84 1E-29·~ ...... 6/23/84 1E-29} 10/14/84 1F-4 ~- 9/14/84 1F-4 ~ .... 9/14/84 1F-7-x .... 7/05/84 1F-11~-'" 4~25/84 1F-14~ ?' 2/07/84 1F-15%~ 2/14/84 1G-1.~? 6/29/84 ¢iG-i~ ~ 9/13/84 /1G-3'.~ ~: 5/16/84 vlG-5,~ 6/29/84 1H-4~ 6/24/84 ZY-3~- 1/21/84 1Y-5~ 5/06/84 1Y-9~'- 5/06/84 1G-14.--' 1/12/84 1L-2~-~ 10/21/84 iL-3 '~-~- Date: SBHP "Static" "Static" B. Currier BPAE Chevron D&M DISTRIBUTION Drilling W, Pasher Geology G. Phillips Mobil Phillips Oil NSK Ops. J. Rathmell "Static" ,, ,, ,, ,, ,, ,, i~cat State of~AK Sohio :~, Union :'~.. Well Files ARCO Alaska, Inc. : - "~.'-~ £.-' · - - :.:; ::. Z~...~:~ 9~51[: ', :,. ;.~:cr, c ~,7 277 5C37 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk AT0-1115B P.O. Box 100360 Anchorage, AK 99510 Transmittal No: 4786 PAGE 1 of 2 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 0H FINALS Schl~er /2G-3 2"/5" DIL-SFL/GR 2"/5" FDC-~L/C~ "R~w" 5"/2" " " ' qPoro" RFr Quicklook CPL Cyberlook 1L-5 /~i~,, 2"/_g'~' FDC-CNL/GR "Porn" 2"/5" " ""Raw" CPL Cyberlo0k . 8/17/84 Run 1 5240 - 859C 8/16/84 " 7950 - 8578 8/16/84 " 7950 - 8578 8/16/84 " 8148 - 8311 8/16/84 " 8148 - 8311 S/16/84_ " ( 79 - 8580 _ ,~..,,~...,- 7750 8/06/84 " 2323- 7750 8/06/84 " 2323- 7750 8106184 " 7750- 7100 8/o6/84 ', 7-3o6- 75o6 7306 2"/5" DIL-SFL/~ 8/14/84 Run 1 ' 2"/5" Density Neutron Raw 8/14/84 " 2"/5" " "Poro 8/14/84 " CPL Cyberlook 8/14/84_ ' 3162 - 8419 3162 - 8395 3162 -8419 7°_/30 - 8350 RECEIVED Alaska Oil & 6as Cot'~s. Commission Anchorage ARCO Alaska. Inc. · ' '.,'::~ .'- ~'~¢"-:k:~ 99510 ~-~ ', ~,. ;-~,c,r,c 9-[,7 ~77 5~37 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/~/~84 Transmittal No: 478~ PAGE2 of 2 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 20-2 /2--~,, DIL-SFL/~ 2"/5" FDC-CNL/GR "Poro" 2"/5" " ""Raw" CPL Cyberlook 8/08/84 " 6090 - 6570 8/08/84 " 6090 - 6570 8/08/84' " 6090 - 6570 ~ 2D-9 2"/5" DIL-SFL/GR 8/08/84 Run 1 2"/5" Density Neutron Poro 8/08/84 " 2"/5" " " Raw 8/08/84 " CPL Cyberlook 8/09/84 " 3895 - 7834 7250 - 7809 7250 - 7809 7450 - 7710 RECEIVED AlasKa 0it & ~as Cons, Commission Anchorage /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Date: DISTRIBUTION D & M W.V. Pasher G. Phillips Dzilling Geology Phillips Oil Mobil J.J. Rathmell ,N ov. Alaska Oil & Gas/Con'S:--~mmJssJon State of Alaska Sohio Union Chevron R & D Well Files NSK Operations ~_r.~..' /~:a"t;, Ir,~ ,., /,.~.~:,~,~ ~!.~r..:~. , ,. ;.',e:-.c ..-[.,. *-., / 5637 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk AT0-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/18/84 Transmittal No: 4786 PAGE 1 of 2 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 0H FINALS Schlumberger 20-3 2"/5" DIL-SFL/GR 2"/5" FDC-CNL/GR "Raw" 5"/2" " " "Poro" RFr Quicklook CPL Cyberlook 8/17/84 8/16/8~ 8/16/84 8/16/8~ 8/16/84 8/16/84 Run 1 3240 - 8598 " 7950 - 8578 " 7950 - 8578 " 8148 - 8311 " 8148 - 8311 " 79 - 8580 1L-5 2"/5" ) ~'I)CT, CNL/C~,' "Poro" 8/06/84 " 2323- 7750 v '2'~/5'' "Raw" 8/06/84 " 2323- 7750 CPL Cyberlook 8/06/84 " 7750 - 7100 RFT 8/06/84 " 7306- 7506 RFD. Quicklook 8/06/84 " 7306 - 7506 2B-3 2"/5" DIL-SFL/GR 8/14/84 Run 1 3162 - 8419 2"/5" Density Neutron Raw 8/14/84 " 3162 - 8395 2"/5" " "Poro 8/14/84 " 3162 - 8419 CPL Cyberlook 8/14/84 ' 7900 - 83~ - _, / ~'- ~ o - ~-~ . . ~-T_.~~''~ - . ~,~ r- ,-,.. /°= (~'~*~-0 ~ ~ ~-"~-~- -~-.:'-- ' ~ k ~t~o Re ce i p, A/kn~le~ged, ~ z~- ~ ~- ~' -/~'i,~~__~~ Date: .- 0~~'~~ DISTRIBUTION " uons. Commission W ~/ ?asher F.G. Baker P. Baxter BPAE G. Phillips Drilling Mobil J' J' Rathmell State of Alaska Sohio Union Chevron NSK Operations R&D Well Files Return To: ARCO ALASKA, Inc. ATTN: Records Clerk AT0-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/18/84 Transmittal No: 4786 PAGE 2 of 2 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal° 20-2 2"/5" DIL-SFL/GR .A 2"/5" FDC-CNL/GR "Pore" - \ 2"/5" " ""Raw" CPL Cyberlook 8/06/C~ Run 1 C.090- 2717 8/08/84. " 6090 - 6570 8/08/84 " 6090 - 6570 8/08/84 " 6090 - 6570 2D-9 ~-~' DIL-S~'~/G~ 8/08/84 l~ 1 <'75"!)ensity Neutron Pore 8/08/84 " " 8/08/84 " CPI, Cyberlook 8/09/84 " 3895 - 7834 7250 - 7809 7250 - 7809 7450 - 7710' /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R & D Alaska Oil & Gas Cons. co~'~Jssion Anchorage C. Re Smith State of Alaska Sohio Union Well Files ARCO Alaska, '" . . ,. : -. '' '.C:.'~ Date: 1.0./~84 Transmittal No: 4765 Return To: · . ARco ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 / Anchorage, AK 99510 ~/ aTnr;n;melut t~dohn:r:~, i~ehdacr:p;h:f f ~il:w~gan~mt %~1' Please acknowledge receipt CBL' s FINALS/Schlumberger 2V-8A "Variable Density" "GCT" 8/01/84 Run 1 7400 - 8909 2G-1 " " " 8/27/84 " 5151 - 7991 2G-2 "- " " " · / 2G-3 " " " 8/27/84 " __ 8/27/84 ~" 4275 - 6536 5950 - 8526 2G-4 " " " 8/27/84 " 5070- 7650 2G-8 " " " 7/31/84 " 6500- 7830 2H-13 " " " " 2H- / " " " 7/30/84 " 7/30/84 " 6100 - 7720 7200- 8732 7130/84 " 6100- 7422 2H-16 . " " " . · 2D-11 '-' " " " . 2D-9 ~'~ " " " 2D-12 ~ " " '" 2D-10 - " " " Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE 7/30/84 " 8/25/84 " 8/25/84 " 8/25/84 " 8/25/84 " DISTRIBUTION D&M W.V. Pasher G. Phillips Drilling ~ Phillips Oil Geology .--,--v,, . Mobil 3.3. Rathmell 7000- 8410. 5900- 7588 6700- 7768 6900 - 8486 ~' ~f' ~ ~ Date: ~: ~ ~--~ . C. R. Smith S t a t e,:jof ~:A1 Sohio Union Chevron NSK Operations Well Files ARCO Alaska, InL Pc,_~.~ Ofl~ce'~'~ox' 36(3 Anchorage. Alaska 99510 Telephone 907 '277 5637 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 9J12/84 Transmittal No: 4721 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. TAPES/Schlumberger GCT #69416 Run 1 GCT #69417 " 7/31/84 54 - 7754 8/01/84 33.5 - 8910 OH LIS #69467 " 8/17/84 3227 - 8640 2G-3 -~ OH LIS #69467 " " RFT " Receipt Acknowledged: Date: DISTRIBUTION B. Adams D & M W.V. Pasher G. Phillips F.G. Baker Drilling Phillips Oil P. Baxter Geology BPAE Mobil J.J. Rathmell ~C. R. Smith~ ' State of Alaska Sohio Union Chevron NSK Operations R&D Well Files ARCO Alaska, I. Post Offic'L~Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 14, 1984 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: 2G-2 1L-5 2D-9 2B-3 2G-3 1L-6 2D-8 2B-2 2G-4 1L-7 2D-7 2B-1 Thank you. Sincerely, Area Drilling Engineer JBK: ih L01 06/28/84 Enclosures RECEIVED SEP ! 9 I984 Naska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK>~OI L AND GAS CONSERVATION ~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS !1. Drilling well ~[X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-139 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21165 548' FSL, 44' FEL, Sec. 31, TllN, R9E, UM 4. Location of Well atsurface 5. Elevation in feet (indicate KB, DF, etc.) Pad 104, RKB 140 I6. Lease Designation and Serial No. ADL 25656 ALK 2582 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2G-3 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. August ,19__84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud well @ 1700 hrs 08/09/84. Drld 12-1/4" hole to 3260'. Ran, cmtd & tstd 9-5/8" csg. Drld 8~" hole to 8633'. Ran logs. Ran RFT. Drld 8~" hole to 8644'TD as of 8/18/84. Ran, cmtd & tstd 7" csg. Secured well and released rig @0900 hrs, 8/18/84. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8" 36~I J-55 BTC csg w/shoe @ 3240' cmtd w/900 sxs PF "E" & 370 sxs PF "C". 7" 26~/ J-55 BTC csg w/shoe @8637'. Cmtd w/380 sxs class "G". 14~lgjp~ng resume and brief description 15D~S/~,"~t~~CNL/CAL f/8624' to 3240' SEE RFT RESULTS RECEIVED SEP ! 9 19 4 6~f)/~f data, perforating data, shows of H2S, miscellaneous data Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. --/~~r//~¢"~'---,, --,~- -- Drilling Engineer SIGNED TITLE.Area DATE NOTE--Repg~ °n~th/~s f/orm is rgquired for each calendar month, regardless of the status of operations, and must be ed i~l duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate 2G-3 RFT RESULTS Measured Dept. 8148 8166 8167 8254 8282 8254 8232 8287 8292 8311 8311 Hydro. Press 3289 3294 3293 3335 3343 3328 3337 3336 3336 3345 3343 Shut in Press 2906 3077 3058 3075 3056 3057 3058 SH2/MR 188 ih RECEIVED SEP ! 9 1984 Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska, In Pc.:: Ol;;:'?"-t-"'~ 360 Anchorage.-. Alaska 99510 Te!¢.;::.hon( 907-277 5637 Re~urn To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 9J12/84 Transmittal No: 4721 Transmitted herewith are the following items. Please acknowledge.receipt and return one signed copy of this transmittal. TAP ES / S c hlum berg er ~"~CT #69416 Run 1 7/31/84 54 - 7754 2H-13 /GcT ,~69417 " 8/01/84 33.5 - 8910 -2V-SA ?~H LIS #69467 " · ~0H ' LIS #69467 " H LIS #69325 . ~~H LIS #69325 " " 8/17/84 I! Run 2 6/25/84 3227 - 8640 2G-3 RFT " DDBHC/GTM~.,. ..... ~ .... -. I,./_: ~ DITD/SGTE/LDT " %/ ":'~ ~- CNL/EPT/PCD~' / . Receipt Acknowledged: oi% SEP 1 4 Ataska Oil & Gas Cons. Commission_ AnChorage SEP: ] ,---. :-! ' B. Adams D & N DISTRIBUTION W.V. Pasher C. ~. Smith F.G. Baker P. Baxter BPAE Dz tlling Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska Sohio Union R&.D Well Files Chevron NSK Operations ARCO Alaskz .. ;-:.-O',.,~_. E,.:,> 360 Anchorap~-. Alaska 99510 Tei.,cFhon( 907 277 5637 Date: 9_/12/84 Transmittal No: 4721 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 / Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. TAPES / Schlumberger ~GCT #69416 Run 1 GCT #69417 " ~OH LIS #69467 " OH LIS #69467 " 7/31/84 8/o]./84 8/17/84 g! 0~O~~ LIS #69325 LIS #69325 Run 2 6/25/84 !! 33.5 - 8910 2V-8A/ 3227 - 8640 2G-3/-j' ,, /' RFT DITD/SG~E/~f ." / ~ CNL/EPT/PCD/LSS/GR / Receipt AcknoWledged: Date: DISTRIBUTION B. 'Adams W.¥. Pasher C. R. Smith F.G Baker Drilling G. Phillips State=~f:Alaska_ Phillips Oil Sohio P. Baxter Geology J.J. Rathmell Union R & D Well Files BPAE Mobil NSK Operations Chevron ARCO Alaska,: Post Ofhc~i'~'~e ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 21, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2G Pad, Wells 1-4 Dear Elaine: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU8/LI08 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany SEC 31 SEC 6 NOT TO SCALE 32 TIIN TION LOCATION SCALE' I MAP II = I MILE D.S. 2-G SEC32 TIIN T 10N SEC 5 DRi SITE 2. G CONDUCTORS AS. BUILT LOCATIONS LOCATED IN T II N, R9E,SEC, 31,UMIAT MER.. WELL NO. I EL. 102.90', O.G. 98.8' Y =5944015.121 LAT. 70°15'29.7334'' X = 508 649.964 LONG. 149°55'48.314" 45' FEL 427' FSL WELL NO. 2 EL. 102.73', O.G. 98.6' Y: 5 944075.037 LAT. 70015'30.3228'' X-- 508 649.9920 LONG. 149°55'48.311" 44' FEL 487 FSL WELL NO. 3 Y = 5 944 135.052 X -- 508649.9700 I 44 FEL EL 102 51' ' · . , O.G. 99.0 LAT. 70015' 30.9131" LONG. 149°55'48.310" 547' FS L WELL NO. 4 Y: 5 944 195.029 X: 508 649.9880 44' FEL EL. 102.10', 0.G.'99.2' LAT. 70° 15'31.5030" LONG. 149o55'48.307" 607' FSL ~'~,""."" ^'"'.;~'i,' '~ ......... , ........ : ........... ~ NEW,dY CERTIFY THAT i AM PROPERLY REGISTERED ~ L',CENSES: TO PRACT;CE LAND SURVEYING IN TNE STATE OF ALASKA 5 THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DiRFCT SUPERVISION ~ THAT ALL DETAILS ARE CORRECT AS OF 7/~1/84. ~ IDate: JULY 26, 1984 imm I i i ARCO Aioska, inc. Kuparu~ Project North Slope Drilling DRILL SITE. 2. G CONDUCTOR AS. BUILT LOCATIONS WELLG I - 4 Scale; AS NOTED Owg. no.: NSK 9.05.207~ · . THRU.; Lonnie C. Smith Commissioner MEMORANDUM ALASK OIL A~ID GAS coNSERVATION COMMISSION ,o- C. t terton DA*E: August F,LE NO: D. 2I. 26 TELEPHONE NO: Sta e of Alaska 13, 1984 FROM: Harold R. Hawkins .~/~y~ SUBJECT: Petroleum InspectorshiP' Witness BOPE Test ARCO Alaska, Inc, 2G-3, Kuparuk River Unit, Sec. 31, TllN,R9E,b~, Permit No. 84-139. Saturday,..August 11, 19.84: I left 1L-6 location (subject of another report) t° ARCO's 2G-3, Kuparuk River Unit to witness another BOPE test, and witness the mud control systems. I witnessed the'BOPE tests and control systems with no failures. I filled out an AOGCC report which is attached. In summary, I Witnessed the BOPE tests and mud control systems that Doyon 9 performed and found the BOPE's and mud control systems were satisfactory. Attachment 02-00IA(Rev. 10!79) O&G #4 5/$4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Well Operator /~.~ ~ ,~_~~ Location: Sec~/ TdA/ R~gM Drilling Contractor ~~A/ Ri~ Location, General ~ ~ /Well Sign General Housekeeping ~/~ Rig Reserve Pit Mud Systems Trip Tank Pit.Gauge Flow Monitor Gas Detectors Visual Audio BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures Representative Permit # 'Set ACCUMULATOR SYSTEM Full Charge Pressure ..~ ~ psi~ -- v Pressure After Closure ]?~ psig Pump incr. clos. pres. 200 psig~ Full Charge Pressure Attained: / ~ N2 Controls/.. Master ~4 / Remote ~ Blinds switch cover Kelly and Floor Safety Valves rain ~-) ~ec. rain ~_/~ sec. Upper Kelly. Test Pressure ~ Lower Kelly. Test Pressure Ball Type Test Pressure Inside BOP Test Pressure Choke Manifold Test Pressure No. Valves /f V/ No. flanges~ Adjustable Chokes _.~.~ ~ Hydrauically operated choke Test Time / hrs. .-_'~ Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor August 8, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~nchorage, Alaska 99510-0360 Re: Kuparuk ~civer Unit 2G-3 ~RCO Alaska, %nc. Permit No. 84-139 Sur.'Loc. 548'FSL, 44'FEL, Sec. 31, TI!N, R9E, U~. Btmhole Loc. l155'F~L, I075'F~L, Sec. 31, TllN, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous direct~ona! survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. M~ny rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations ~n~__~ ~hese_ 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 the Habitat Coordinator's Office, Department of Fish and Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 'hours prior to comm~encing installation of the blowout prevention t ~%r, Jeffrey B, Ket~i~ Kuparuk River Unit 2G-3 August 8, !984 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 Commission 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 ~tness present. Very truly yours, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COmmISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o enc!. ARCO Alaska, Inc. ~ Post Office B,... 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 July 30, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2G-3 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2G-3, along with a $100 application fee Diagrams 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 ° A diagram and description of the BOP equipment Since we estimate spudding this well on August 8, 1984, your earliest apprqYal will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/JG/tw GRU8/L74 Attachments RECEIVED oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA U~L AND GAS CONSERVATION CO,v~MISSION PERMIT TO DRILL DRILL REDRILL DEEPEN 2O AAC 25.0O5 EXPLORATORY [] SERVICE [] ~.RATIGRAP~ DEVELOPMENT OIL [~X SINGLE ZONE IX-X ~ DEVELOPMENT GAS [] MULTIPLE ZONE [] ~ 9. Unit or lease name River Unit Kuparuk 1 b. Type of well 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 548' FSL, 44' FEL, Sec.31, T11N, R9E, UM At top of proposed producing interval 1388' FNL, 1328' FWL, Sec. 31, TllN, RgE, UM At total depth 1155' FNL, 1075' FWL, Sec. 31, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 140', PAD 104' 6. Lease designation and serial no. ADL 25656 ALK 2582 10. Well number 26-3 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 15. Distance to nearest drilling or completed 26-2 well 60' ~ surface feet 18. Approximate spud date 08/0~/84 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi, NW of Deadhorse miles 548 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8547' MD, 6390' TVD feet 2491 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLEANGLE46,10l(see2OAAC25.035 (c) (2) 2774 psig@ 80°F Surface , 3185 psig@ 6251 ft. TD (TVD) 121 Proposed Casing, Liner and Cementing Program I i SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT i~- Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) i24" 16" 62.5# H-40 Weld 80' 36' I 36' 1161 116' ± 200 cf ' I 35' 3294'I 2748' 620 sx Permafrost E & 12-1/4" 9-5/8" 36.0# J-55 BTC 3259' 35' I HF-ERW ~ I 370 sx Permafrost C 8-1/2" 7" 26.0# J-55 BTC 8514' 33' II 33' 8547'1 6390' 310 sx Class "G" [ HF-ERW I I ~ I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8547' MD (6390' TV•). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole, The 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 2774 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 26-3 will be 60' away from 26-2 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the'7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruption in the disposal process. (see attached sheet) -23. I hereby certify that the foregoing is true and correct to the best of my knowledge Samples required I--lYES Permit number APPROVED BY Form 10401 GRU8/PD40 Mud log required [--]YES ~.NO Approval date ?~,__) ~0~//.08/~ CONDITIONS OF APPROVAL Directional Survey required J~Y ES •NO I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE August 8, 1984 by order of the Commission Submit in triplicate PERMIT TO DRILL 2G-3 The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED JUL ~ 11~ Alaska Oil & Gas Cons. Commission Anchorage . . J - ANNUL.A,q, PIPF. ~ BLIND ' RAM~ ORILLII SPOOL 6 PIPE RAMS q ' CSt; 2 DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head Z. 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 5. 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 g. 13-5/8" -.5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL Will4 HYDRAULIC Ft. UID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITl~ 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WIT14 CHARGING PUMP OFF. 4. RECORD ON NAJ)C 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 AND MANIFOLD WITH ARCTIC DIESEL· 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHE~J3. RUN IN LOCK DOWN SCREWS IN HEJ~J3. 3. CLOSE ANNULAR PREVEN"FER AND ~21J~'Vl~S ]J'PS~ OF CHO~S. DON~T TEST AGAINST CLOSED CFDKE S · AND HOLD'FOR 10 4 TEST ALL COMPONENTS TO 250 PSI MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PiPE RAMS· 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR I0 B. DOW _nm OF CHOK ISOLA?TON ~FAL¥'J~S, TO ZERO PSI TO TEST VALVES. TEST REPLAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTRF.~uM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP sE'r OF PIPE RAJ4S AND CLOSE BOTTOM SET OF P I PE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE Pu~J4S. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAJ4S AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED' TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MUkNIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SE'F 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 FUNC- J U L 3 1 i984 Alaska Oil & Gas Cons. Commission Anchorage Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/lC" side outlets. 5. lC" ball valves, hydraulically actuated, w/lC" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify 6hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. 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. 16" Conductor RECEIVED JUL ]. 1984 Alaska Oil & (]as Cons. Commission Anchorage .ITEMT~ APPROVE :DATE-~ (1) Fee Admin (3) , ~) (10 and 11) (12 thru 20) ( 5 ) BOP E X~-~ ~'/-~. ~ (21 thru 24) (6) Add: · . . 2. IS 3. 4. 5. 6. 7. 8. , ,',,. ,. YES NO ,- . attached ' :~""",~- the permit fee ' · ee®eeeeeeeel~ee~ee®e®eeeeeeeeeleeeeeleele ~ell to be~located in a defined pool ............................ ' Is well located' proper distance from property line ................... Is well located proper distance from other wells ................... Is sufficient undedica~ed acreage available in this pool~. ......... · Is well to be deviated and is well bore plat included ............. ' ' Is operator the only affected party ............................... · . Can permit be approved before ten-day wait .......................... e I0. i1. Does operator have a bond in force .................................. Is a .conservation order needed ...................................... REMARKS': :',.,':i' ' Is administrative approval needed ................................... 12. 13. 14. ~15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Is conductor string provided ................................... Is enough cement used to circulate on co~du;to~ a~d'surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ~ .............. ,. Will surface casing protect fresh water zones .... '.~...' .......... Will all casing.give adequate safety in collapse, tension and burst... Is this well to be kicked off from an existing wellbore .............. Is .old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... Are.necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ,~~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .............. · .... 25. Additional requirements ............................................. ~j~/~ ___ Additional Remarks: ~A-~ ~--~ ~4~IA~ ~ g~5"~C~ ~P-~-~ ~Z)f~7 ~L}~~ I-4 Geology: Enginp~rin~: HWK~ LCS~BEW ~ WVA ~ JKT ~ rev: 12/08/83 6. CKLT ~NiT~AL GEO. UNIT ON/OFF POOL CLASS STATUSI AREA NO. SHORE Vi"/" 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. V ERIP"IC,~T I[3N bV'P OIO,H02 YEiRIFICA'I'.IOli i~ISTING PAGE 1 LVP 010,~02 VERIFICATION LISTING PAGE 2 ** REEf, HEADER SERV!CE NAME :RFT DATE ORIG!~ :CSU CONI'!I~UATION # :01 PREVIOUS RE~L COMMENTS :SCHL{IMBERGE~ ~Ebh SERVICES CI)STOMER FIELD TAPE ** TAPE HEADER ** SERVICE NAME :RFT DATE :84/08/17 ORIGIN :C6U TAPE NAME :+++++~++ CONTINIIATION ~ :01 PREVIOUS TAPE : COMMVNT$ :SC~L[.IMBERGER ~LL SERVIC~6 CUSTO~E~ FIFbD TAPE EOF ** FILE MEADER FILE N~ME :RFT ,O01 SERVICE MA~E :LOG VERSION # : 26,~ DATE MAXIMUM LENGTH ~1024 FILE TYPE PRE¥IO~)S FThE ** FILM TRAILER FILE ~AMM :RFT .001 SERVICE NAME :LOG VERSION DATE :~3/11/17 ~AXI~U~ LENGTH :1024 FILE TYPE :CR NEXT FILM NA~E ** F~LE HEADER FILE N~'E :RET ,002 SERVIC~'I AME :CALiBR VERSION ~ ; 26.2 DATE :83111/17 MAX%~U~ LENGTH :1024 FILE TYP~ :CR PREVI~JUS FILE LVP OlO.H02 VERIFICATION LISTING PAGE ** FILE TRAILER FILE NA~'~E :Rf'T .002 SERVICE NAME :CALIB~ VERSIO~ ~ : 26,2 DATE :83/11/17 MA×I~U~ LENGTH :1024 FILE TYPE NEX~ f'ILE ~A~E : ** ~"IbE HEADER FILE Na~E :RFT 003 8ERVIC~ NAM~ DATE :83/11/17 NAXI~U~ [,~NGTH :1024 FILE ~YPE :C~ PREVIOUS FIL~ ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE I 1 ~6 0 2 I ~6 0 3 2 79 34 4 1 66 255 5 I 66 O 6 4 73 7 4 05 INCH 8 4 '73 12 ~I I 66 29 1~ 1 66 1 14 4 b5 ,lin lb I 66 73 16 1 66 o I 66 0 DATU~ SPECIFICATION RbOCK6 MNEM S~RvIcE SERVICE UNIT APl AP1 AP~ API FiLE SIZE 8PL REPR ID ORDER ~ LOG '£YPE CLASS MOD NO, TOID RFT S 98 000 O0 0 3 4 ETI~ RyT S 98 636 21 0 3 4 TENS RFT LS 98 635 21 0 3 2 MSPE RFT RPS q8 970 Ol 0 3 2 SGP ~FT P~IG 98 814 O0 0 ] 4 PRE6 RFT PSIG 98 814 O0 0 3 ~ RPRE DFT PSIG g8 814 O0 0 3 2 PDIO RfT 9~ ~14 Ou U 3 ~ PD~O DFT 98 $14 O0 0 3 2 POH~ ~FT 98 ~14 O0 o 3 2 PROCESS CODE (OCTAL) 73 0410000000000~ 68 04000o00000000 49 04000000000000 49 04000000000000 68 04100000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 0420000000u000 bVP OiO,H02 VERIFICATX[)N LISTING PAGE 4 PTEN RFT 98 814 O0 0 3 2 PBUN ~FT 98 814 O0 0 3 2 PTHO RFT 98 814 O0 0 3 2 GR RFT GAPI q8 310 O0 0 3 ~ 1 49 04200000000000 I 49 04200000000000 1 49 04200000000000 1 49 04000000000000 ENTRY BLOCKS TYPE $IZ~ REPH CODE 2 1 96 0 3 2 79 34 4 i 66 255 5 ~ ~6 0 6 4 73 311 7 4 65 INCH ~ 4 73 ~2 9 4 ~5 11 1 ~6 29 13 1 66 ~4 4 65 ,lin 15 1 ~6 73 ~6 1 66 1 0 1 ~6 0 DATUM SPECIFICATION BbOCK6 ~NEM SERVICE SERVICE UNIT APl API APl AP1 FILE SlZk 5Ph [{EPR ID ORDER ~ bOG TYPE CLASS TOD ~FT S 98 000 O0 ETIM R~T S 98 636 21 TEN~ RFT l,b 98 635 21 ~SPE Rf'T RPS 98 9'70 O1 SGP RFm P$1G 98 814 O0 PRES RFT P.$1G 98 814 O0 RPRE RFT P6IG q~ 814 O0 PO10 RFT 98 814 O0 PO20 RFT 98 814 O0 PONE ~FT 08 814 O0 PT~ RFT 98 814 O0 PMUN RE~ 98 ~.14 O0 PTWO RFT g8 81~ O0 GR RFT GAP1 98 310 O0 PROCESS CODE (OCTAL) 73 04100000000000 68 04O00000000000 49 04000000000000 49 04000000000000 68 04100000000000 49 040000000000~0 49 040000000000 0 49 04000000000000 49 04000000000000 49 04200()00000000 49 04200000000000 49 04200000000000 49 04200000000000 49 04000000000000 ** DATA TOD 46022400 ETIM SGP 3~65,0000 PRE~ PD~O 0,0679 PONE PTHU 3.0000 GR FEET MgTER8 o5510,1016 19967,4785 0,3~00 TENS 2844,0000 M~PE 3204~0000 RPRP.: 320410000 PDlO 5:~0000 P[~5 6,0000 PRUN 268.0000 ******** UEFTH 7g,0625 .0659 2.0000 VERIFICATION LISTING PAGE TOD 4.~022640 ETIM SOP 3278,00(.)0 PRE6 PD2O 0,0o69 PONE PTHU 3°0000 GR 65588.1016 19991.2539 230.6999 TENS 755.000U ~PE 3216,0000 RPR~ 3216,0000 Pbl0 8.0000 PTE~ 7.0000 PttUN 69.8125 FILE NAME :RFT .003 VERSIO~ # ; 26.2 DATE NAXiNU~ LENGTH FILE TYPE NE×~ FILE NA~E FII, E NA~E :RKT SERVICE NA~E :LOG VERSION ~ : 26,2 DATE :~3/11/~7 FILE TYPE PREVIOUS f'ILE : 19,0938 0,0654 2,0000 $* DATa FORMAT RECORD ENTRY BLOCKS TYPE SIZ~ REP[{ CODE I I b6 0 2 1 66 0 3 2 79 4 1 b6 255 5 i 66 0 6 4 '73 7 4 65 INCH 8 4 73 12 9 4 65 ,lin 11 1 66 29 ~4 4 ~5 ,lin 15 i 06 73 DATUM S['ECIFICATION BbOCKM MNEM 6KR¥1CE ~:~E}{VIC}S Ut~IT AP1 API APl API FILl:2 SiZE 6Pb ['~KPR PROCESS iD ORDER ~ hOG TYPE CbASS MOD NO. 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DATE :83/11/17 ~{AXIMUN LENGT~ ;1u24 FILE TY~E :CR NEXT FILE NA~E ** ~'ILE HEADER FILE NAME :RFT .007 SERVICE NA~E :LOG VERSION ~ : 26.2 DATE :83/11/~7 MAXIMUM LENGTS ;1024 FILE TYPE :ER PREVIOUS FIL~ ** DAfA FORMAT RECORD *~ ENTRY BLOCKS TYPE SIZE REPK CODE ENTRY 1 1 66 0 2 1 06 0 3 2 79 34 ~ i 66 255 5 1 66 0 b 4 7 3 31,1 7 4 65 INCH ~ 4 73 12 9 4 65 .lin 11 I 66 29 1,4 4 65 ,lin 15 1 06 73 16 I 06 1 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEh SFRVICE ,,SERVICE U.NIT API AMI APl API FiLE SIZE SPb REPR PROCESS ID ORDER ~ BOG TYPE C[,,ASS MOD NO. CODE (OCTAL) TOD R~T $ 98 000 00 u 7 4 I 73 04100000000000 ETIM RFT S Q8 636 21 0 7 4 1 68 0400000000000:0 TEN~ R~,. lB 98 635 ~1 0 7 2 I 49 04000000000000 MSPE RFT RPS 98 970 O1 0 7 2 I 49 04000000000:000 SGP RFT PSIG 9~ 814 O0 U 7 4 ~ 6~ 04100000000000 PRES ~F'T PSIG 98 ~14 O0 0 7 2 i 49 04000000000000 LYP OlO,H02 YER1VICATIOm LISTING PAGE 9 RPRE RFT PSIG 98 8i4 O0 0 7 2 PDIO RFT 98 814 O0 0 7 2 PD20 R~'T 98 814 O0 0 7 2 PTKN PFT g8 014 O0 0 7 2 PHUN Pf'T 98 014 O0 0 7 2 PT"U RF't 98 814 oO o 7 2 GR RFT GAPI 98 ]10 O0 0 7 2 I ~9 04000000000000 1 49 04000000000000 1 49 04000000000000 1 q9 04200000000000 1 49 04200000000000 ! 49 04200000000000 1 49 04200000000000 I q9 04000000000000 *~ O~l~ FORMAT MECO~D ENTRY BbOCK$ TYP~ SIZE REPR CODE 1 1 b6 0 2 I 66 O 3 2 79 34 4 1 ~6 255 5 1 66 0 6 4 73 311 7 4 65 I~C~ 8 4 '13 12 9 4 65 ,lin 11 I 66 29 13 I 66 14 4 05 ,lIm 15 1 b6 73 i6 1 66 0 1 66 0 DATUM SP,,CIFIC.ATION BbOCK6 MNEM 5MRV1CE SERVICE IINIT APl APl AP1 AP1 FILE SIZE 5PL REPR ID TOD PFT ETIM RFT TEN6 DF'r 8GP RF'r PRES RFT RPRE ~FT PDIO RFT PD20 ~FT PO~IE ~FT PTEN RFT PHIIN RFT P T H 0 R F T GR PFT PROCESS ORDER # bOG TYPE CheSS MOD hO, CODE (OCTAL) S q8 900 O0 0 7 4 1 73 04100ouo000000 S 98 636 21 0 7 4 I 68 04000000000000 [.,~ 98 63g ~1 0 '7 2 i 49 ~4000000000000 RPS 98 970 O1 0 7 2 1 49 04000000000000 P$IG 98 a!4 O0 0 7 4 I 68 04100000000000 p~ 9~ ~ oo o 7 ~ i ~9 o~oooooooooooo Ps~ ~ ~i~ oo o ? ~ ~ .~9 o~oooooooooooo 9~ ~l~ oo o ? ~ ~ ~9 04000000000000 9~ ~4 o~ o ~ ~ ~ 4~ o~oooooooooooo ,~~4 ooo ~ ~ ~4~ o~ooooooooooo DATA ** TOD SGP 3290,000o PgE6 20,8437 0.0659 5¥P 010.H02 VERIFICATIOi~ L!STING PAGE 10 PD20 0°0069 PONE 4.0000 PTEN PTHO 3.0000 GK 68.6250 7.0000 TOD SGP PD20 46023280 E'fll,i 3284,0000 PREY 0.Ob'19 o0NE 3,0000 GR FEET METER6 65573,8828 19986,9199 18~.7007 TENS 2794.0000 ~5"E 3206 0000 ~,~E 3206.0000 POlO ~:0000~.EN 6.0000 P~UN 65.6250 FILE NAt,~E ;RFT ,007 SERVICE VERSION # : 25,2 DATE :83/11/17 MAXIMUM hENGTH :~0~4 FILE TY~E :CR NEXT FILE NAME ; ** FI~E HEADER FIL~ NAME :RFT ,008 SERVICE NAME :LOG VERSION # DATE :83/11117 MAXI~U~ LENGTH :1024 FILE 3YPK ;CR PREVIOUS 2,0000 20,515~ 0.0669 2,0000 ENTRY TYPE 2 3 4 5 b 9 13 14 ~5 0 SIZE REPR CODE ENTR[ I b6 0 I 06 0 2 79 I 66 255 1 b6 0 4 73 311 4 05 INC~ 4 '73 12 4 65 ,lin I 66 29 1 66 1 4 65 1 b6 73 1 b6 1 1 06 0 DATO~ SPECTFICATIU~ BbOCKS MNEI~ 5Ei{VIC£ SERVICE UNIT AP1 RPI APl At,ii FIbE SIZk; SPb REPR bYP OIO,H02 VERiFiCATiON bISTING PAGE ID OROEg ~ bOG TYPE CbA3S MUD mO. 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GA, PI gB 310 OU 0 8 2 PROCESS CODE (OCTA6) '73 04100000000000 68 04000000000000 ~9 04000000000000 49 04000000000000 68 04100000000000 49 04000000000000 q9 04000000000000 49 04003000000000 ~9 04000000000000 49 04200000000000 49 04200000000000 49 O~2OO000000000 ~9 04200000000000 49 04000000000000 LYP OI, O.H02 VERIFICATICIN blSTIN, fi PAG~2 12 TOD 46023392 E~Ibl SGP 3294.0000 PRES PO20 0.00'!9 DON~ PTHO ].~000 GR 655!0.10 0 3214 67 16 1990'1.4'185 .3000 T~N5 2620.0000 .0000 RPRE 3214.0000 .0000 PTEN 7.0000 .1250 TOD 4602345~ ETIM SGP 3322.0000 PD20 0'0679 PONE PT[,!U 3.0000 GR FEET 65532,0] 65 3244 6 !53 METERS 91 199'14.1660 .0999 T~N$ 2614.0000 .(')000 ~PR£ 3~44,0000 ,0000 PTEN O.OOOO ,8'150 ** FIbF TRAILER FILE NAME :RFT ,008 8fRY!CE NAME :LOG VER6ION 9 : 26,2 DATE MAXi~ON LENGTtt :1024 FILE TYPE :CR NEX~ ** FILE t~EADER ** FILE NAME :RFT ,009 SERVICE NAME :bUG VERSION # : 26,2 DAT~ :83/11/17 MAX%~UN LENGTH :1024 FIbE TYPE :CR ~SP~ POlO PHUN ,~SPE PD10 PHUN 20.609~ 0.0659 2,0000 1,1699 0.0~59 3,0000 ** DATA FORMAT RECORD ENTRY BLOCKS TYPE 1 2 3 7 SIZE 1 ! 2 1 1 4 4 4 4 1 ~EPR CODE 66 06 79 b6 06 73 65 73 65 b6 ENTRX o 0 34 255 0 INCH .lin 29 LYP OlO,H02 VERIFICATION LISTING PAGE 13 1 66 14 4 05 .lin 15 1 b6 73 ~6 1 66 0 1 66 0 DATO~ SPECIFICATION BLOCKS MNE~ SERVICE SERVICE UNIT APl API APl API FILE SIZE SPL REPR ID U~DER ~ bOG TYPE CLASS MOD NO, CODE PROCESS (OCTAL) TOD RFT S 98 000 O0 0 9 4 ETI~ PFT S 98 636 21 0 9 4 TENS RFT I,~ 98 635 21 0 9 2 M&P~ [~'T RPS 98 970 O1 0 9 2 SGP RFT PSIG 98 814 O0 0 9 4 PRES RP'T PSIG 98 814 O0 0 9 2 RPR~ PFT PSIG 98 814 O0 0 9 2 PDIO R~'T 9~ 814 O0 0 9 ~ PD20 ~FT 98 814 O0 0 9 2 PONE ~FT 98 814 O0 0 9 2 PTEN ~FT 98 814 O0 0 9 2 PHU~ ~'T 98 814 O0 0 9 2 PT~O Rf'T 98 814 O0 0 9 2 GR PFT GAPi 48 ~,10 O0 0 9 2 I 73 04100000000000 I 68 04000000000000 1 49 04000000000000 ~ 49 04000000000000 1 68 04100000000000 I 49 04000000000000 1 49 04000000000000 1 49 04000000000000 1 49 04000000000000 ! 49 04200000000000 ~ 49 04200000000000 1 49 04200000000000 I 49 04200000000000 I 49 04000000000000 ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY I I b6 0 2 I 66 0 3 2 79 ~ I ~6 255 5 I 66 0 6 4 73 '7 4 65 INCH 8 4 73 12 9 4 65 ,lIN 11 ! 66 29 13 1 66 1 14 4 b5 .lin 15 1 bb 73 16 I b6 1 0 I 06 MNE~ ~5~,RVICE SEaVlCE UNIT AP1 AP1 AP1 API FILE SI.E SPL REPR ID ORDER ~ LOG TYPE CLA~S TOD ETI~ TENS MSPE PFT SGP PRES RFT RPRE RET POlO RFT PD20 RFT NO, CODE S 98 000 O0 0 9 4 S 98 636 21 O 9 4 LB 98 635 21 0 9 2 RPS 98 97O O1 u 9 2 oo o P$IG 98 914 O0 0 9 2 98 ~14 Oo 0 9 2 98 814 O0 0 9 2 (OClAb) I 73 04100000000000 I 68 04000000000000 I 49 04000000000000 I 49 OqUO0000000000 I 68 04~0:0000000000 1 49 04 00000000000 ~ 49 OqOOOOOOO000QO I 49 04000000000000 I 49 04000000000000 PHUN 98 814 98 814 98 814 GAPi 98 310 O0 0 9 O0 0 9 2 O0 0 9 2 O0 0 9 2 0 0 0 9 1 49 04200000000000 I 49 04200000000000 1 49 04200000000000 I 49 04200000000000 1 49 04000000000000 TOD 40023000 E~iIM SGP 3292.0000 PRE6 PD2O 0.06'19 PONE PTHO 3,0000 GR FEET 655~0.101 Oo 3214. 6. METERS 6 19967.4785 3000 TENS 2624.0000 0000 RPRE 3214,0000 0000 PTEN 7,0000 4375 TOD 46023696 ~GP 28,0000 PRES PD~O 0,0679 PONE PTHO 0,0000 GR 65545,0 10 2 7 391 19978,1289 3.5003 TENS 2614.0000 0.0000 RPRE 20.0000 8.0000 PTEN ~,0000 0,7500 ** FILE TRAILER FILE NAME :RFT 009 SERV ICE VERSIQN # : 26,2 DATE :~3/11/17 ~AXI~U~ LENGTH :1024 FiLE TYPE :CR NEXT FIhE ~AME : ~SPE 20.0156 PDXO o,0669 PI~UN 2,0000 ~SPE 20.6563 PDIO 0,0669 PtiUN 0,0000 FILE NAME :RF'r 010 SERVICE NAME ;hO~ VE~SI~ ~ ; 26.2 DATE :~3/11/1 7 MAXIMUM LENGTH ;~024 FILg TYPE :CR PREVIOUS FILE ** DATa FORMAT RECORO ** ENTRY BLOCKS TYPE SiZE REPR CODE ENTRX I bb 0 I 66 0 3 2 79 34 VP 01~,!~'{02 VERIFICATION LISTING PAGE 15 ~ ~ ~6 255 5 1 66 0 ~ 4 '13 7 4 ~5 INC~ 8 4 73 9 4 65 11 1 66 29 ~5 1 66 lb I 06 0 1 b6 0 ATUM SPECIFICATIt,~N BbOCK6 NEt~ SERVICE ,iD ORDER '0!") RF'T S 98 000 [TIa PFT S q8 636 'ENS R~"~ T.,, i,~ 98 635 ~P~ RFT RPS 98 970 ,GP ~ t;"',[' PSIG g~ 814 'PRE RFT WSIG q8 'OlO RFT 98 814 'D20 ~FT 96 814 ' 0 N E; 'TEN RFT 98 'HUN ~FT 98 814 ,~ ~PI APi AUI FII,E SiZe5 6Pu ~EPR bOG TYPE Cb.~SS MOD O0 U i0 4 21 0 10 ?-1 0 10 2 O1 0 10 2 O0 0 10 O0 U 10 2 O0 u 10 O0 0 10 2 Oo 0 i 0 2 oO 0 10 2 Oo 0 1, 0 ? oo 0 10 2 OO o 10 2 oO 0 I0 2 PROCESS CODE (OCTAb) 73 04100000000000 68 04000000000000 49 04000000000000 49 04000000000000 68 04100000000000 49 04000000000000 ~9 04000000000000 49 04000000000000 49 04000000000000 49 04200000000000 49 0a2()00000000()O 49 04200000000000 49 04200000000000 49 04000000000000 0 0 34 255 0 311 INCH 12 .lin 29 1 ,1l~ 73 1 0 )ATU~~ SPECIFICATION ]~ L)RDE~ ~ LOG TYPE CL..~6S rod Rf' T S 96 000 O0 o 10 ETIM ~FT S q8 636 21 O i0 CODE (OCTAL) 4 1 73 04100000000000 4 1 68 040000Ut) O00000 ~¥P OlO,F]02 VERIFICATION LISTING PAGE 16 635 21 0 10 2 970 O! 0 10 2 al4 O0 0 10 4 al4 O0 0 10 2 914 OU 0 10 ~ gl4 O0 0 10 ~ ~14 OO 0 I 0 2 ~14 OO 0 I0 2 81~ O0 0 10 2 814 O0 0 10 2 R14 Oo O I0 2 310 00 0 10 2 ['0!D 4o023k172 ETIM ~GP 3334,00oo PblE8 ~020 0,0o79 PONE ~ T H 0 3,0 0 00 G 1~ FEET ~ETE~S 65610. 1016 19g07.47}t5 O. 3010 T~NS 2540.0000 3254.0000 RPR~ 3~54.()000 ~.0000 PTEN 7~ . 0000 4002404.8 }!:T ~1 l~i 3327,0000 PRES ~THt] 3. 0000 g~ FEET METER~ o5569.3125 199L15. 5273 175,203~ TNN~ 2534.0000 3250,0000 RP~ 3250,0000 1,000'0 PTEN 1,0000 154.5000 IERSION ~ : )ATg :83111/17 ~AXI~O~i [,ENGT~ ;102~ rILE TYPE :CR ~EXT P'ILf": NA~,E: : ~* FID?: HEADER ** ~ERVICE N A ~,~ k; :I~OG ;ERSIUN ~ : 2(,.2 )ATE :83/I1/17 FiLl: ~'YPU :CR I 49 04000000000000 ~ 49 04000000000000 I 68 U41OuOUOOOuO00 1 49 04000000000000 I 49 04000000000000 I 49 04000000000000 1 49 04000000000000 1 49 0420U000000000 I 49 04200000000000 1 49 04200000000000 I 49 04200000000000 I 49 04000000000000 MSPE 22.5156 PDIO ~,0069 PHUN ',0000 ffSPE 45.6563 PD!O 0,0069 PMUN 3,0000 bV'P 010.~,~o2 vERIF,ICATJ~.[]N bISTiNG PAGE 17 DATA ~]NTRY BbftCK5 RECORD T/PElf SIZE 1 1 2 1 3 2 4 1 5 1 7 4 8 4 9 4 ,1.1 1 13 .~b 16 1 )ATOP SPECIFICATION ~NEM 6ERV1CE SERvIcer BLOCKS UNIT AP~ API APl bOt~ TYPE CbA6S $ gB 000 oo S g~ 636 I,,b 98 635 RPS 98 07o P~IG 98 ~tl4 DO P~IG 98 ~14 P616 98 ~14 O0 98 BI~ O0 98 814 OO 98 ~14 O0 98 8 i 4 O0 qB 814 o0 (; A P i 9 U 3 i 0 00 DATA FOR i,I A']' .~:N TRY BLOCKS RECORD 1 2 3 7 15 REPR CODE 66 66 79 66 73 05 13 65 66 65 66 06 API FILE MOl) 0 0 0 11 0 0 11, 0 0 CODE 06 66 79 bO '13 73 05 ~6 06 65 ENTR~ 0 0 30 255 0 311 INCH 12 29 ! ,lin 73 1 O REPR CODE 73 49 49 49 49 49 49 49 49 49 49 49 ENTRY 0 O 3~ 255 0 311 I NCIi 12 ,lin 29 1 , lin 73 PROCESS (OCYAL) 04100000000000 0400000000o000 0~000000000000 04000000000000 04100000000000 0400000000000O 04000000000000 040O000O000000 04000000000000 04200000000000 04200000000000 04200000000000 0~200000000000 04000000000000 ~¥P OIO,H02 VERIFICA~..~iON L%STiNG PAGE 16 I bf., 0 ! 06 0 )ATUt~ $?ECIFICATION BL[1CKi5 ~OD PFT 8 9~ ~RE~ PF'P P~IG 98 ~PR~; P~ 'i" P~TG 98 ~DI, O RFT 98 ~ONE RFT 98 ~TEN RFT 98 ~HUN RP'T 98 ~T~O P~'T ~8 ;R. RFT GAPi 98 API TYPE CLA6S 00o O0 636 21 635 21 9 7 o 01 814 O0 814 00 ~4 Ov g 4 00 814 O0 814 ~0 814 oo t ~ 0 00 A P MO 0 () U 0 O I FILE SIZE D NO, 11 4 11 a 11 2 I1 2 11 4, u 11 2 0 11 2 0 11 2 0 11 2 0 11 2 tt 11 ~ 0 il 2 o 11 2 0 11 2 REPR PROCE~3$ CODE (OCTAb) 73 0410'0000000000 6B 04000000000000 49 04000000000000 49 04000000000000 68 04100000000000 49 04000000000000 49 0400VO00000000 49 04000000000000 49 04000000000000 49 04200000000000 49 0420U000000000 49 04200000000000 49 0420{)000000000 49 04000000000000 ~OD 46024i4~, EiIM 5GP 33~4, (')uoo PRE6 .~D?..O o, 0679 PUNE ,~TH(J 3. ('} 0 o u G~ P, OD 46024352 5GP 3337. O00O PRE8 .~D20 O, 0079 PONE .~THO 3. 0000 FEET METERI~ 655 1, O. 1 () 16 19007.4'185 0,3000 TENS 2524,ou00 32b6. OOO0 RPRE 3266. 00(')0. 8,0000 PTEN 2,0000 ~9 2500 FEET METER~ 65579,2656 ,1 9988,5605 204,600~ TEN6 2990,0000 3260.0000 RPRL; 3260.0000 .t, 0000 PTEN 2,0000 66.0~25 MSPg 20 9 PHIJN ~t, 0000 ~8PE 21,765~ POlO 0,0669 PHUN 3,0000 ~* FILE TRail, ER ** FILE i', ~ HE :Rb'm .oli SERVICE NAME :bOG 3ATE ;~3t11/1.7 ~AXIMU~ T,ENG..n ;1024 ** FILE ~!E;~DE~ ** F1L~ mAHE :R~"~ ,012 , C ' 010 [t02 VERIFI...Aq.'iON bISTING PAGE 19 SERVICE MAME :LOG VERSION DATE :83Ill/1.7 MAXIMU~ Lk:NGT/i ;1024 PREV 1'0I;6 ENTRY' BLf]CK8 I i b6 0 2 I b6 0 3 2 79 34 4 I ~6 255 5 i 66 b 4 73 311 'l ~ b5 INCH 9 4 65 · 1 '['N 11 1 06 29 14 4 05 ,1 IN 15 I 6b 73 16 I 66 o 1 66 0 DATUN SPECIFICAIION ~%LOCK6 I~NEM 6ERVICE iSERV'.i. CE UNIT ADi AP1 APl API FILE SIZE 6Pb REPR II) ORDER ~ bOG 'tYPE: C~ASS MOD TOD F~"T 8 98 000 O0 0 12 4 ETIM ~P"T 8 98 636 21 0 12 4 TE~N8 Pf'T LB 98 635 21 O 12 2 M~PE [~FT RPS 98 970 Ol 0 SGP PFT P~IG 98 814 O0 0 12 4 RPRE PFT P6IG 98 814 O0 0 12 2 PDIO p~'m 98 814 OO 0 12 2 ~D~O RF'f 48 814 O0 O 12 PONE ~'T q8 ~la O0 0 12 2 ~TEa ~,FT 98 814 O0 0 12 2 PHI_IN R~'T 98 814 O0 0 12 2 PTHO ~p"T 98 814 O0 O 12 GR PFT GAPA 98 ~10 O0 0 12 2 CODE [ OCTAL) I 73 04100000000000 I 68 04000000000000 I 49 04000000000000 1 49 04000000000000 I 68 04100000000000 1 ~9 04000000000000 1 49 04000000000000 1 49 04000000000000 1 49 04000000000000 I 49 04200000000000 I ~9 04200000000000 1 49 04200000000000 1 49 04200000000000 1 q9 U4000000000000 ** DAT;~ FORNAT RECORD ** ENTRY EnlgCK8 TYPE SIZE REPR CODE 1 1 ~6 2 I ~6 3 2 79 4 1 o6 5 1 ~6 ~ 4 73 O 0 34 255 0 3!1 ~VP O!O,H02 Vii~RIFICATiON bI~TiNG PAG~ 20 7 4 o 5 8 4. 7 ] 9 4 15 1 0 I PECIFICA£IUN BLOCK6 RViCE SErViCe3 UNIT APl AP1 APl APl 113 ORDER ~ bOG TYPE CbA~S FT S 98 000 O0 0 FT S 98 636 21 FT i,~ 98 635 21 u FT RFS q8 970 O1 u FT P~IG 98 814 O0 FT P~IG 98 81,4 00 0 FT 98 814 OO 0 FT 98 814 O0 F~ 98 814 Oo 0 FT 98 814 O0 F~ q8 ~14 OO 0 FT . 98 814 O0 FT GAP1 98 310 00 o £OP 40024544. 5GP 3329,0000 ~D20 0 . ,~THO 3,0000 E T I .a PRE~ P [j N E INCH -~2 .lin 29 1 73 ! 0 ro~) 4o0247b~ 5GP 3321.0000 2020 0. OO7W ?THIO 3,0000 Fi. GE SIZE 6P.h REPR NO, CODE 12 4 1 12 4 1 12 2 1 12 2 1 12 4 1 12 2 1 12 2 12 ?. 1 12 2 1 12 2 1 12 2 l 12 2 1 12 2 12 2 1 ~* FIu~.. Tag. II, ER rILE ~A~E :RFT ,012 SERVICF NA~E ;LOG ~ERSIUN ff : 26,2 DAT~; :83/11,/17 ~AXIMU~ I,~N(;TH 11024 FILE TYPE ******** DEPT[I FEET b.551 O, 1016 19967,4785 0.3 000 T 3250,0000 RPRE 3250,0000 3.0000 P'l' E i~ 1,0 O 00 57,1.875 FEET METER6 ¢,5586,3750 19990. 7260 225,6010 TE.5 g30.O000 32~4,0000 RPRg 5.0000 PTEN 63,0313 PROCESS (OCTAl,,) 73 04100000000000 68 O4000000000000 49 OaO00000000000 49 04000000000000 68 04100000000000 49 04000000000000 49 04000000000000 49 040()0000000000 4'9 04000000000000 49 04200000000000 49 04200000000000 49 04200000000000 49 04200000000000 49 o4OOOOuOO00000 M$1)E 17,1~75 PDIO 0,0669 PnUN 3.0000 MbPE i7,1250 POlO 0,0669 PnU~ 3.0000 5VP 010,t102 VERiFiCATir~t~ LI~TING PAGE 21 rlbg m A ~v~l;i :RFT 013 ~ERV~CE ~ A~E :LOG ~ER~ION $~ ; 26.2 )ATE :s3/ll/X 7 ~AXI~U~ LENGTri :!024 ~i[,g TYPE ?REVI'OIJS FILE DATA t'ORMAT H~:C[]~D ** ~NTRY BLOCKS T~PE SiZE REPR CODE ENTRY I I 6~ 0 2 I 06 0 3 2 79 34 ~ I 6~ ,255 5 i ~6 o b 4 73 311 7 4 b5 INCH 8 ~ 73 12 9 t b5 ,lin 11 1 66 29 13 1 ob 1 14 4 O5 .lin 15 I Ob 73 16 I b6 1 0 1 ~6 0 )ATON SP[CCT. FI¢.AT!ON Bb[!CK6 ~NEM 6F.t~vIC. E SERVICE uiiIT APl AP1 APl APl FiLE SIZE SPL REPR ii", ORDEH '~ bOG TYPE CLA~S MO[) NO. l'OO Rf'T 6 98 000 O0 0 13 4 ~'I' I ~I ~FT S 98 636 2i O 13 4 tENS R~'T l.,~ 98 635 21 0 13 2 ~SPE RP'~ RPS 98 970 O1 O 13 2 SGP RFT P~IG 98 814 o0 0 13 4 ~R~6 RFT P$IG 98 814 oo 0 13 ~ ~PR~ ~FT PS!G 9~ ~I, 4 O0 0 13 2 ?DIO PFT 98 814 O0 0 13 2 ~O20 ~FT 98 ~14 O0 0 13 2 ~ON~ ~FT 98 814 OO ~ 13 2 VTEN P~'7' q8 ~14 O0 0 13 2 PHUN FP'T 98 814 00 u 13 2 ~THU P~ T g8 S14 O0 0 13 2 ;H PFT GAPl 98 310 OO U 13 2 PROCESS CODE (OCTAb) i 73 04100000000000 i 68 04000000000000 1 49 0400000o000000 1 49 04000000000000 1 h8 0~100000000000 1 49 04000000000000 I 49 0400O000000000 1 49 04000000000000 1 q9 04000000000000 1 49 04200000000000 49 0420U000000000 1 49 04200000000000 1 49 0420V000000000 1 49 U4000000000000 DATA FORNAT RECO~D ** gNT~Y PbOCK5 ~P 0lO.H02 VEP. 1FICAT£D~ bi'STING PAGg 22 )ATBM 8PEC.IFICATION 4NEE 6~]RVICE 6P]RViC~; ID .ORDM~ ~ TY~; SiZE I 1 2 1 3 2 b 1 6 4 7 ~ 4 9 14 4 15 0 I BBOCKS UNIT APt bOG LO q8 ~PS 48 PSIG g8 PSIG 98 P~IG qB 9~ 98 ~8 GAPi 98 i'v EPt< CODE ENTRY 7.9 34 ~6 255 73 ~5 INCH 73 12 29 b 5 · 1 ] N ~6 73 b6 1 66 0 APl AP1 ~PI FiLE TYPE CLA~S MOl) NO, 0 0 0 0 0 0 1 3 636 21 u 635 970 01 u 13 ~ 14 0 o u 814 o ~14 O0 0 814 oo 0 13 i.114 ~14 o0 0 814 81~ 814 O0 310 O0 0 13 REPR C 0 D E 73 49 ~9 h 8 a9 PROCESS (OCTAL) 04100000000000 04000000000000 04000000000000 0400UO00000000 04100000000000 oqooooooo00000 04000000000000 49 04000000000000 49 04000000000000 49 04200000000000 49 04200000000000 49 04200000000000 49 0~200000000000 04000000000000 rOD SGP PD20 PTHO 46O24912 3337,0000 0,0679 3. OO O0 TOD SGP PD20 P'tHO 4b025072 3332,0UOU O,Obb9 3,0000 G ~ ******** DEPTH ******** FEET ~ETERS b5510,1. 016 19qb7,478b 0,3000 TEN~ 2630,0000 32~(), 000U RPRK 3260. 0000 ~,.OOOO PTE;N 2,0000 57.8750 b5568,0938 19905.1543 17~,6008 TENS 2624,0000 3254,0000 RPRE 3?54,0000 6.0000 PTEN 1,0O(.)0 ~5~,8750 MSPE 18,3~38 PDIO 0,0069 PHUN 3,0000 MbPE 2,3242 Pi;lO 0.0669 PMIIN 3,0000 ~VP 010,}i~02 V~PIFICATIO~'~ LISTING PAGH 23 tERSION ~;' : 26,2 )ATE {AXI~O~~ L, ENGT.~; ;1024 ~Ib~ TYPE ~REVIOUS Fl:bF. BLOCKS 1, ~ 6 0 2 79 34 I O~ 255 5 i 66 0 b 4 73 311 7 4 ~5 INC~i 8 4 '13 1,2 9 4 05 11 I bb 29 14 4 05 ,lin 15 I 06 73 0 1 ~6 0 )ATUM S~ECIFICATION BioOCKS 4NEM 6FP,.VIC~ 8Fi~Vi(;E Ut, I'T APl LpI APl AP1 FI[,E SiZE SPL REPR i~, ONUI~:R s LOG i'YPE CLASS rTIM PI,'m $ 98 636 21 9 14 4 ~PE ~b'T RPS g8 970 O1 0 14 2 : G P u ~' T P & I G 9 ~ }~ 14 { ~ 0 0 14 4 ~PR~; P~'T PS!L, 98 ~la O0 0 14 2 ~DlO PFT 98 U14 (}g U 14 2 ;g2O R~'T 98 ill4, t)u g 14 2 ?ONE ~b'm 98 RI~ O0 0 14 2 ~rF~ p~"r 98 ~14 ov U 14 2 CODE (OCTAb) '73 0410000000VO00 68 04000000000000 49 0400()()000000(30 49 04000000000000 6~8 04 I ('}L)O00000000 49 040000OO00t)O00 49 04000000000000 49 0400UOOO000000 49 0400000000UO00 a9 04200000000000 49 0420U000000000 :~VP OlO,H02 VERIFACATAtim blSTING PAG~ 24 ? H U i:~ P, b".,," 9 B [{ 14 o 0 0 14 2 ,:THO PFT 98 R14 00 0 14 2 ~R ~FT GAPI 98 310 OO 0 14 2 1 49 04200000000000 1 49 Oq2000OO000000 1 49 04000000000000 ~NTMY T'~PE SIZE ~EPR CODE MNI'RY I 1 66 0 2 I 66 0 3 2 79 3 ~ 4 I ~6 255 5 1, 06 ~ 4 73 311 7 4 b 5 I a C H 8 ~ 73 11 I ~6 29 ~3 I 66 ~4 4 ~5 ,lin 15 1 66 73 1~ 1 ~ 1 0 I ~6 0 )ATOM SFECIFICATIUN )~LOCK6 ~NE~'I SE~ViCE SERVICE UNIT apl AP1 APl APl Flbg SIZe. SPb REPR 1[) ORDER ~ bOG TYPE CicA,SS MUD [OD RFT $ 98 t~,O0 O0 0 14 4 ~TIM ~f'~7 8 98 636 21 O 14 4 ~ENS RFT l.,S g8 635 21 0 14 2 ~SPg RFT RPS g8 g7o Oi 0 14 5GP ~Fg' P6IG g~ ~,4 oo 0 14 4 ?RES RFT PSIG g8 ~14 O0 0 14 2 RPRE PFT PaIG 98 f314 00 0 14 ?D20 RFT 98 814 00 0 14 2 ~ONE R~'T 98 ~i4 O0 V 14 2 ~TEN RFT ~ 814 O0 0 14 2 ~HUN RFT 98 ~14 O0 O 14 2 ~THO qf'T 98 814 O0 0 14 2 ~R PFT GAPi 98 310 oo 0 14 2 PROCESS CODE [OCTAL) 73 OqlO0000000000 ~8 04000000000000 49 04000000000000 49 04000000000000 68 04100000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04000000000000 49 04200000000000 49 04200000000000 49 04200000000000 49 04200000000000 49 04000000000000 5GP 2D20 PTHU 65510,10i6 19967.4'185 0.3000 TEN3 2654,0000 MSPK 3256.0000 RPRE 3256,o000 PD~U 0,0~00 PTEN 2.0000 PM[IN 20,140~ 0,0069 3,0000 rOD 4b025376 ETIF, 5,3011 5 G P ] 33 o. ~ u o o ~.' ~ E ~ ~ 252 o o o u PD20 O, 00'19 PO~ 4 ] 0000 PTHO 3.0000 C;R 25,9844 9ATE 7 ~AXI~U~ LENGTH :1024 gILE TYPE ~EXT FIbF, 19'.;90. 6973 TENS 2640,0000 RPRE 3252,0000 PTEM ~, o000 0~4 PO!O PHUN 20,1719 0.0~69 ~* FILE HEADE~ ** 5ERVI, CF MAME :bOG DATE :83111/17 ~AXI~OY LgNGT[t :1024 Fi I.,g 'tYPE': :CR PREVIO[J~ FILE ; DATA FORNA~I' RECOt<D ** ENTi{Y RhOCK$ TYPE] SiZE REPk CODE 1 I tab 2 i b6 3 2 79 4 1 66 5 1 06 6 4 '13 7 4 05 8 4 73 9 4 05 ll 1 / b6 13 I 06 14 4 65 15 i b6 !6 1 06 0 1 66 DATU~ SPECIF!¢ATION ~0¢K6 ~NEM SF~VICE SERVICE {.INIT APl AP1 AP1 AP1 FILE ID OROFR ~ bOG :CYf'E (bASS NOD NO, TOO RFt~ S 98 000 O0 0 15 ETIM ~FT S 9~ 636 21 0 15 TENS Rf'q' l,~ 9~ 635 21 0 15 MSPL Rf'T RPS 9~ 9'!0 O1 0 15 ENTRY 0 0 255 0 INCH 12 ,lin 29 ,lin 73 O SIZE SPb REPR CODE 4 I 73 4 1 68 2 1 49 PROCESS (OCTAL) 04100000000000 0400~000000000 04000000000000 04000000000000 bVP 01.0,F202 V£P. 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O0 ~.7969 999,2500 ,:999; 250:0 -O99,25OO 3 8105 -999 2500 -999 2500 -999 2500 1,9053 99o.2500 :99~ ' 2500 -999.2500 4.9883 -999.2500 -999.250U -999.2500 1,7568 -999,2500 -999,2500 -999,2500 3.7129 -999.2500 -999.2500 -999,2500 4.2813 -999.2500 -999,2500 -999.2500 3.1367 -990.2500 -999.2500 -999.~500 3.4395 '~99,2500 '990.2500 ALi CALl RNRA I h M CALl RNRA C A L I I ,h ~ CALl RNRA CALl Rb~RA IbM CALl ~NRA 'IbM CALl RNRA CALl RI'iRA IbM CALI PHRA CALl RNRA 3 01t7 -999 2500 -999 2500 2,9961 ~999,2500 999,2500 3,7324 -999~500 -999, 500 3,~340 '999, 500 -999,2500 2.0586 -999,~500 -999,.500 -999: O0 -999.2500 O0 '999, '999,2500 3,6504 -999,2500 '999,2500 4,1836 '999,2500 '999.2500 3,0~59 :999,2500 999,2500 3.3691 -999,2500 -999,2500 bVP OlO.}qO~ VERIFICATiOi, LISTING PAGE 7 NPNi -c~9q., 2500 DEPT 5600 0000 SF'I,u SP 136 5000 GR RHOB -999 2500 DRHO NPHI -999 2500 NCNL DEPT 5500,0000 SFLU SP 139,0000 CH RHOB -999,~500 DRHU NPHI -999.2500 NCNb DEPT 5400 0000 SFT,U SP 139,7500 GR DEPT ~300.0000 SFLU SP 140,7500 GA RHOB 999.2500 DRHD NPHi -999,2500 NC~!b DEPT 5?00,0000 Spr'gu SP 138.7500 ~R R,HOB 999,2500 DRNU NPHI :999.2500 WCNL DEPT 5000 0000 SFI.,,U 'nooo qR SP 1,41,, RHOB -99~,2b00 DR, HO DEmi' 4900.0000 SFLO SP 139,5000 GR RHOB -999.2500 DRHO NPHI -q9~,2500 NCNb DEDT 4~00 0000 SFLU SP 139:5000 GR RMO~ -999'2500 DK)~O NPHI -999,~500 NCnb DEPT 4600 0000 SIr:,'LU SP '137:5000 GR -999 2 1 I3 -99c~ -990 3 11a -999 -99o 4 79 2 -999 2 106 -999 -999 2 99 -999 -999 P 106 -99q -999 2 -999 -99q 2 9.0 -999 -999 2 99 -99~ -990 2 97 .2500 926 000 2500 2500 .4551 25O0 '2500 . ,2500 '757U 1250 2500 2500 6113 750 '~500 ,2500 6367 ,0000 ,2500 .2500 :5820 9'150 .2500 .2500 ,6797 ,4375 ,2500 .2500 .4746 .0000 ,2500 :4922 1875 .2500 ,2500 .5156 ,3125 .2500 .2500 .757~ .6250 I,hD NRAT GR NRAT FCNL T ,G D GR NRAT FCNL NRAT FCNb ILD NRAT FCML ILD GR NRAT TLD GR l'bt~ NRaT FCNL GR NRAT FC~:L NRAT -999.2500 -999, ,,, O0 -999.2b00 -999. 2500 3,5488 '999 2500 '999' .99~'2500 ..... ,2500 2,66al -999,2b00 -999,25~0 -999.25 0 3,~359 '999, 500 -999,2500 -999,2500 2,8672 '999.2500 -999,2500 -099,2500 2,8574 -999,~500 '999.2500 -999.2500 2 8770 -999:2500 -999.2500 -099'2500 2,7207 999,2500 999,~500 999,2500 2,8184 '999,2500 '099,2500 '999,~500 2.8379 2999 2500 999:2500 -999.~500 3,1074 '999,2500 IhM CALl. RNRA CALl RNRA ! I,~M CALi RNRA I l.,M CALl RI~RA IbM CALl R N R A II, M CALl RNRA II,It CALl RNRA CALl RNRA CALl R i'~ R A I L,M CAUl RNRA CALl 2,931.6 999%2500 -999.~500 3,4941 999,2500 1999.~500 2,8066 ,25oo 3,0371 -999,~500 '999,~500 2,7891. -999.2500 -999.2500 2.7734 2999,2500 999,~500 2.7324 '999.2500 '999.2500 6367 999.2500 2,7031 -999.2500 -999.2500 2,7188 999~2500 :999.2500 2.9844 -999.2500 bVP 010,M02 VER1F]CA'rloN LISTING PAGE 8 RaOB RHOB -9 NpHI DEDT 44 SP RHOB NPHI -o SP 1 RHOB 99.2500 DRMO 99,2500 ~,{CNb 00.0000 SFLU 35,7500 GR 99,2500 DRHu O0 ~000 8FI,,U 35 000 gR 90 2500 DRY]I:) 99 2500 NCNb 00,0000 SFLU 36,5000 GR 99,2500 DRHU 99.2500 NCNb DEPT 4,~0o,~000 SFI..,U SP 138, 000 GR RHOb -099.2500 D~N[] NPHI -999.2500 NCNb DBPT 41 SP ~ RHOB -9 O0 0000 SFLU ,5000 qk 99,2500 DRHU 99.P500 NCNb DEPT 4000,0000 SF),O SP 137.7500 GR RHOB -o99.~500 DR{40 NPHI -999.~500 NCNb DEPT 30 SP RHOB NPHI DEPT 38 SP 1 NPHI -9 DEPT 37 SP RHOB OEPT 36 SP 1 NPHI -9 DEPT 35 00.0000 SFY.,O 26,4375 aR 99,2500 ~MO 9~,2500 NCNb O0.O00o SFLU 26,2500 GR 99,2500 DRHO 99.2500 NCNb 00,0000 SFf, U 99 2500 DRHO 99:2b00 NCNb 00 0000 S~'LU 23:00n0 GR 99,25o0 DRgO 99.9500 NCNb 00.0000 SFLU -999,2500 NRAT -999,2500 FCNI, 3,0098 ILD ~07,81.~5 GR '999,2500 NRAT '999,~500 FCML 3,9266 110' 750 -999,~500 NR~T -999,2500 FCNL 3,1074 IhD ,095 3?50 GR .~ 99' 2500 NRRT -999,.9.500 ~ C., b 9],5020 .999,7500 2500 NRAT -999'2b00, FCNb 4.7227 87 0000 -999' .250o MR,AT -999.~500 FCNL 2 2305 7bD 84i9375 GR -099 2500 N~AI' -99~.2500 FCN[ 4,5430 97,5625 -990,2500 -990,2500 FCNL 3.5547 87,6250 GR :999.2500 999,2500 FCNh 2 9395 IbD 61:9062 -999. 2500 MRAT -~99,250(; FCNL 3,470'1 96 3'150 -999i2500 -999 2500 FCNL. m,5781 '999,250() -999.2500 3.4043 -999.2500 -999.2500 -999,2500 4,2344 -999,2500 -999 ~500 -999~ 500 3,595'7 -099.2500 -999.2500 -999,2500 2,933 -999,250~ -999.2500 -999.2500 4,8359 :~99,2500 999~2b00 -999.2500 3.2'154 -999.2500 -999,2500 -999.2500 5.6211 2099,2b00 999,2500 -090,2500 4 2422 -999:2500 -099,2500 -999,2500 4.7695 -999,~500 -999,~500 -999.2500 4.5039 -999,2500 -99O.2b00 -999.2500 ~.0547 RNRA CA[,, I, R N R .A II,M CALl R N R A IbM CALi RNRA I L,~I CALl RNRA Ib~l CALl R NRA IL, M CALl RNRA CALl ~.NRA IL, M CALl RNRA IbM CALl RNRA ILM CALl RNRA TLM -999.2500 -999,2500 -999,~500 4,0000 -999,~500 -999,~500 :3.4023 '999,2500 -999,~500 2,7051 '999,2500 '999,2500 4.5625 '999,2500 '999,2500 2,9043 999,~2500 2999.2500 5,0625 '999,2500 '999,~500 4,0195 '999,2500 '999,2500 5,3984 '999.2500 '999,2500 4.1523 -999 2500 -999~2500 ~,6406 VERIFICATION LI~TING PAGE 9 ~HOB !,15.7500 -099.2500 DRHI') -999,, 2500 82..l 875 -~9~,2500 )EPT ~{OS qPHI 3400 0000 SFbO 118 2500 GR -999 ~500 DRHO -990.2500 NCnb 4,0664 1.6D 74 4375 GR -999' ,~99,~500 NRgT .2500 FCNb '999.2500 CALl -999,2500 R~RA '999,~500 ' O0 CALl -.999,2500 RNRA -999.2500 -999.2500 4,~742 -999. 500 -~99.2500 )EPT 3300,0000 SFI.,W 3o1387' ILD 3,0984 Ib~ 3,3203 5P 127,0000 GR 74.6250 CR -999,7500 CALl -~99,2500 ~ftOB -999.2500 DRHO -999,2500 NRAI -999,2500 RNRA -999,2500 ~PHI -999.2500 NCNL -99¢~,2500 FCNL -999.2500 I.. 8164 54,3438 GR :~9q, 2500 NRA'I 99.2500 FCNL , f.P~ 3~z,. 00o0 SFI..,W ~,P .i62,0000 aR :~HOg -999,2500 ~PHI ,.999. 2500 NCNb 13,5859 -999,7500 CALl -999,2500 RNRA '999,2500 ~RVlCE ~A~ ~AXI~[}~ LENGTH ; 1024 FILE TYP~ : ~EXT FILE UA;~E : 2000,0000 -999.2500 -999.2500 ** TAPE TRAII, gR ** SERVICE NAME :EDIT DATE :~4/00/ 5 9RIGIN 10000 TAPE NA~,iM :9467 CONTINUATION # :01 NEXT T~PF ~IAME ; CO,MEATS : ** REEL TRAIl,ER ** SERVICE MA"E :EDIT DATE; :84/00/ ORIGIN ~EEL NAMF : CONTINTIATiON # :01 NEXT REEL NAI~h: ; COMMENTS