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200-124
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WFLL oPFRATInNS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: SP Exploration (Alaska), Inc 4. Well Class Before Work Development 21 Exploratory ❑ 5. Permit to Drill Number: 200-124 3. Address: P.O. Box 196612 Anchorage, AK99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 60-029-21698-01-00 7 Property Designation (Lease Number): ADL 028281 8. Well Name and Number: PBU J -22A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: �R,[ PRUDHOE BAY, PRUDHOE OIL ■ . ECE'V 11. Present Well Condition Summary: Total Depth: measured 10387 feet Plugs measured None feet OCT 2 9 2019 true vertical 9083 feet Junk measured None feet Effective Depth: measured 10324 feet Packer measured 5948, 8959, 9172, 9414 feet /� AOG (V' true vertical 9039 feet Packer true vertical 5561, 8020, 8182, 8361 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 39-118 39-118 Surface 1999 13-3/8" 38-2037 38-2037 5380 2670 Intermediate 9675 9-5/8" 37-9712 37-8584 6870 4760 Liner 727 7' 9462-10189 8396-8946 7240 5410 Liner 913 2-7/8" 9474- 10387 8405-9083 13450 13890 Perforation Depth: Measured depth: 10200 - 10300 feet True vertical depth: 8954-9023 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr85 14-1/2" 12.69 L-80 35 - 9295 19320 - 9523 35 - 8274 18292 - 8441 Packers and SSSV (type, measured and 411/2' HES TNT Packer 5948 5561 true vertical depth) 4-1/2' HES TNT Packer 8959 8020 4-1/2' HES TNT Packer 9172 8182 4-1/2" TAN HBBP Packer 9414 8361 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In Subsequent to operation: 798 21767 3868 0 997 14.Attachments (regwredper20nac25m0.25.071.a2s2ea) 15. Well Class after work: Daily Report of Well Operations IZ Exploratory ❑ Development p Service ❑ Stretigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: ® Oil Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-398 Authorized Name: Lastufka, Joseph N Contact Name: Hyatt, Trevor Authorized Title: IM cialist ContactEmail: Trevor.Hyatt@bp.com Authorized Signature: Date: I�12 I A Contact Phone: +1 907 564 4627 Form 10-404 Revised 04/2017 x,.< KtaPaPUMJRBUMbifnY OCT 3 01019 Submit Onainal Only *** WSR continued from 09/11/19 *** (LRS Unit 46 - Circ-out Pre Pulling Unit) Pumped 3 bbls 60/40 meth down TBG taking returns up IA to establish circulation. Pumped 731 bbls of 9.8 ppg brine down down TBG taking returns up IA to J-21 FL. to circ-Out. SV/SSV=C MV=O CV's=OTG 9/12/2019 Final WHP's=.87/110/33. T/I/0= vac/vac/75 Temp=S1 (LRS Unit 70 - Test BPV to 500 & 1000 psi) Pumped 18 bbls 100*F 9.8 brine down IA/TBG to pressure test TWC/BPV in TBG hanger. Held TBG/IA pressure around —500 psi for over 5 minutes with no pressure gain in well head except for initial 40 psi required to set TWC . Held TBG/IA pressure at 1000 psi for over 5 minutes with no pressure gain in well head. While holding 1000 psi, established a LLR rate of 0.25 bpm. Dry hole tree; closed top valve. MV= open; casing valves= OTG'S. 9/12/2019 FWHP's 39/vac/137 T/I/O = Vac/Vac/145. Pre AA pulling unit. RU lubricator and PT to 350/3500psi (PASS) Run down and set 6" 'J' TWC #403. LTT (PASS). Remove 6" upper tree and install Temp #46 as Dry Hole, torque to API specs. Install 6" Tapped blind flange and Torque to API specs. PT against MV to 350/5000psi (PASS) Remove working side IA and OA blinds and install Integrols with block valves. PT to 350/3500psi (PASS). Bleed OA to 0. RDMO ***Job 9/12/2019 Complete*** SEE LOG FOR DETAILS. Final T/I/O = TWC/0/0. (LRS Unit 46 - Test Back Pressrure Valve) Job Postponed due to Well Support and Valve 9/12/2019 Shop rigging down equipment Stby A 04-21 for J-22 prep work and pad prep until ready for move. Start move @ 0900 hrs. 9/12/2019 Sub on edge of J Pad @ 13:30. Continue moving rest of equipment 24 Hr Summary: Continue setting up. Peak electrician repair gas alarm system. Derrick inspection 24 Hr Forecast: Test gas alarms. Test TWC from top. ND dryhole tree and THA. NU and test BOPE 9/13/2019 ***Job continued on WSR 09/14/19 24 Hr Summary: Continue rigging and connecting lines. Repair gas alarms (trip tank sensor inoperable) Complete Rig audit checklist. Fire up boiler. Test TWC from above. 9/14/2019 24 Hr Forecast: NU and test BOPE 24 Hr Summary: Continue rigging and connecting lines. NU BOPE, connect hydraulic lines, function test BOPE, Install test joint. test BOPE - no failures. Report sent to AOGCC. Install riser pipe and airboot to flow box. Accept the unit @ 1600 hrs. Maintain hole fill down IA @ —1.3 bbls/hr. MU lubricator to pull TWC. PT donut riser. PT lubricator 250 psi low 2900 psi high. Pull TWC. Lay down riser. 9/15/2019 24 Hr Forecast. LD Tb T/I/O = TWC/0/0 Assist AA pulling unit w/ pulling TWC. RU lubricator 68-839 w/ 15' of extension. PT lubricator 350/3500 psi (Pass). Pull 6" J CIW TWC #403 at 130" through 9/15/2019 stack. RDMO ***Job Complete*** Final WHPs T/l/O = VAC/0/0 ***SWCP 4516 RIG SUPPORT FOR AAO-1 11*** PULL 4-1/2" HES RHC-M FROM X-NIPPLE AT 9,228' SLIM / 9,220' MD. RHC-M BODY HUNG UP AT 6,851', 6,825', & 6,781' SLM PULLING OUT OF HOLE. TAG FILL AT 9,333' SLM W/ 3.78" CENT, 3.805" CENT, 2.73" L.I.B. (Impression of fill). HAD NO ISSUES GOING BY TUBING STUB AT —9,291' MD (Made five passes). 9/16/2019 ***WELL TURNED BACK OVER TO AAO-111, NOTIFIED DSO OF WELL STATUS*** Daily Report of Well Operations PBU J -22A 24 Hr Summary: Maintain hole fill down IA @ -1.3 bbls/hr. MU and landing Jt and screw into Hanger. Crossover slipped out of hanger dropped string. Derrick, Wellhead, and stack inspection - Okay. Wellhead is 1" lower after dropping string. PPOT IC failed. LEaks off to 500 psi (IA 0 psi / OA 120 psi) Cameron sting into least void and PT IA to 1250 psi (rolling test) no pressure response in test void during 10 minute test. RU SL. Pull RHC plug body @ 9228' SLM. Note tight spots while POH @ 6851, 6825', 6781'. RBIH w/ 3.80" drift assy. SD @ 9,333' slm (PX Plug @ 9340' MD, 0 from rig floor), Tap down few times, 150# over -pull. PUH to 9250' slm, made multiple passes to 9,333' slm. Stub appears fine. OOH w/LIB few marks on the side of LIB. MU SLB spear/pulled hanger (105k up wt.). Line pump up circ to dirty tank to confirm returns 9.8 ppg brine. Go over pressure cross check 24 Hr Forecast: Slickline drift thru Tbg stub to ensure no damage when tbg dropped. Spear pup below hanger and pull tbg to floor. LD -40 Jts tbg. PU and set Baker Storm Packer. 9/16/2019 Change IC Pack -off T/I/O=N/A/0/0, Temp=Sl. PPPOT-IC (FAIL), post hanger drop. PPPOT-IC: Stung into test port (0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Pumped through void, good returns. Unable to pressure void above 2500 psi, pressure bled to 500 psi in 30 seconds. Torqued LDS to 600 Ib/ft. Still unable to achieve test pressure. RU to PKG port, opened PKG SBS to verify 0 psi in void. Pumped plastic to re-energize secondary Y seal. Unable to get plastic returns from PKG SBS port. Still unable 9/16/2019 to achieve test pressure. FAIL). Bled void to 0 psi. 24 Hr Summary: Pump on line taking returns to dirty tank to confirm returns are clean brine, pumped 100 bbls brine, got good 9.8 ppg back. Monitor well for no -flow. Attempt to pull 4- 1/2" tbg, unable to pull, pulled 24k over, tried working pipe. No luck. appears packer may be set. Discuss best option w/ HAL to mover packer downhole. Stack all weight (82K) down for 1 hr to encourage packer to slip downhole. Pump down backside 2000 psi 5 mins w/ all weight stacked. No movement. Call out slickline. Break out spear from manger @ SLB. Thread inspection - appears crossover was not fully engaged. Will send both to Baker machine tomorrow to be gauged/inspected. Ran 4-1/2" XX plug (8 x 1/4" EQ ports) Set @ 9197' slm. 24 Hr Forecast: Set Tbg plug in X nipple below packer, Pressure up on tbg to 3500 psi/20 mins to set packer. Pull tbg plug. Drift thru EOT and re-enter tbg stub to ensure serviceability of the well. RU EL and cut tbg above the packer. LD -20 Jts tbg. PU and set Baker Storm 9/17/2019 Packer. Change IC Pack -off. ***SWCP 4516 RIG SUPPORT FOR AAO -111 *** (RWO) SET 4-1/2" XX PLUG (Cal = 25" - 8 x 1/4" eq. ports) AT 9,197' SLM (Nipple below packer). 9/17/2019 ***JOB IN PROGRESS, CONTINUED ON 9/18/19 WSR*** 24 Hr Summary: SLB SL unit on location, Ran 4-1/2" XX plug (8 x 1/4" EQ ports), set @ 9197' slm. RU test line to TBG. On line w/test pump, Test 4-1/2" TNT PKR. Saw pressure drop, PKR started to set @ 2250psi. Pump off line @ 3500 psi. monitor pressure for 20 minutes. Good test, PT held 3500 psi for 20 minutes, bleed off pressure. SL RU, RIH and EQ/pulled 4-1/2" XX plug @ 9197' slm. Drift EOT into stub to verify no exit or re-entry problems w/ 3.50" Bell guide, 3" pump bailer, 4-1/2 GS, Run caliper, RD SLickline, RU Eline and RIH with tubing punch... 24 Hr Forecast: Run PDS caliper. Punch and cut tbg above packer @ 9104. Pull 10 jts Tbg. 9/18/2019 1 Set Baker Storm packer belwo wellhead. C/O IC pack -offs Daily Report of Well Operations PBU J -22A ***SWCP 4516 RIG SUPPORT FOR AAO -111*** (RWO) RIG PRESSURED UP ON TUBING TO FINISH SETTING HES TNT PACKER. EQUALIZE & PULL 4-1/2" XX PLUG BODY FROM 9,197' SLM. TAG FILL W/ 3.50" BELL GUIDE, 2.60" BELL GUIDE, 1.70" L.I.B. AT 9,333' SLM. SAT DOWN W/ BELL GUIDES ON TUBING STUB AT 9,304' SLM (Little effort to hop in). RAN 3.00" x 10' PUMP BAILER TO FILL AT 9,338' SLM (No issues getting by tbg stub). RAN 4-1/2" GS TO 9,333' SLM (No issues getting in tbg stub or back thru over shot). RAN READ 40 ARM (Ext. reach) CALIPER TO 9,304' SLM (Unable to get into stub - No data). 9/18/2019 ***WELL TURNED BACK OVER TO AAO -111, NOTIFIED DSO OF WELL STATUS*** RIH with tubing punch and punch tubing from 9086 to 9096 (reference to original tally), POOH, MU RCT, RIH and cut tubing @ 9104'(4.5' below connection). Pull six joints of 4 1/2" TBG and attach a er orm and set @ 36'. Replace IC seal in CSG spool. Inspect hanger profile with Borescope (ok), Install hanger in wellhead, lock down and test 9/19/2019 (good test), Pull hanger assembly LD hanger assembly, Pull and LD tubing Inspect tubing cut (good cut), Prep rig floor for 4" drill pipe, monitor well - well behaving, Install test plug, Test rams and annular on 4" drill pipe, 9/20/2019 RD testing assembly, Install wear bushing LD WBRRT assembly, Drain water from stack, MU baker packer assembly and RIH picking up 4" drill pipe, Set packer @ 6000', Test 9 5/8" casing to 2500 psi (Good Test). Release 9/21/2019 packer RIH and set Packer (Elements) @ 6197', Test below the packer down the drill pipe to 2500 pss (Good Test), Release packer, POOH laying down drill pipe, Cut drilling line, LD Packer assembly, Pull Wear bushing, Install test plug in wellhead, Testing BOP's, Test plug not 9/22/2019 holdinq pressure, Pull test plug and change seals, Reinstall and lock into well head. Perform shell test, Contact Matt Herrera (AOGCC) gave a witness waiver @ 02:14 hrs, Test 9/23/2019 BOPE, RD test equipment, Prepare and run 4.5" tubing assembly per tally. Run completion and tag tubing stump with no-go . 9073.75' (tubing stub @ 9059.58). Observed shear pins shear with 8k @ btm- 9063.38, Upper - 9071.38. Space out and land hanger in wellhead and test. Overshot No-go 4.43' above tubing stump. Circulate KI -3869 into compeltion fluids to completion fluids. Drop rod & ball. Attetmpt tp pressure up to set 9/24/2019 packers, Not successful. Discuss fwd plan with office, RU slickline, ***WELL 9/1 ON ARRIVAL*** (assist all american rig) SWCP 4517 RIG UP 9/24/2019 ***CONT WSR ON 9-25-19*** RU Slickline. Test lubruicator, Retorq bots on shooting flang. Perform rolling test on PCE. Called Supt for approval. Continue operations on Slilckline WSR. Latched ball & rod PUH, brought rig pumps up to 4 bpm washing through RHCM plug body for 4 bbls. SD with ball & rod attempted to get ball to seat while pumping with not indicaton of trying to choke off or seat in pulg body. Shear off and set slip stop catcher below Sta # 2; top GLM, and pull DKC valve. Rocoverd DKC and broke down looking for problems. Brass shear pins in DKC bent but not sheared. both orings top and bottom in tact. No signs of leakage. Set new DKC in GLM #2'; top GLM. Attempt to get TBG pressured up. No indication of it trying to build. When pump is brough on line there is a delay in getting retunes from IA open to trip tank giving signs that leak path is deep. (Overshot) Call APE Trevor Hyatt and SSupt continue process of elimination. Pull rod & ball and inspect. Hard to tell if it was on the seat in the RHCM. Pull and recover RHCM body looking for issues??? 9/25/2019 Daily Report of Well Operations PBU J -22A ***CONT WSR FROM 9-24-19*** LATCH B&R AT 8982' SLM, PICK UP HOLE WHILE RIG PUMPS TO WASH OUT RHC BODY, SET B&R AT 8982' SLM. RIG UNABLE TO PRESSURE UP ON TBG. SET 4-1/2" SLIP STOP CATCHER AT 3543' SLM. PULL RK-DCK VALVE FROM STA#4 AT 3442' SLM. SET NEW RK-DCK VALVE IN STA#4 AT 3442' SLM. PULL B&R & RHC FROM X -NIP @ 8,985' MD SET 4-1/2" X -SELECTIVE TEST TOOL IN NIPPLES 8,985'& 5,974' (see log for details) 9/25/2019 ***CONT WSR ON 9-26-19*** ***CONT WSR FROM 9-25-19*** RAN 4-1/2" X -SELECTIVE TEST TOOL TO NIPPLES 8,985' MD & 5,974' MD (see log for details) RAN 4-1/2" DND HOLE FINDER (see log for details) SET 4-1/2" RHC -M -PLUG BODY IN X -NIP @ 8,985' MD RAN 4-1/2" CHECK SET TO RHC -M @ 8,985' MD 9/26/2019 ***SWCP 4517 RIG OFF ALL AMERICAN*** Pull out of the hole with X -Selection test tool. Pick up D&D hole finder and run on slickline. Run in the hole and locate the leak between 8,922' and 7.925'- Rig down slickline and 9/26/2019 shooting flange - Install riser. Circulate out Corrosion Inhibitor. Rig up and pull hanger. PJSM-Pull Tubing. Pull hanger to rig floor wt= 95K. Pull 4.5" Tubing while monitoring hole fill. Lay down bad joint #211, Inspect packers. Rig up and run 4.5" VT # 12.6 completions as per 9/27/2019 program to 3.585' Run completion and tag tubing stump with no-go @ 9073.74' (tubing stub @ 9059.58'). Tagged no-go twice, down weight 76 Klbs, Space out, land hanger in wellheadand and LD. Overshot No-go 4.44' above tubing stump. Circulate 312 bbls of 9.8 ppg brine w/KI-3869 ay�G inhibitor down TBG followed by 128 bbls of clean 9.8 ppg bring. Drop ball & rod pressure up and set tandem TNT PKR's. Test down TBG to 3500 psi and chart for 30 min. Bleed back pressure to 2000 psi. Pressure up on IA to 3500 psi and chart for 30 min Bled TBG and 9/28/2019 shear DKC. RU LRS and pump 35 bbls of diesel into IA then u -tube for 1 hr. (LRS Unit 42 Assist All American w/ Freeze Protect) Pumped 40 bbls diesel down TBG to 9/28/2019 freeze protect. All American in control of of well. FWHP's 0/0/0 Rig up lubricator and Set J-3 TWC - Test from below 2,500 psi - Blow down all surface equipment - Nipple down BOP equipment - Nipple up dry hole tree and test - Secure cellar 9/29/2019 and Release rig 15:00 hrs. ***Job CompletE*** T/I/0=0/0/0. Set 6"J TWC #421 @150" for All American. Job Complete. See log. Final 9/29/2019 WHP's TWC/0/0. T/I/O=TWC/0/0. Post All American. RD 6" temp valve #46. RU 6" Cameron upper tree. Torqued to API spec. PT to low 300psi and high 5000psi for 5 min ea. Passed. Pulled 6" J TWC #421 @130". RD 2" I/A O/A piggy back valves. RU 2" 5000 API blind flange. Torqued to API spec. PT to 2500psi. Passed. Job Complete. See log. Final WHP's I/A,O/A OTG. MV 10/3/2019 open SV,WV closed. ***WELL S/I ON ARRIVAL***(post rig) PULLED B&R FROM RHC PLUG BODY @ 8,978' SLM PULLED RK-DGLV FROM STA#1 @ 5,843' MD PULLED RK-DCK VALVE FROM STA #2 @ 3,443' MD 10/9/2019 ***CONT WSR ON 10/10/19*** ***CONTINUED FROM 10/9/19 WSR*** (RWO expense) SET RK-LGLV AT ST #2 (3,443' MD) & RK-OGLV AT ST #1 (5,843' MD). PULL EMPTY 4-1/2" HES RHC -M BODY FROM 8,980' SLM / 8,996' MD. BAIL —3-1/4 GALS OF FINE SAND / RIG TRASH FROM 9,309' TO 9,313' SLM. 10/10/2019 ***JOB IN PROGRESS, CONTINUED ON 10/11/19 WSR*** Daily Report of Well Operations PBU J -22A ***CONTINUED FROM 10/10/19 WSR*** (RWO Expense) BAIL -2 GALS OF FINE SAND / RIG TRASH FROM 9,313' TO 9,318' SLM. PULL EQUALIZING PRONG FROM 2-7/8" PX PLUG BODY AT 9,340' MD (No psi change). BAIL -3-3/4 GALS OF FINE SAND / RIG TRASH FROM 9,318' TO 9,323' SLM. RAN 3.75" G -RING TO 9,321' SLM (Drifted clean, Unable to get deeper or tools to stick). CURRENTLY SETTING UP 3.00" PUMP BAILER W/ 2.25" SNORKEL BOTTOM. 10/11/2019 ***JOB IN PROGRESS, CONTINUED ON 10/12/19 WSR*** ***CONTINUED FROM 10/11/19 WSR*** (RWO Expense) BAIL -2-1/2 GALS OF FINE SAND & RIG TRASH FROM 9,321' TO 9,326' SLM. PULL COMPLETE 2-7/8" PX PLUG BODY FROM 9,325' SLM / 9,340' MD. TAG 2-7/8" WFD ER PATCH W/ 2.25" CENT, S-BLR AT 10,180' SLM / 10,198' MD (No sample or issues). 10/12/2019 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** TREE= • 6' aW FLS _WELLHEAD= IVb OY ACTUATOR=BAKERC TYPE OTB. ELEV = 76.94' Rff WEV= 39.41' BF. ELEV = 40.14' KOP= 2900' Max Angle = 50'@ 10312' Datum ND= 1009T Datum TVD= 880(7 SS 13-3/8" 72#, L-80, D = 12.348' Y. L-80. D = 8 BA1 41/2' TBG, 12.63, 13CR415 VT, .0152 bpf, ID = 3.958' 9065' 412' TBG STUB (0924119)4 9071' Minimum ID =1.310" @ 10198' WFD ER STRADDLE PKR 412'TBG,12.63,13CR415VT,.0152bpf,ID=3.958' 9280' - 4-12' RCT CUT TBG (0627/19)9320' TOP OF 7" LNR 9462' TOP OF 2-7/8' LNR 9474• 1, 12.6#, L$0 BUTT, .0152 bpf, D = 3.958' 9523' - 9-5/8' CSG, 479, L-80 BTRS, D = 9.681' 9711' TOPOFWHPSTOCK10186' LNR, 29#, L-80, .0371 bpf, D = 6.184' 10186' RA TAG 10196' PBTD = 2.372' SAFETY NOTES: DO NOT PUMP METH OR METH CHEMICALBLEND INTO OA DUE TO J 22A NCOMPAT BIILITY W/EPDXY ES N —PLASTIC COATED TBG -'CHROME TBG"' HES X NIP, ID = 3.813" 3LFTMANDRELS ST MD ND PERFORATION SUMMARY TYPE VLV LATCH REF LOG: SWS RST ON 08/30/00 DATE 2 1 ANGLE AT TOP PERF: 43' @ 10200' 21 33 Note: Refer to Produc8on DB for lis tor.cal perf data SE SPF I INTERVAL I owbrsaz SHOT SlY 2' s 10200-10210 O 1m/ o PULLED 2-7/8' PX PLUG(10112119) 2' 6 10226 -10246 O 1127,00 2' 4 10254-10264 O 0920N0 2' 4 10280 -10300 O 09/03N0 PBTD = 2.372' SAFETY NOTES: DO NOT PUMP METH OR METH CHEMICALBLEND INTO OA DUE TO J 22A NCOMPAT BIILITY W/EPDXY ES N —PLASTIC COATED TBG -'CHROME TBG"' HES X NIP, ID = 3.813" 3LFTMANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 3443 3422 5843 5473 21 33 MMG 1 MMG DOME RK SO RK 16 20 10/10/19 10/10/19 1 5921' �-14-12' HES X NIP, ID = 3.813' 5948' 9b/8' X 4-12' HES TNT PKR D = 3.856' 5986' 4-12' HES X NIP, ID = 3.813' 8959' 9S/e' X 4-12' HES TNT PKR ID = 3.856- 8986' 4-12" HES X NIP, ID = 3.813" 9081' 9-S/8'X4-12'UNKIUE OVERSHOT 9144' 4-12' HES X NIP, ID = 3.813" 8172' 9SB" X 4-12' HES TNT PKR ID = 3.856' 9210'4-12"HESX NIP, ID=3.813" 9295' 9-5/8"X4-12" UNIQUE OVERSHOT J JLU UbUJ-VE, U= T2-7/8- NP RED, D = 2.3 PBR I1W HBBP PKR, ID =4.750' OTIS X NP, D = 3.813' = 3.725' 9621' aMD 7i LOGG® 10/29/93 7- VMDOW (J -22A) 10189' - 10195' 10198' - 10216' WFD ERSTRADDLE PKK ID =1.310" (12/16M 11 DATE REV BY I COMMENTS DATE REV BY COMMENTS 1987 ORIGINAL COMPLETION 11 1028/19 1 JNL/JMD I DEPTH CORRECTIDN TO OLD TBG 0826100 MASKEL CTD SIDETRACK 1028/19 MH/JMD GLV C/O (10/10/19) 10/02/18 AAO 111 IRWO 1028/19 MWJMD PULLED 2-7/8' PX PLUG(10112119) 07!02119 AA0111 IRWOBYINTERVENTIONS 0929119 AA0111 I RWO BY INTERVENTIONS 10iD7/19 JMD DRLGHOCORRECTIDNS 11 PRUDHOE BAY UNIT WELL: J -22A PERMIT No:'2001240 API No: 50-029-21698-01 TI I N. RI 3E, 682' FNL 8 803' BP Exploration (Alaska) ti Q N N Q N 01 C C � Y � U � 3 Q C6 c t m L Y ao a) Q Y C Y M N O H Z' i v Q a a c O_ Y U > N N c Z n @ > Cfm O bA Q N vi 0 m Qj L Y Q 3 c N r � C .✓ �n N O Y O> O O n O ncD to to c N O N E a H Y c O o �a@J a) ^ Na EH = �a a arm SJ6i O @J n m ca m E s E o v N m >, Q wa •g +' p v U N H U! w al >O vl Ca C E v l7 oq O U U U O a1 O O N Y �n C h a) O c '� H V N vii w 0 07 Q E r0 ' a1 O O� a� .7. a c m v O O U F -Z va v = W m.—�rci m v� va.-�Ln W c N C O N ~ Um N Ta t>O aim U L w—gym N LO O_ N N 'M d 3 Ciml c £ Y x F=- O al O a O 'c Y r� N to N O c vi u' 3 .o O OHO^ N I, I� F- V N N LLL m N to I-- li F Y r l7 U I -U Y. VI H Vl F- Q 001 001 ti THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean M. McLaughlin Engineering Team Lead BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU J -22A Permit to Drill Number: 200-124 Sundry Number: 319-398 Dear Mr. McLaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such Ru ther time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this Z`9 day of August 2019. 3BDMS�AU6 3 0 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number: 200-124 1 Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6 API Number 50-029-21698-01.00 7, If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU J -22A 9. Property Designation (Lease Number): 1 10. Field/Pools: ADL 028281 PRUDHOE BAY. PRUDHOE OIL 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). 10387 9083 9340 8307 2295 9340 None Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 39-118 39-118 Surface 2575 13-3/8" 38-2613 38-2613 5380/6390 2670/2820 Intermediate 9675 9-5/8" 37-9712 37-8584 6870 4760 Liner 727 7" 9462-10189 8396-8946 7240 5410 Liner 913 2-7/8" 9474-10387 8405-9083 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10226- 10300 8973 - 9023 4-1/2" 12.64t 13Cr85 / L-80 35-9523 Packers and SSSV Type: 4-1/2" HES TNT Packer Packers and SSSV MD (ft) and TVD (ft): 9203 / 8205 4-1/2" TI W HB6P Pecker 9414/8361 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: September 2. 2019 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Sperry, Nathan be deviated from without prior written approval. Contact Email. Nathan.Sperryabp.com Authorized Name: Mclaughlin, Sean M Contact Phone: 907-564-4258 Authorized Title: Engin nng Team Lead - CTD aQ1 n Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that representative may witness Sundry Number: Iter, C1 Z 0 Plug Integrity ❑ BOP Test llr Mechanical Integrity Test ❑ Location Clearance ❑ `('r11 Other: A S C$OPle i X54' -T `5 -"oh i 1 V q yeax-s r -j Post Initial Injection MIT Req'd? Yes 11 No ❑ . 113UM-12±54 Auu 3 0 2019 Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: 10-14c Ly ADBYTHE 9JZ� Approved COMMISSIONER COMMISSION Date: ORIGINAL Iii P-Z-ftea& 17 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Nathan Sperry RWO/CTD Engineer i = by 0NN Date: August 29, 2019 Re: J -22A Sundry Approval Sundry approval is requested to install a straddle packer on J -22A. History and current status: Well J -22A is a vertical, GDWFI producer that was worked over in 2019. The workover scope was to perform a tubing swap. This was after an incomplete workover attempt in 2018 where the tubing was partially retrieved. In 2018, a second tubing cut was performed at -6,025' MD after we were unable to pull the tubing. After the 2019 workover, it was discovered that there is a leak in the 9-5/8" casing at 6,025' MD. Pronosed Plan: All American Oilfield 111 pulling unit will pull the tubing and add a second production packer to straddle the leak on or around September 2nd. 2019. The MASP is 2295 psi. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed tubing swap is attached for reference. Scope of Work: The primary objective of this RWO is to restore well integrity and return the well to operable status. Pre -Rig Prep Work: 1. V: Set TWC. Proposed RWO Procedure: 1. MIRU. ND tree. NU and test BOPE. (Annular, Blind Rams, Mud Cross, VBRs — sized appropriately for 2. Pull 4'/", 12.6#, 13Cr tubing VamTop tubing. 3. Add a second production packer above the casing leak. 4. Run 4'/", 12.6#, 13Cr VamTop tubing with Unique Overshot. 5. Set TWC. ND BOPE. NU and test tree. RDMO. Post rig Work 1. Set Packers. MIT -IA 2. Install flowline, reconnect well, install wellhouse. 3. Pull Ball & Rod. Pull RHC, plug, nipple reducer, Install GLVs. �- K tT-T M-f'T-.s A,ebv RY Lt Nathan Sperry RWO/CTD Engineer 564-4258 CC: Well File Joe Lastufka TREE= 6'CIW FLS VVf3LHEAD= WEVOY ACTUATOR= BAKER OKB. rLEV = REF ELEV = 76.94' 39.41' BF. AEV = 40.14' KOP= 2900' Max Angle = 50" @ 10312' Datum AD= 10097' Datum TVD= 8800'88 D = 12.348" 9-58' CSG, 4711, L-80, D = 8.681' 3, 12.63,13CR86 VT, .0152 bpf, D = 3.959" H 9311' 4-12' RCT CUT TBG(0627/79) 932W Minimum ID = 1.310" @ 10198' WFD ER STRADDLE PKR TOP OF T LNR9462' 4-1/2" TBG, 12.6#, L-80 BUTT, .0152 bpf, D = 3.958" 8622' 9-5/8' CSG, 47#, L-80 BT'S,D = 8.681' 8711' IF VIIHPSTOCK -t 10186' bpf, D=6.184'10186' RA TAG10186' I L /e" LNR, 6.18#, L-80, .0058 bof. D = 2.372" I SAFETY NOTES: DO NOT PUMP METH OR METH J2 2 A BLEND INTO OA DUE TO CHEMICAL � INCOMPATIBILITY WlEPDXY RESIN *"PLASTIC COATED TBG'••CHROME TBG*" 2104' 1--�4-12' HES X NIP. ID = 4 3458 3436 22 1 K::dS DMY NT 0 06/16/19 3 5822 5455 33 KBGd5 DMY NT 0 06/16/19 2 7688 6998 34 KBG-4-5 DMY NT 0 06/16/19 1 9055 8094 41 KBG-43 DMY NT 0 06/16/19 9176' 4-1/2-HESXNIP.D=3.813' 9-5/8"X 5-1/2" HES TNT PKR, ID = 3.856- 4-1 M" .856'4-12" HES X NIP, ID = 3.813" 988" X 5-72" UNIQUE OVERSHOT OTIS XA SUDNG SLEEVE, D = 3.813' 4-12" X 2-7/8' NP RED, D = 231' (0685/14) F PBR TNV HBBP PKR. D = 4.750' OTB X NI— P —j 9474' 11DEPLOYMENT SLEEVE 9480' 4-12" OTIS XN NP, D = 3.725 9622' 4-12' TUBING TAL VMH 60 9621' ELMO -rT LOGGED 10/29/93 7" WIDOW (J -22A) 10189' - 10195' - 10216'WFD ER STRADDLE PKR, D =1.310' (12/16/11) DATE I REV BY PERFORATION SUMMARY REV BY COMMENTS 1987 PIT LOG: SM RST ON 08/30/00 ORIGINAL COMPLETION ANGLEAT TOP PERF: 43" @ 10200' MASKEL Note: Refer to Production fB for historical pert data SIZE SPF NIEWAL Opn/Sqz SHOT SOZ r s 10200 - 10210 C 10102/00 0723/19 r 6 10226 - 10246 C 1127100 2" 4 10254 - 10264 C 0920,00 2" 4 10280 - 10300 C 09/03/00 I L /e" LNR, 6.18#, L-80, .0058 bof. D = 2.372" I SAFETY NOTES: DO NOT PUMP METH OR METH J2 2 A BLEND INTO OA DUE TO CHEMICAL � INCOMPATIBILITY WlEPDXY RESIN *"PLASTIC COATED TBG'••CHROME TBG*" 2104' 1--�4-12' HES X NIP. ID = 4 3458 3436 22 1 K::dS DMY NT 0 06/16/19 3 5822 5455 33 KBGd5 DMY NT 0 06/16/19 2 7688 6998 34 KBG-4-5 DMY NT 0 06/16/19 1 9055 8094 41 KBG-43 DMY NT 0 06/16/19 9176' 4-1/2-HESXNIP.D=3.813' 9-5/8"X 5-1/2" HES TNT PKR, ID = 3.856- 4-1 M" .856'4-12" HES X NIP, ID = 3.813" 988" X 5-72" UNIQUE OVERSHOT OTIS XA SUDNG SLEEVE, D = 3.813' 4-12" X 2-7/8' NP RED, D = 231' (0685/14) F PBR TNV HBBP PKR. D = 4.750' OTB X NI— P —j 9474' 11DEPLOYMENT SLEEVE 9480' 4-12" OTIS XN NP, D = 3.725 9622' 4-12' TUBING TAL VMH 60 9621' ELMO -rT LOGGED 10/29/93 7" WIDOW (J -22A) 10189' - 10195' - 10216'WFD ER STRADDLE PKR, D =1.310' (12/16/11) DATE I REV BY I COMMENTSDATE REV BY COMMENTS 1987 ORIGINAL COMPLETION 08726/00 MASKEL CTD SDETRACK 10/02116 AA0111 RWO 0782119 I AAO 111 I RIND BY INTERVENTIONS 0723119 L JMD UPDATED RVVO TBG 0723/19 JMD CORRECTED TBG CUT DEPTH PR(DHOE BAY UNIT WELL: J -22A PERMIT No: '2001240 API No: 50-029-21698-01 BP Exploration (Alaska) TREE= WELUIEAD= 6'CIw FLS WEVOY ACTUATOR= BAKERC OKB. E -EV = 76.94' REP ELEV - 39AV PROPOSED REV 1 BF. E -EV = 40.14' KOP= 2900' Max Angle = 50' @ 10312' Datum MD= 10097' 13-3!8"72#, L-80, DatumTVD= 880(r SS D-12.348' Note: Refer to Production DB for historical pert data 9-5/8" CSG. 47#. L-80. D = 8.681" 1 2613' 1 1 4792' 1 SAFETY NOTES: DO NOT PUMP METH OR METH BLEND INTO OA DUE TO CHEMICAL INCOMPATIBILITY WIEPDXY J _2 2 A COATED TBG"*HROME BGm "'PLASTIC 2104' 4-12" HES X NIP, ID = 3.813' 3 2 TOP OF 9-5/8" CSG g79Q• / REV BY PERFORATION SUMM9Y DATE REV BY COMMENTS —14-12' HES X NP, D = 3.813' 1 "NOTE: MIT -T AND MIT -IA EVERY ANGLEAT TOP PERF: 43' Q 10200' NS/JMD BULT PROPOSED Note: Refer to Production DB for historical pert data SIZE SPF MHZVAL Opn/Sgz SHOT SOZ 2- 6 10200 - 10210 9-58" X 5-12' HES TNT PKR, D = 3.656' RWO BY INTERVENTIONS 4 YEARS PER THE AOGCC*" 6 10226 - 10246 C 1127100 2- 9-W- CRETACEOUS CSG LEAK 602b' 10254 - 10264 C 0920100 4-12' HES X NP, D = 9.813' 4 10280 - 10300 C 09103/00 -6150' 9-5/8' X 5-12' HES TNT PKR D = 3.656' 4-12" HES X NP, D = 3.813' 4-12' TBG, 12.63,13CR$8 VT, .0152 bpf, D = 3.958' 9311- 14-1,2" RCTCUTTBG (0627!19) 9320' 9326' 9518' X 5-12' UNIQUE OVERSHOT 9340' OTLS XA MED3 Minimum ID = 1.310" @ 10198' 8340 4-12"X2-718'NPRED, D=2.31"(06 WFD ER STRADDLE PKR 9349 4-112' PX PLUG (08/05117)] 9394' TOP OF PBR DP OF 7" LNR 1-t_9462' OF 2-7/8" LNR 9474' BG. 12.6#, L-80 BUR, .0152 bpf, D = 3.956- 9622 8-5/8' CSG, 47#, L-80 BTRS, D = 8.681' 9711 TOPOFWHPSTOCK 10166' 7- LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10166' RA TAG10196' PBTD 10324' - 2 718" LNR 8.18#, L-80, .0058 bpf, D = 2.372' 10367' 9621' ELMDTTLOGG®1D29/93 7- VWWW (J -22A) 10189' - 10195' VJFD ER STRADDLE PKR, 0=1310'(12116111) DATE REV BY PERFORATION SUMM9Y DATE REV BY COMMENTS REF LOG SAS RST ON 08/30/00 ORIGINAL COMPLETION ANGLEAT TOP PERF: 43' Q 10200' NS/JMD BULT PROPOSED Note: Refer to Production DB for historical pert data SIZE SPF MHZVAL Opn/Sgz SHOT SOZ 2- 6 10200 - 10210 C 10/02/00 RWO BY INTERVENTIONS 2" 6 10226 - 10246 C 1127100 2- 4 10254 - 10264 C 0920100 2' 4 10280 - 10300 C 09103/00 PBTD 10324' - 2 718" LNR 8.18#, L-80, .0058 bpf, D = 2.372' 10367' 9621' ELMDTTLOGG®1D29/93 7- VWWW (J -22A) 10189' - 10195' VJFD ER STRADDLE PKR, 0=1310'(12116111) DATE REV BY COMMENTS DATE REV BY COMMENTS 1987 ORIGINAL COMPLETION 0829119 NS/JMD BULT PROPOSED 08/26/00 MASKELL. CTD S13ETRACK 0829119 NS/JMD BUILT PROPOSED REV 1 10/02118 AAO111 RWO 07/02119 AAO111 RWO BY INTERVENTIONS 0723119 JMD UPDATEDRVYOTBG 0723119 JMD CORRECTED TBG CUT DEPTH PRUDHOE BAY UNIT WELL: J -22A PERMIT No: X2001240 API No: 50-029-21698-01 T11 N, R13E, 682' FNL & 803' BP Exploration (Alaska) 1 2 3 4 4'-2" - A 0 D D T-815�sN A SHENKAI SL 13-5M ANNULAR 6'-103/ fi' 3,_1" o SHENKAI SL o 13-5M DOUBLE RAM B B 9' 17/ 18" 81_5EI V-41/18" 31_25/,1 5'-1� 11 C 1'-93/4G o 010 o Oo C 0 0 0 + 0 10111 V-41/2 11 V-41/2 o a D G ZMIN "0 5,_31/2" OPEN CLOSING / OPENNING VOLUME (GAL) 300 ITEMS CLOSING VOL PPENNING VOL ANNULAR 23.59 1 17.41 D 4.39 3.91 D 0.40 0.40 NOTES' ENTS OF TMS DM G TITLE BOP INFORMATION IN TMS DRANANG IS FOR ROPERTY OP WESTERN ERVMCOW.ANY 11AER013-SM BOP STACK t REFERENO AND IS NOT FORLT LREP�MnON��13 noN ov TMISA-000.15-002 WITHOUTTME EXPRE85 SENII.t SFNVICES DATESCALEWDONTCONSTRUCT101. D IMTULL RELEASE TY MJP 01n.IraDleNOFWESTERN ERVICES COW ISflEV �glAMwr.aTY 28/Feb/2018 N.T.S.O DESCRIPTION BY MFT) DATE PROHISITM. MJP �TE01/Mer/2018 w+� A sMEE1 1 OF 1 1 2 3 4 CASED HOLE Well Log Transmittal To: AOGCC Natural Resources Technician 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) 200124 31145 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Temperatur 2) Signed Print Name: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2-1 900 Benson Blvd. Anchorage, AK 99508 GANCPDCna USA ANC.hou.xwh.BP.com and ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907)245-8952 RECEIVED AUG 292019 AOGCC 50-029-21698-01 Date :L4, q I q PROACTIVE DIAGNOSTIC SERVICES, INC., 130W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245.8952 E-MAIL: PDSANCHORAGEPMEMORYLOG COM WEBSITE: WWW.MEMORYLOG.COM https.', madcasedholemysharepointeompersonaLdiane_williams readcasedhole_c.M ommentsDesUop'SP Transmitdoex MU.%fGI V L. i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION �V' 1 .L) REPORT OF SUNDRY WELL OPERATIONS 2019 1. Operations Performed _}'�� Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 OperationsA�I V 6 Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well D Re-enter Susp Well ❑ Other. ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4, Well Class Before Work 5. Permit to 0611 Number. 200-124 3. Address. P.O. Box 196612 Anchorage, Development 0 Exploratory ❑ AK 99519-6612 1 Stratigraphic ❑ Service 1 6. API Number: 50-029-21698-01-00 7. Property Designation (Lease Number): ADL 028281 8. Well Name and Number: PBU J-22A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth', measured 10387 feet Plugs measured 9340 feet true vertical 9083 feet Junk measured None feet Effective Depth: measured 9340 feet Packer measured 9203, 8205 feet true vertical 8307 feet Packer true vertical 9414.8361 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 39-118 39-118 Surface 2575 13-3/8" 38-2613 38-2613 5380/6390 2670/2820 Intermediate 9675 9-5/8" 37-9712 37-8584 6870 4760 Liner 727 7" 9462-10189 8396-8946 7240 5410 Liner 913 2-7/8" 9474-10387 8405-9083 13450 13890 Perforation Depth: Measured depth: 10200 - 10300 feet True vertical depth. 8954-9023 feet Tubing (size, grade, measured and true vertical depth) 4-1/7' 12.6# 13Cr85 / L-80 35-9523 35-8441 Packers and SSSV (type, measured and 4-1/2" HES TNT Packer 9203 8205 true vertical depth) 4.1/2" TI W HBBP Packer 9414 8361 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut-In Subsequent to operation: No Test Available 14. Attachments: (reyixred per 20 Mc 25.070,25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 319-178 Authorized Name: Laslufka, Joseph_X. Contact Name: Hyatt, Trevor Authorized Title: Special t Contact Email: Trevor.Hyatt0bo.com Authorized Signature: �/ / Date: Contact Phone +1 907 564 4627 Farm 10-404 Rewseo 04/2017 �� O f-�0568vi;41BDMS4&vJUL 2 4 2019 Submit Original Only Daily Report of Well Operations J -22A ACTIVITYDATE SUMMARY **WSR continued from 06-21-2019*** (LRS Unit 76 - Assist All American Pulling Unit: Heat 6/22/2019 Seawater) Continue to heat Bug Tank tank to 120*F 24 Hour Summary: AOGCC witnessed BOP test 0630 to 1330. Plug valve between Chk manifold leaked/replaced. Test CMV's 5,6,9 from backside to complete BOP test. LD test joint. Repair hyd leak on upper annular QC (need function test) WS rigging up IA to Chk. MU Shooting flange. 24 Hour Forecast: Pull TWC, Circ crude to SW kill string @ 2211' to surface, Pull hanger/kill 6/22/2019 strip 24 Hr Summary: Test lubricator, pull 2 way check valve, rig down lubricator, test line to red tank, circulate crude from well, Completed circ 50 bbls SW, 100 bbls soap, 250 bbls SW (all -150f) 100 bbl excess to displace soap pill. Clean returns. AAR. PJSM/JSA MU bell nipple. AAO create JSA for pulling hanger. RU Doyon to LD VAM condition B tbg. PJSM/JSA w/ Cameron and Doyon Casing. Pull hanger. Level derrick to minimize drag on the BOP stack and well head. Lay down 52 joints 4.5 Vam Top tubing, no damaged threads or joints laying down. 6/23/2019 124 Hr forecast: LD Kill String. MU SLB BHA w/ overshot, 4" DP TWO= TWC/0/0 PULL TWC. R/U CIW Lubricator# 839 w/ J plug pulling tool & 1-5' ext. PT'd lubricator Low 300psi, High 3500psi. Pulled 6" J TWC #401 @ 135" mid window. R/D 6/23/2019 CIW lubricator. ***Job complete*** FWHP = 0/0/0 24 hr Summary: PJSM Lay out Overshot BHA, Rig up floor, P/U SLB fishing BHA, 8-1/2 OD overshot w/ 4.5" mill over extension, 4-3/4" bumper sub, oil jar, (6) DC's, Accelerator 233' OAL. Set wear bushing. Start run 4" DP. PVT, micromotion flowmeter, Drawworks transmission repaired. RU Doyon to MU DP. Level rig, RIH with 4" Dp F/ 609' T/ 2130', kick drill while tripping all hands in place 1 min 45 sec, RIH F/ 2130'T/ 2930'. 24 hr forecast: RIH 60' above fish, break circ, engage fish, jar loose, monitor weight 6/24/2019 1 increase, monitor well for flow/losses, TOH with fish. 24 hr summary: RIH with fishing BHA 4" dp F/ 2930'T/ 3064', trip tank sensor went down again, Call out tech, Trouble shoot sensor, cleared issue, RIH F/ 3064'T/ 5920', Lost PVT sensor again - replaced and no further problems. Break circulation and flow check well. Latch tbg stub @ 6004'. Unable to jar free. Discuss w/ town. Pick up power swivel to release overshot. RD power swivel, LD dp F/ 6005'T/ 5289', Drill line twisting blocks address twisting issue, LD dp F/ 5289'T/ 5000'. 24 hr Forecast: Lay down 4" drill pipe and fishing BHA, RIH with 4.5 Vam top tubing with 6/25/2019 lovershot on bottom for a recut on the tubing. 24 Hour summary: Continue TOH w/ 4" DP w/ Doyon Casing fF/ 5000' T/ 232', L/D BHA, unload and strap tbg for overshot, cut off run, RIH with overshot and 4.5" Vam top tbg F, 5.75'T/ 3207 24 hour forecast: Next BOP test: 6/29/2019; Last Tripping Drill: 6/26/19; Last H2S/Gas Drill: 6/26-19; Brine 6/26/2019 weight in/out 00:01 hrs: 8.3 12:00 hrs 8.3 Daily Report of Well Operations J-22A 24 Hour summary: RIH with overshot and 4.5" Vam top tbg F, 5.75'T/ 5950', Space out to latch fish, PJSM with SLB, function test line cutter, RIH make cut @ 9300', work pipe unable to break free, rig up power swivel, broke circulation, Pulled 160K while circulating, observed wt loss of 4K, pulled to 175K, pipe pulled free, well u-tubing, displace 9# brine with 8.3 sea water, Monitor well (static) Blow down lines to choke and tanks, rig down power swivel. 24 hour forecast: Next BOP test: 6/29/2019; Last Tripping Drill: 6126/19; Last H2S/Gas Drill: 6/26-19; Brine 6/27/2019 weight in/out 00:01 hrs: 8.3 12:00 hrs 8.3 ***ALL AMERICAN UNIT III*** (SLB E-LINE CONVEYED RCT CUTTER) RIG UP, FUNCTION TEST CABLE CUTTER. CUT TUBING AT 9300' WITH POLLARD RCT. STANDBY FOR RIG TO FREE PIPE. PIPE FREE AFTER CIRCULATING FLUIDS. RDMO. 6/27/2019 ***JOB COMPLETE ON 27-JUNE-2019*** 24 hr Summary: Blow down all lines, prep for move if all the fish is connected, TOH F/ 9300' T19050', Rig Service, TOH F/ 9050' T/ over shot, lay down cut joint and remove over shot, lay down 4.5 buttress, D-1 drill picking up Safety joint, lay down buttress, retrieved both cuts, talked with Nathan recieved permission to run production, run cut joint into overshot slid in smoothly, rig up Doyon torq turn. 6/28/2019 124 hr forcast: Run production tubing, space out on cut off, land tubing, Make up and run in the hole with 4 1/2" 13Cr 12.6# tubing, tagged up at 9147', 153' high. no indication of shear pin shear, talked with Tyler and Nathan, Lay down 2 jints, rig up to test BOPE. Witness waived by Matthew Herra @ 23:30 hrs 6-29-19 24 Hr forecast: Test BOPE 6/29/2019 lWitness waived by Matthew Herra @ 23:00 hrs 6-29-19 ***RIG-ASSIST ALL AMERICAN III***(rwo expense) PULLED 4-1/2" RHC PLUG BODY FROM X-NIP @ 9,140' SLM (-160' below estimated depth) 6/30/2019 ***CONT JOB ON 7/1/19*** 24 Hr Summary: Lay down 2 joints of 4.5 Vam, break out cross overs needed for test plug, rig up running joint, drain stack and run test plug, land test plug fill stack, test BOPE, Make up landing joint, pull and LD test plug, PJSM with SLB slickline crew, rig up slick line, sheaves, functioned cutter, good cut, RIH to retrieve RHC plug from X nipple„ lay plug dwn, RIH with bailer. 24 hr Forecast: Slick line caliper memory log, make dummy runs to calculate access to cut- 6/30/2019 1 off tbg at 9303' Daily Report of Well Operations J -22A ***RIG ASSIST- ALL AMERICAN III*** DRIFTED W/ 15'x 2-1/2" DRIVE DOWN BAILER TO 9,320' SLM (No issues) LOG READ 40 ARM CALIPER FROM TO 9325' SLM TO SURFACE( caliper showed good data ) LOG READ 40 ARM CALIPER FROM 9325' SLM TO 9000' SLM.( data shows overshot stung over tubing stub) SET 4 1/2" RHC PLUG BODY @ 9140' SLM. 7/1/2019 ***WELL LEFT IN CONTROL OF ALL AMERICAN III*** 24 HR Summary: Slick line operations, bailer run, caliper log run, read logs, RIH 2 joints, relog bha, rig down SLB slick line, space out completion, run in and torque lock downs, rig Doyon casing down. 24 hr forecast: Nipple upn shooting flange, rig up lubricator, test lubricator, run and set 2 -way 7/1/2019 Icheck valve and test, nipple down BOPE. finallllllll SET TWC FOR RIG. R/U CIW lubicator #839 w/6" J plug & one 5' EXT. PT'd lubricator low 300psi, High 3500psi. Set 6" J TWC #424 @135" Performed LTT on TWC. R/D CIW 7/2/2019 lubricator. RDMO ***Job Complete*`* 24 Hr summary: N/U shooting flange, Rig up extension and lubricator, test lubricator, set TWC, good test above, test from below observed leakage, no visible leaks at surface, talk with Tyler, monitored psi lose rate, went into a rolling test, 2500 psi rolling test @ 1/2 bpm, Rig down test equipment, flush lines with h2o, bled Koomey dwn un hooked lines, rrig dwn outside fluid lines, N/D BOP, spool koomey hoses, install tree adapter, and dry hole tree, test tree void, visual leak test on tree, release rig @ 23:59 7-2-19. 24 hr forecast: Winds at 35 to 40 mph, when winds allow, complete crane work move rig to 7/2/2019 R-02. TREE= 6'CIWFLS VVELLFEAD= WEVOY ACTUATOR= BAKERC OKB. E_PJ = 76.94' REF ELEtf = 39A1' BF. E J0/ = 40.14' KOP= 2900' Malt Angle = 50° @ 10317 Datum MD= 1009T Datum TVD = 8800 SS 13-3/8' 729, L-80, I-1 2613 D = 12.348' 3,12.63,13CR416 VT, .0152 bpf.ID = 3.958' —t 9311' 4-12' RCT CUT TBG(0627119) 9320' Minimum ID =1.310" @ 10198' WFD ER STRADDLE PKR 12.6#, L-80 BUTT, .0152 bpf, D = 3.958' 962; 9-5/e' CSG, 47#, L-80 SIRS, D = 8.681' 971' TOPOFWHF'STOCK10186' IR 29At, L-80_0371 bpf, D = 6.184'10186' RA TAG 10196' 7/8' LNR 6.189, L-80, PBTD 10324' _ REV BY COMMENTS PERFORATION SLAMI Y 1987 ORIGINAL COMPLETION W LOG: SAS RST ON 06/30/00 082680 J 22A ANGLE AT TOP PERF: 43' @ 10200' INCOMPATIBILITY W/EPDXY RES N —PLASTIC Note: Refer to production DB for historical pert data SIZE SPF INTERVAL OprJSgz SHDT SOZ 2" 6 10200 -10210 C 10102100 2- 610226 - 10246 C 11/27/00 2' 4 10254- 10264 C 09/20/00 06/16/19 2' 4 10280- 10300 C 09/03/00 1 7/8' LNR 6.189, L-80, PBTD 10324' _ 9203' --95/8' X 5-12' HES TNT PKR, D = 3.858' 9241' 442' HES X NIP, ID = 3.813' X —) 9622' "4-12' TUBING TAIL WITH SO SUB 9621' BMD TT LOGGED 1029193 7- W DOW (J -22A) 10189' - 10195' - 10216' JjWFD ERSTRADDLE PKR ID = 1.310't12A6/111 DATE REV BY COMMENTS SAFETY NOTES: DO NOT PUMP METH OR METH 1987 ORIGINAL COMPLETION BLEND INTO OA DUE TO CHEMICAL 082680 J 22A INCOMPATIBILITY W/EPDXY RES N —PLASTIC AAO111 RWO 07IM9 COATED TBG—CHROME TBG- 0723N9 JMD UPDATEDRWOTBG 0723N9 2104- 4-12'HESXNIP,D= 3.8 13' LFTMANDRELS STMN DGAS TWE VLV LATCH PORT DATE 3438 22 KBG45 DMY NT 0 06/16/19 3 1582215455133 KBG4-5 DMY NT 0 06/16/19 2 7688 6998 34 KBG45 DMV NT 0 06116/19 1 9055 6094 41 KBG4-5 DMY NT 0 1 0616/19 9175' 4-12'HES X NIP, D=3.813' 9203' --95/8' X 5-12' HES TNT PKR, D = 3.858' 9241' 442' HES X NIP, ID = 3.813' X —) 9622' "4-12' TUBING TAIL WITH SO SUB 9621' BMD TT LOGGED 1029193 7- W DOW (J -22A) 10189' - 10195' - 10216' JjWFD ERSTRADDLE PKR ID = 1.310't12A6/111 DATE REV BY COMMENTS DATE REV BY COMMENTS 1987 ORIGINAL COMPLETION 082680 MASKELL CTD SIDETRACK 10172118 AAO111 RWO 07IM9 AA0111 RWOBYNTERVENTIOIS 0723N9 JMD UPDATEDRWOTBG 0723N9 JMD CORRECTED TBG CUT DEPTH PRUDHOE BAY UNIT WELL: J -22A PERMIT No: x1001240 API No: 50-029-21698-01 SEC 9, T11 N, R11 3E, 682' FNL 8 803' SP Exploration (Alaska) ALASKA OIL AND GAS CONSERVATION COMMISSION RIG INSPECTION REPORT INSPECT DATE 6/18/2019 P.i.Supv ,�Vz AOGCC INSPECTOR Adam Earl Comm: Rig JAAO 111 Coil Tubing Unit? No Rig ContractorAll American Oilfield Rig Representative SteinerlCastagne Operator BP3 Contractor Representative Bass/Wurdeman Well I PBU J -22A Permit to Drill # 2001240 Sundry _Approval # 319-178 Operation Workover Inspection Location �PBU J pad Working Pressure, W/H Flang, Working Pressure, BOP Stack Annular Preventer Pipe Rams Blind Rams Locking Devices, Rams Stack Anchored Choke Line Kill Line Targeted Turns HCR Valve(s) Manual Valves Flange/Hub Connections Drilling Spool Outlets Flow Nipple Control Lines P Pit Fluid Measurement Flow Rate Sensor Mud Gas Separator Degasser Separator Bypass Gas Detectors Alarms Separate/Distinct Choke/Kill Line Connections Reserve Pits Trip Tank RI(; FI r]!1R P P P P VA P FP =P P 1PP P l9a MISCELLANEOUS PPE p Well Control Trained P Housekeeping FP Well Control Plan p FAILURES: 5 Kelly or TD Valves Floor Safety Valves Driller's Console Flow Flow Rate li Pit Level In Gas Detection Monitor Hydraulic Control Panel Kill Sheet Current CORRECT BY: P Working Pressure Operating Pressure Fluid Level/Condition Pressure Gauges Sufficient Valves Regulator Bypass Actuators (4 -way valves) Blind Ram Handle Cover Control Panel, Driller Control Panel, Remote Firewall 2 or More Pumps Independent Power Supply N2 Backup Condition of Equipment P NA NA NA P P - FP NA P qNA P P See Comments Remote Hydraulic Choke FOV Upstream of Chokes Targeted Turns Bypass Line W 0 a Non fire rated hoses from koomy unit to BOP stack, Kill line had installed threaded unions, not in compliance, no calibration stickers on COMMENTS koomy pressure gauges, and the well sign was on location but not hung in plain sight. I returned 65 hours later to inspect that all issues had been fixed and brought into compliance. A request to proceed was granted from the AOGCC office on koomy control lines based on API 16D,3rd edition Nov.2018. Photos attached. ' 2019-0618_Rig_AA0111 _PBU_J-22A_ae rev. 5-8-18 AAO 111— Rig Inspection 6/18/2019 Photos by AOGCC Inspector A. Earl AAO 111 Rig Inspection —June 2019 Page 1 of 4 Choke Line 6/18/2019 AAO 111 Rig Inspection —June 2019 Page 2 of 4 BOPE Control Lines 6/18/2019 AAO 111 Rig Inspection —June 2019 Page 3 of 4 AAO 111 Follow-up Actions 6/20/2019 Photos Courtesy of BPXA Kill Line Connection — BOP Stack side AAO 111 Rig Inspection —June 2019 Page 4 of 4 Kill Line Connection — Rig side THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU J -22A Permit to Drill Number: 200-124 Sundry Number: 319-178 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, .40 Daniel T. Seamount, Jr. Commissioner DATED this) Z day of April, 2019. R13DMSi{E' APR 15 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ® 9ECEI i . APR 0 4 7; 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Qpe Mon hu own ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Chan A - ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 Exp 5. Permit to Drill Number. 200-124 - 3_ Address : P.O. Box 196612 Anchorage, AK ' 99519E612 Stretigrephic ❑ Service ❑ 6. API Number 50-029-21688-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU J -22A 9. Pmperty Designation (Lease Number): 1 10. Field/Pools: ADL 028281 1 PRUDHOE BAY, PRUDHOE OIL - 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): 10387 9083 9340 8307 2295 9340 None Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20" 39-118 39-118 Surface 2575 13-3/8" 38-2613 38 - 2613 5380 / 6390 2670 / 2820 Intermediate 9675 9-5/8" 37-9712 37 -8521 887400 4760 Liner 727 7" 9462-10189 8396 - 8946 72 5410 Liner 913 2-7/8" 9474-10387 8405-9083 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 1 Tubing Grade: Tubing MD (ft): 10226 - 10300 8973 - 9023 4-1/2" 12.8q 13Cr85 / L-80 35 - 2211 / 6025 - 9523 Packers and SSSV Type: 4-12" TIW HBBP Packer Packers and SSSV MD (ft) and TVD (ft): 9414 / 8361 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14. Estimated Date for Commencing Operations: Apnl 15, 2019 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedum approved herein will not Contact Name: Hyatt, Trevor be deviated from without prior written approval. Contact Email: Trevor.Hyatt&Qbp.com Authorized Name: MUaughlin, Sean M Contact Phone: +1 907 564 4627 Authorized Title: Engineering Team Lead - CTD Authorized Signature: /. J. L.ry �� Y / .. Date: r -/A/1.7 °r rZ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ Test 9_ Mechanical Integrity Test ❑ „Location Clearance ❑ QBOP + Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS>Wv✓ APR 151019 Spacing Exception Required? Yes ❑ No 12( Subsequent Form Required: APPROVED BYTHE IApproved by: COMMISSIONER COMMISSION 41Z:1� Date:+I'z�� ' ORIGINAL Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. 'K'�"L ll''- A dubmit Form and Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt � bp RWO/CTD Engineer Date: Date: April 3, 2019 Re: J -22A Sundry Approval Sundry approval is requested to perform a tubing swap on J -22A to restore integrity to the well. History and current status: Well J -22A is a vertical, GDWFI producer that was CT sidetracked August 2000. Since the well was a CT sidetrack, the original 4-1/2" L-80 tubing was left in place. Due to the corrosive nature of production fluids and L- 80 tubing, the well currently has two (2) tubing patches and is now shut-in for additional TxIA communication. Rather than performing another leak hunt and a possible third patch in the well, it is decided that a RWO will be performed to swap the corroded L-80 tubing with new 4-1/2" tubing. r A caliper was first pulled in 2008 which showed the tubing to be in poor condition with max wall penetrations up to 52% and overall wall loss up to 12%. The tubing continued to deteriorate over the years (calipers in 2011 and 2014 showed max wall penetrations of 61 % and 75% respectively along with overall wall loss of 21 % and 33%) and finally in late 2013 was finally SI for TxIA communication. An E -line LDL program was put together to pin- point the TxIA communication in May 2014. The log was successful in identifying a leak and a patch was later set in June 2014 which restored integrity, proved by a PASSING MIT -T. Well J -22A produced for over two years until TxIA communication plagued the well again. Another LDL log was performed and a new leak was identified shallower in the tubing. A second patch was installed and subsequently PASSED an MIT -T January 2017. After the second patch was installed, the well had six months of steady production until TxIA communication was exhibited for a third a time. A plug was set and MIT's were performed to test the well for operability. The well PASSED a CMIT-TxIA but FAILED an MIT -T. It is now decided to execute a RWO rather than leak hunt and potentially insert a third patch. A workover to pull the existing tubing and install 4.5" 13 chrome tubing was attempted in 2018. The workover scope was planned such that a mechanical barrier was required to be in place just above the reservoir. To achieve this isolation a plug was set in the sliding sleeve above the packer and intended to remain there for the duration of the work. The top 6025' of L-80 4.5" tubing was retrieved. The remaining tubing did not come out so easily. The well is equipped with a polished bore receptacle above the packer. There was concern that the isolation to the reservoir could be compromised with extended jarring; the tubing might pull free at the PBR instead of at the desired tubing cut location. It was elected to suspend work at the time as the approved work scope did not include exposure to reservoir pressure during the workover and weather conditions were deteriorating in early October. It is now planned to complete the original planned scope of work. Proposed plan: All American Oilfield 111 pulling unit will perform a tubing swap on or around May 1 st. 2019. The MASP is 2295 psi. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed tubing swap is attached for reference. Scope of Work: The primary objective of this RWO is to restore well integrity and return the well to operable status. Pre -Rig Prep Work: 1. V: Set TWC. Pre RWO Tree Work Proposed RWO Procedure: 1. MIRU. ND tree. NU and test BOPE. (Annular, Blind Rams, Mud Cross, 2-7/8"x 5-1/2" VBRs) 2. Pull 41/2" 13Cr Kill String. L— a y/f r 44v)4e e --1-,,/�`n© I;,_GG 3. Pull 4Y" L-80 tubing from jet cut made 6/15/18. 4. Run 4'/i', 12.6#, 13Cr VamTop tubing with Unique Overshot. 5. Set TWC. ND BOPE. NU and test tree. RDMO. Post rig Work 1. Set Packer. MIT -IA 2. Install flowline, reconnect well, install wellhouse. 3. Pull Ball & Rod. Pull RHC, plug, nipple reducer, Install GLVs. Trevor Hyatt ROW/CTD Engineer 564-4627 CC: Well File Joe Lastufka WEE= 6'CJWFLS WB-LFfAD= NicEVOY ACTUATOR= BAKERC OKB. ELLV = 76.94' REF ELEV = 39AV BF. ELLV = 40.14' KOP= 2900' Max Angle = 50' @ 10317 Tatum MO= 1009T Dah#n TVD = BBDO SS 13CR-85 VAM TOP KLL STRING, .0125 bpf, D = 3.958' i 3-38' 72#, L-80, 2613' D = 12.348' 9-58- CSG, 47#, L-80, D =i-681 4792' Minimum ID = 1.310" @ 10198' WFD ER STRADDLE PKR .0152 bpf, D = 3.958' 1-t 9622' L-80 BTRS, D = 8.681' 9711' D�- 10186' FRA AG -1-4 ioisa- 6.18#, L-80, .0058 bpf, D = 2.372' J -22A GAS LFT MANDRELS ST MD I TVD DEV PERFORATION SLAIVARY VLV I LATCH REF LOG SVVS RST ON 08/30/00 DATE 3 ANGLE AT TOP PH RF: 43" @ 10200' LBD Note: Refer to Production OB for historical per[ data SIZE SPF INTERVAL Opn/Sgz SEDT SQZ 2' 6 10200 - 10210 • C 10/02/00 9232 8227 42 2- 6 10226 - 10246 - C 1127/00 2" 4 10254 - 10264' C 0920/00 2" 4 10280 - 10300 C 09/03/00 6.18#, L-80, .0058 bpf, D = 2.372' J -22A GAS LFT MANDRELS ST MD I TVD DEV I TY PEI VLV I LATCH I PDE DATE 3 7014 6452 35 LBD DMY RM 0 03/12/14 2 8260 7474 36 LBD DMY f;N 0 05/22/07 1 9232 8227 42 LBD DW RM 0 03/24/09 STA #4 8 #5 = PULLED STATIONS W1 IaW 1082f18 OTIS XA SLIDING SLEEVE, D = 3.813- -9340'1 4-1/2'X 2-78' NP RED, D = 2.31'(06, ,F -is -3-w-7 4-12' PX PLUG (OSM5/17) TIVV HBBP PKR, D = 4.750' OTISX NP. D=3.813' —� 9490' 4-12" OTIS XN NP, D = 3.72: 9622' 4-12' TUBING 7Al VVITFI SO: 9621' BMD TT LOGGED 1029/93 l 7- VMDOW (J -22A) 10189' - 10195' 10198'-1021V j VW -D 62 STRADDLE F D= 1.310" (12116/11 DATE Fill/ BY COMVENTS DATE REI/ BY CONVENTS 1987 ORIGINAL COMPLETION 08128/00 MASKELL CTDSIDETRACK 10/02118 AAO111 RVVO 10/09/18 JMD DR -G HD CORRECTIONS 10/09/18 JL/JMD FNALODEAPPROVAL 04/04/19 JM/JMD ADDED REF ELEV PRIDHOE BAY UIVT WELL J -22A PEFMT No. `2001240 AR No: 50-029-21698-01 SEC 9, T11 N, R1 3E 682' FAL 8 803' FEL BP Exploration (Alaska) TREE = 6" CNV FLS VVELLWAD= WEVOY ACRIATOR= BAKERC INIML KB. 76.94' _EE BF. EF/ = 40.14' KCP= 29W Wx Angle = 50'@ 10317 Datum ND= 1009T Datum TVD = _ 8800' SS PROPOSAL 1-22A tz.3as- 9-5/8" CSG, 47#, L-80, ID = 8.681" 4-1/2' TBG, 12.6#, 13Cr VAM PTOP .0152 bpf, ID = 3.958' 4-12"RCT COT TBG (06/15 —=91 Minimum ID =1.310" @ 10198' WFD ER STRADDLE PKR OP OF 7" LNR OF 2-7/8' LNR ..0152 bpf, ID = 3.958' L-80 BTRS. D = 8.681' MK (c➢M -uz noArvr,"=a. GAS LFT MAPDRELS 1 9300' 1 I4-112" HES X NP, D = 3.813" 9-5/8- X 4-12" I -ES TNTPKR D= 3 88' 4-1/2' HES X NP. D= 3.813' A SLUNG SLEEVE ID = 3.813' X 2-7/8' NP R®, D = 2.31' (06 PBR 9-5/8" TW HBBP W.R. ID = 4.750- 4-112" OTIS X NP. D = 3.813' 9474' N DEPLOYMENT SLEEVE 4-12" OTB XN NP. ID = 3.725- --L_25= .725" —j 9622' N4-1/2"TI.BMTALVMHS0SU8 m21' HELPm TT LOGGED 1029/93 7" VWJ:)OW (J -22A) 10189' - 10195' DATE REV BY CON WEICS DATE RE/ BY 00KNASI S PERFORATION SIIAW RY 0812WW MASKELL CTDSIDETRACK Rff LOG: SVVS PST ON 0&130100 1_1 AAO III INVO AMILE AT TOP PERF: 43' @ 10200' Wte: Refer to Production DB for historical pert data SIZE SPF FITERVAL OprdSgz SHOT SOZ 2- 6 10200 - 10210 O 10102/00 2" 6 10226 - 10246 O 1127/00 2' 4 10254 - 10264 O 09120/00 2" 4 10280 - 10300 O 09/03/00 -uz noArvr,"=a. GAS LFT MAPDRELS 1 9300' 1 I4-112" HES X NP, D = 3.813" 9-5/8- X 4-12" I -ES TNTPKR D= 3 88' 4-1/2' HES X NP. D= 3.813' A SLUNG SLEEVE ID = 3.813' X 2-7/8' NP R®, D = 2.31' (06 PBR 9-5/8" TW HBBP W.R. ID = 4.750- 4-112" OTIS X NP. D = 3.813' 9474' N DEPLOYMENT SLEEVE 4-12" OTB XN NP. ID = 3.725- --L_25= .725" —j 9622' N4-1/2"TI.BMTALVMHS0SU8 m21' HELPm TT LOGGED 1029/93 7" VWJ:)OW (J -22A) 10189' - 10195' DATE REV BY CON WEICS DATE RE/ BY 00KNASI S 1987 ORIGINAL COMPLETION 0812WW MASKELL CTDSIDETRACK 1_1 AAO III INVO 09/18118 JND BOLT PROPOSED D=131W PRUME BAY tIPltT WELL: J -22A PERInTT W: `1001240 API W: 50.029-21698-01 SEC 9, T11 K R13E, 682' FPL & 803-1 BP Exploration (Alaska) 1 2 3 4 41_2' - G G —7 ° 0 A A 3'-$,5/s 1 SHENKAI SL 13-5M ANNULAR 61-103/6' SHENKAI SL 13-5M DOUBLE RAM B B 9'-17/6'1 8'-511 4'-611/6" 111/6" 31.25/8^ C 1'-93/ 11 G 010 G C GG G G D + 0 10111 V -41/2'p o0 00 oio willVir 51-31/211 MIN OPEN CLOSING / OPENNING VOLUME -(GAL) 300 ITEMS CLOSING VOL OPENNING VOL ANNULAR 23.59 17.41 D RAM 1 4.39 3.91 D HCR 0.40 0.40 NOTES: THE CONTENTS OF THIS CRANING PROJECT T1 BOP INFORMIN METHEPROPERTYOFNESTERN ENERGYSERMCESCGRP.ANY 13-5M BOP STACK ORAN/N01FOR GISF REFERENCE ONLY REPRODUCTION OF THIS EIAEROD"�"° A-000-15-002 ORpNN TY ppTE SGIIE 28/Feb/2018 N.T.$ µEIGHT REV IS NOT FOR ORµMNG N1TH011T THE EXPRESSAND PERMISSION OF AE8TERN 1�1pH'^�^^Aa O IMTAL RELEASE TY MJP 01MnQ018 CONSTRUCTION. CONSTRUCTION. ENERGY SERMCES CORP IS STRICTLY PROHIBITED. Rev DESCRIPTION BT APPO DATE APPROVED MJP GATE 512E 01/M8f/2018 A SHEET 1 OF, O 11 2 1 3 1 4 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday,August 7, 2017 9:10 AM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK, OPS Well Pad SW;AK, OPS WELL PAD W; AK, OPS Well Pad Z;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver,Tyson;Wellman,Julie;Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Project Aide;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA);AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Producer J-22A (PTD#2001240)TxIA Communication Confirmed All, Producer J-22A(PTD#2001240)was made under evaluation on 7/17/17 for having sustained inner annulus casing pressure above NOL and failing a TIFL. On 8/5/17 slickline set a tubing plug and fullbore performed a passing CMIT-TxIA to 2,470psi and failing MIT-IA with a 3.6 gal/min leak rate. The failing MIT-IA with measurable leak rate confirms a failure of the primary well barrier. At this time the well is reclassified as Not Operable and will remain shut in and secured. Completed Work/Plan Forward: 1.Downhole Diagnostics: Cold TIFL—Failed 07/15/17 2.Slickline/Fullbore: Load IA&Tubing, set plug,CMIT-TxIA, MIT-T—Completed 8/5/17 CMIT-TxIA passed to 2470psi, MIT-IA failed with 3.6gaI/min LLR while taking returns to flowline. 3.Anchorage PE: Evaluate plan forward. Please respond with any questions, Joshua Stephens Well Integrity Engineerr P 2 020 l X Office: 907-659-8110 SCAVINE® Cell: 907-341-9068 wo From: AK, GWO SUPT Well In e. Sent: Monday, July 17, 2017 12:21 PM To: AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OP ! u• AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad HUQ; AK, OPS Well Pad L ; • , ••S Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pa. • k, Ops West Area TL; 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWeIllntegrityCoordinator@bp.com> Sent: Monday,July 17, 2017 12:21 PM To: AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK,OPS Well Pad SW;AK, OPS WELL PAD W;AK, OPS Well Pad Z;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver, Tyson;Wellman,Julie; Youngmun,Alex;Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Project Aide;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer1-22A (PTD#2001240) Susatined IA Pressure Over NOL Attachments: J-22A.pdf; Producer J-22A(PTD#2001240)TIO Plot 2017-07-17.docx All, Producer J-22A(PTD#2001240)was reported to have sustained Inner Annulus(IA) pressure over Normal Operating Limit (NOL)on 07/14/17. Confirmed pressures were TBG/IA/OA=2460/2470/160 psi.A cold Tubing Integrity Fluid Level (TIFL) test failed, indicating a lack of two competent well barriers.The well is now classified as Under Evaluation, and is on a 28 day clock to confirm or restore barriers,or be secured. Plan Forward: 1) Downhole Diagnostics: Cold TIFL—Failed 07/15/17 2) Slickline/Fullbore: Load IA&Tubing, set plug,CMIT-TxIA, MIT-T 3) Well Integrity Engineer/Anchorage PE:Additional diagnostics as required A wellbore schematic and 90-day TIO plot are attached. Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska SCANNED UG 4Q�f (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 From: AK, A • SUPT Well Integrity Sent: Thursday, Nove .- 2016 1:05 PM To: AK, GWO SUPT Well Integrity; A', i' 2 OSM; AK, OPS GC2 Field 0&M TL; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismo !•u• A; Daniel, Ryan; AK, OPS PCC Ops Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS e •;• RJ; Wellman, Julie; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Co -tions Well Integrity; AK, OPS FF Well Ops Comp Rep; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; •*_i•ewitch, Beau; Pettus, STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIO• • 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well 0 Other:Set Patch i✓h#'-i3 Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 200-124 J 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21698-01-00 7. Property Designation(Lease Number): ADL 0028281 8. Well Name and Number: PBU J-22A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10387 feet Plugs measured feet true vertical 9083 feet Junk measured feet DEC 12 Z016 Effective Depth: measured 10325 feet Packer measured See Attachment feet • true vertical 9040 feet Packer true vertical See Attachment feet �R ni C G Casing: Length: Size: MD: TVD: Burst: Collapse: ,� Structural Conductor 80 20"Conductor 40-120 40-120 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9674 9-5/8"47#L-80 38-9712 38-8584 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10200-10210 feet 10226-10246 feet 10254-10264 feet 10280-10300 feet True vertical depth: 8954-8961 feet feet 8973-8987 feet 8992-8999 feet 9010-9023 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 35-9522 35-8441 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): n ^� Treatment descriptions including volumes used and final pressure: SEAMEDMAR 0 8 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 650 32225 992 1440 1057 Subsequent to operation: Shut-In 0 120 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q • Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name C/atron,Garry R(Wipro) Title PDC Principal Engineer Signature I f L CL.;-;.......---.:::::::: Phone +1 907 564 4424 Date 12/9/16 Form 10-404 Revised 55/'2`015 1/77— Z/b!, ` /7- 3 Lk, 1 2016 Submit Original Only RBDMS DECL • • ,(rs YY 0 0 N as as as as 0 0 coo as a C- 0 0 O O O d d uiI- I-- 0 3 3 COct. 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R --.. 0 o ( E .5. ccnNWW !-Z-1 UJ J- J Q - N a) J J - 1.7. . 1-4- 0_ < ,-, O rnrnOM nO � W vwwQNW a) L11 Q O C to 1- J J D u) 'a Z } zE1- ccn a 0L: Hi- Qcc., a.0« cwnaawt : DU w H 0 Qo c0 c0 O >- 0 0 N 5 r- m r r 0 Q Fat 6"CNV FLS • S TES:COMPOSITE WRAP REPAIR SH WELLF E/YD= McEVOY LEAs NOT MIT OA OVER 1200 PSI DUE TO ACTUATOR= BAKER C .1 -22A DESIGNED PRESSURE RATING OF REPAIR AND DO INITIAL KB.ELE 76.94' NOT PUMP METH OR METH BLEND INTO OA DUE TO BF.ELEV= 40,14' CHEMICAL INCOMPATIBIUTY W/EPDXY RESIN KOP= 2900' Max Angle= 50°@ 10312' ***PLASTIC COATED TBG** Datum MD= 10097' Datum TVD= 8800'SS 2131' --ICA MCO SSSV LAND NP,D=3.813" ..__._. , [13-3/8D I _ GAS LFT MANDRELS 724,L-80,D=12.348" j---1 2613' ST MD TVD DEV TYPE VLV LATCH FORT DATE 4-112"BKR FLO-GUARD ONE TRP — 4473'-4510' 5 3187 3178 15 LBD DOME RM 16 11/15/16 PATCH,0=2.45"(11/07/16) 4 5375 5074 31 LBD DMY RM 0 09/08/16 3 7014 6452 35 LBD DMY RM 0 03/12/14 [9-5/8 CSG,47#,L-80,D=8 681" I-1 4792' ( 2 8260 7474 36 LBD DMY RM 0 05/22/07 1 9232 8227 42 LBD DMY RM 0 03/24/09 TOP OF 9-5/8"CSG H 4797 - 8008'-8045'H4-1/2"BKR KB PATCH,ID=2.45"(6/16/14) 9340 —OTIS XA SLIDING SLEEVE,LI=3.813" Minimum ID = 1.310" 10198' I 9340' j--j4-1/2"X 2-7/8 NP RHS D=2 31 (06/05114) , WFD ER STRADDLE PKR 9394' —j TOP OF PBR Z 9419' H9-5/8"TNY HBBP PKR,D=4.750" I I 9458' —14-1/2"ORIS X NP,D=3.813" TOP OF 7"LNR H 9462' TOP OF 2-7/8'LNR —{ 9474' ' ' 9474' H DEPLOYMENT SLEEVE I I 9490' H4-1/2"OTIS XN NP,D=3.725" 4-1/2"TBG,12.6#,L-80 BUTT,.0152 bpf,ID=3.958" —1 9522' . k— I 9527 --14-1/2"TUBING TAIL WITH SO SUB 9521' H ELMD TT LOGGED 10/29/93 9-5/8"CSG,47#,L-80 BTRS,D=8.681" H 9711' 7"WA+DOW (J-22A) 10189'-10195' 7"LNR,29#,L-80,.0371 bpf,ID=6.184" —1 10186' TOP OF WHIPSTOCK —1 10186' RA TAG —I 10196' 10198'-10216' —WFD ER STRADDLE PKR /•�•�•�•�•�•�•� ID=1.310"(12116/11) PERFORATION SUMMAF2Y ��*�0.�.�.0�/ 8. REF LOG:SWS RST ON 08/30/00 1......S...../ ANGLE AT TOP PERF:43°@ 10200' •444,4.14.........' ` Note:Refer to R-oduction D(3 for historical perf data ` SIZE SFF INTERVAL Opn/Sqz SI-10T SQZ 2" 6 10200-10210 0 10/02/00 ` F61D — 10324' 2" 6 10226-10246 0 11/27/00 2" 4 10254-10264 0 09/20/00 2" 4 10280-10300 0 09/03/00 �Ai�, \io, 2 7/8"LNR,6.18#,L-80,.0058 bpf,ID=2.372" 10387' DATE REV BY CORMENTS DATE REV BY COMMENTS PRUDHOE BAY LHT 1981 ORIGINAL COMPLETION 07/06/16 RCT/JM) GLV C/0(07/04/16) WELL: J-22A 08/26/00 MASK L CTD SIDETRACK 07/26/16 MSS/JMD GLV CO(07/22/16) PERMT No: 2001240 06/12114 JTG/JM? PULL PLUG/NP RED&PLUG(6 09/12/16 ZV/JMD SET XX PLUG/GLV CO(09/08/16) AR No: 50-029-21698-01 06/19/14 MIYJM) SET BKR KB PATCH(06/16/14; 11/16/16 DIS/JMD SET FLO-GUARD PATCH(11/07/16) SEC 9,T11N,R13E,682'FM_&803'FEL 06/25/14 DLH/JMD PULL PLUG/GLV 0/0(06/23/14 11/16/16 CJWJM) GLV C/O(11/15/16) 07/05/16 RCT/JM) MNORCORRECTIONS 12/12/16 JMMJM1 RILED XXPLUG(11/15/16) BP Exploration(Alaska) IV O- 221 • Z:iCoG3 ®_�,► WELL LOG OCT 2 7 201€; TRANSMITTAL DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. \O2Y/201(a M.K.BENDER To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2-1 900 Benson Blvd. Anchorage, AK 99508 gancpdcabp.com and SCANNED NOV 1 42016 ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 25-Sep-16 J-22A BL /CD 50-029-21698-01 2) Signed : Q' " J,/avlo) ..�:+k: Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(CIDMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\Transmittal S heets\BP_Transmit.docx • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, September 08, 2016 7:50 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Facility OTL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad RJ;Wellman,Julie; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington,Aras J;Wallace, Chris D (DOA) Subject: NOT OPERABLE: Producer J-22A(PTD#2001240)TxIA Communication All, Producer J-22A(PTD#2001240) passed a Combination MIT-TxIA to 2500 psi on 09/08/16.When attempting to bleed the IA to achieve the required differential for an MIT-T,the tubing pressure tracked the IA pressure.The well is reclassified as Not Operable,and will remain secured with a downhole plug until tubing integrity is restored. Thanks, • - ...; �� Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 WANEDh'1\9 c) �� s •1 C:(907)943-0296 " t u ` U „J H:2376 Email: AKDCWellIntegritYCoordinator@BP.com From: AK, GWO • . Well Integrity Sent: Monday, August 15, 6 8:05 AM To: AK, OPS GC2 OSM; AK, OPS ield O&M TL; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ry. 'K, OPS PCC Ops Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad RJ; We ' Julie; AK, GWO SR Slickline WSL; 'Regg, James B (DOA) (iim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Inte. '+ Grey, Leighton; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; 'chris.wallace@alaska.gov' (chris.wallac-a.laska.•ov); Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; ' - nicki, Oliver R; Tempel, Troy; Worthington, Aras Subject: UNDER EVALUATION: Producer J-22A(PTD #2001240) Sustained IA Casino • essure above MOASP All, Producer J-22A(PTD#2001240)was reported to have sustained inner annulus(IA)casing pressure abov- � OASP on 08/13/16.Confirmed pressures were TBG/IA/OA=2310/2310/180 psi.The well is reclassified as Under Evalu. ion for further diagnostics. Plan Forward: 1. Slickline:Set TTP,CMIT-TxIA, MIT-T 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday,August 15, 2016 8:05 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Facility OTL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad RJ;Wellman,Julie;AK, GWO SR Slickline WSL; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; Grey, Leighton;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: UNDER EVALUATION: Producer J-22A(PTD#2001240) Sustained IA Casing Pressure above MOASP All, Producer J-22A(PTD#2001240)was reported to have sustained inner annulus(IA) casing pressure above MOASP on 08/13/16.Confirmed pressures were TBG/IA/OA=2310/2310/180 psi.The well is reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. Slickline:Set TTP,CMIT-TxIA, MIT-T 2. Fullbore:Assist Slickline; Load IA and Tubing,CMIT-TxIA, MIT-T 3. Well Integrity Engineer:Additional diagnostics as needed Please reply if in conflict with proposed plan. Thanks, Adrienne McVey SCANNED J4N I8 201? Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWellIntegrityCoordinator@BP.com 1 Ima~ '~roject Well History File Cover(~' ~ge 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. ~~ j~)- _j.~, ~ Well History File Identifier RESCAN DIGITAL DATA [] Color items: ~ Diskettes, No. I [] Maps: OVERSIZED (Scannable) [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERY~INDY Project, Proofing BY: BEVERLY ROBIN VINCENT SHERYGWINDY [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: ' '~~.~ /S/ · Scanning Preparation = TOTAL PAGES BY: BEVERLY ROBIN VINCENT SHERY~~I/INDY Production Scanning Stage l PAGE COUNT FROM SCANNED FILE: ~_~...~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,~ YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREP~/'~IE'S W~RE FOUND: _L_.._.~_YES ,~ NO I RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /S/ Quality Checked 12/10/02Rev3NOTScanned.wpd STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other trj PATCH 10198' - 10216' Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown 0 Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development la Exploratory ❑ • 200 -1240 3. Address: P.O. Box 196612 Stratigraphic El Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 21698 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: - ADLO- 028281 PBU J -22A 10. Field /Pool(s): ■ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10387 feet Plugs (measured) None feet true vertical 9082.8 feet Junk (measured) None feet Effective Depth measured 10325 feet Packer (measured) 9414 10198 10210 feet true vertical 9039.71 feet (true vertical) 8361 8953 8961 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 37 - 117 37 - 117 1490 470 Surface 2001' 13 -3/8" 72# L -80 36 - 2037 36 - 2037 4930 2670 Surface 574' 13 -3/8" 72# S00 -95 2037 - 2611 2037 - 2611 Production 9677' 9 -5/8" 47# L -80 35 - 9712 35 - 8584 6870 4760 Liner 733' 7" 26# L -80 9462 - 10195 8396 - 8950 7240 5410 Liner 913' 2 -7/8" 6.16# L -80 9474 - 10387 8405 - 9083 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - _ _ - True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 35 - 9522 35 - 8441 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" TIW HBBP Packer 9414 8361 2 -7/8" WFD ER Packer '5),$a ` . 10198 8953 2 -7/8" WFD ER Packer c 4 p i 10210 8961 .4 -/v 7 12. Stimulation or cement squeeze summary: 0 4 ; Intervals treated (measured): �0 r� f ,,,,f,,._ j' s , Treatment descriptions including volumes used and final pressure: '" O ss7 ph 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 702 29,315 943 1,593 Subsequent to operation: 663 34,375 549 1,433 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development la ,. Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil _ la Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE] GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nam a Lastufk ilk Title Data Manager ln Signatur Phone 564-4091 Date 1/9/2012 I ll Form 10 -404 Revised 10/201� " /Z . /� a--- Submit Original Only J -22A . 200 -124 PERF ATTACHMENT . Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base J -22A 9/3/00 PER 10,280. 10,300. 9,009.87 9,023.28 J -22A 9/20/00 APF 10,254. 10,264. 8,992.05 8,998.92 J -22A 10/2/00 APF 10,200. 10,210. 8,954.13 8,961.37 J -22A 11/27/00 APF 10,226. 10,246. 8,972.65 8,986.54 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET _SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE III MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE III • • J -22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/9/2011 ; ** *JOB CONTINUED FROM 09- MARCH - 2011 * ** (ELINE SCMT CBL) ' WELL FLOWING ON ARRIVAL, WING /SSV =OPEN, SWAB= CLOSED, IA/OA =OTG, INITIAL SHUT IN T /I /0= 2400/700/150 !TOOL FAILURE UNABLE TO COMPLETE JOB DUE TO TIME RESTRAINTS, 'CLOSE OUT PERMIT SSV /SWAB/WING= CLOSED, MASTER =OPEN. LEAVE LOCATION ** *JOB IN PROGRESS AND CONTINUED ON 11- MARCH -2011 WSR * ** 3/9/2011 T /I /O= 2450/800/180. Freeze protect FL/ Assist E -line with SCMT log. Pumped 10 bbls of neat methanol and 73 bbls of crude to freeze protect. Pumped 5 bbls neat spear, followed by 240 bbls of 1% kcl at 5 bpm. down TBG to kill well. Slowed rate to !.5 bpm. while E line RIH. E -line having tool problems and coming out of hole. Pumped total of 311 bbls of 1% KCL. Pumped 2 bbls neat methanol to sweep surface lines. Pumped 35 bbls to freeze protect TBG. E -line still on well at LRS departure. FWHP= 0/80/60 3/10/2011 * ** JOB CONTINUED FROM 9- MAR -2011 * ** (E -LINE SCMT) WELL SHUT IN ON ARRIVAL INITIAL TWO = 0/0/0 PSI 'INITIAL VALVES CONFIGURATION = MASTER = OPEN, SSV, SWAB = CLOSED RIH AND TIED IN TO JEWELRY. WAITED FOR LRS TO KILL THE WELL WITH .240 BBLS OF 1% KCL AT 5 BPM. AFTER WELL WAS KILLED LRS PUMP RATE WAS DECREASED TO 0.5 BPM. ; CONTINUE RIH TAGGING BOTTOM AT 10300'. 2 UP LOGGING PASSES WERE '. PERFORMED AT 30 FPM FROM 10300' - 9450'. LRS PUMPED A TOTAL OF 290 BBLS OF 1% KCL. CONFIRMATION OF GOOD DATA WHILE LRS PUMPED 75 BBLS OF CRUDE TO FREEZE PROTECT WELL ON TOPOF1 %KCL. LOG CONFIRMED THAT THERE IS A GOOD CEMENT BOND IN ALL THE PERFORATION ZONES AND FROM TD TO TOC AT 9910 FT. FINAL VALVES CONFIGURATION = MASTER = OPEN. SSV, SWAB = CLOSED FINAL T /I /O = 0/0/0 PSI ' ** *JOB IN PROGRESS AND CONTINUED ON 11- MAR -11 WSR * ** 3/10/2011 T/I/O= 0/60/40 temp =s /i Assist E -Line w/ SCMT log... Pumped 5 bbls neat methanol spear, followed by 240 bbls of 1% KCL to load... Pumped an additional 37 bbls of 1% :KCL and 88 bbls of crude while E -Line logged... IA & OA = OTG... E -Line still on well i upon LRS departure... FWHP= 0/6040 3/11/2011 *** JOB CONTINUED FROM 10- MAR -2011 * ** (E -LINE WFD STRADDLE PKR) IWELL SHUT IN ON ARRIVAL INITIAL TWO = 0/0/0 PSI 1 INITIAL VALVES CONFIGURATION = MASTER = OPEN, SSV, SWAB = CLOSED IA/OA OTG ;RIH WITH WFD STRADDLE PACKER, MAX OD = 2.24 ", SAT DOWN ON LINER TOP AT 9474', UNABLE TO PASS. 'CHANGE OUT WLEG ON STADDLE. ** *JOB IN PROGRESS, CONTINUED ON 12- MARCH -2011 WSR * ** • . 3/12/2011 ** *JOB IN PROGRESS, CONTINUED FROM 11- MARCH - 2011 * ** (E -LINE WFD STRADDLE PKR) ;SET WFD LOWER STRADDLE PACKER, MID ELEMENT SET DEPTH = 10215', ;DEPTH REFERENCED TO SLB RST DATED 30 -AUG -2000 ;FINAL VALVE POSITIONS: MASTER = OPEN, SSV, SWAB, WING = CLOSED, IA/OA = OTG FINIAL T /I /O = 0/60/20 1WELL SHUT -IN ON DEPARTURE 1 : ** *JOB COMPLETE * ** 6/17/2011i'*** WELL SHUT IN ON ARRIVAL * ** ;RIG UP SWCP LANDLINE #11 ! * ** CONT WSR 6/18/11 * ** 6/18/2011 * ** CONT WSR FROM 6/17/11 * ** ISET SLIP STOP C -SUB AT 5508' SLM CURRENTLY RIH TO PULL STA #4 RM -DGLV * ** CONT WSR ON 6/19/11 * ** 6/19/2011: * ** CONT WSR FROM 6/18/11 * ** PULL RM -DGLV FROM STA #5 AT 3154' SLM (3187' MD), PULL RM -DGLV FROM s STA #4 AT 5348' SLM (5375' MD) SET RM -LGLV (16/64" PORTS, 1500# TRO) IN STA #5 AT 3164' SLM (3187' MD) 1 * ** CONT WSR ON 6/20/11 * ** 6/20/2011 * ** CONT WSR FROM 6/19/11 * ** 'SET RM -OGLV IN STA# 4 AT 5348' SLM (5375' MD) PULL SLIP STOP C -SUB FROM 5508' SLM * ** WELL LEFT SHUT IN ON DEPARTURE, PAD OP NOTIFIED * ** 7/3/2011 1620/1680/200. Temp= 132 °. Bleed IA to 700 psi (Eval TxIA comm). No AL. IA FL @ 5375', Sta #4, OGLV (288 bbls). Bled IA from 1680 psi to 700 psi to UR ;tank (all gas) in 2.5 hrs. IA FL unchanged. During IA bleed, TP & OAP decreased 20 psi. Monitored for 30 mins. WHPs unchanged. Job complete. Final WHPs= 11600/700/180. 1 SV =C. WV, SSV & MV =O. IA & OA =OTG. NOVP. ._..® 7/4/2011T /I /O= 1620/700/190. Temp= 133 °. WHPs (Post IA Bleed). No AL. TBG & IA pressure unchanged. OAP increased 10 psi overnight, SV= C. WV, SSV, MV= 0. IS, OA= OTG. NOVP. 7/5/20111*** WELL FLOWING ON ARRIVAL. * ** 'TAGGED 2 -7/8" WFD LWR ANCHOR @ 10,200' SLM (10,213' ELMD, no issues, imp of f.n.). * ** WELL S/I ON DEPARTURE, NOTIFIED PAD OP OF WELL STATUS. * ** 7/6/2011 T/I/O= 2300/700/100 ( Assist E -Line / RST Log) Pumped 5 bbls neat meth and 355 ' bbls 1% KCL down the TBG while a -line made logging passes. Freeze protected the !TBG w/ 60 bbls crude. RDMO / FWHP= 0/700/100 wing =shut / ssv =shut / 1 : master =open / IA and OA open to gauges. Operator notified of departure. • 7/6/2011 ***WELL SHUT IN ON ARRIVAL * ** (ELINE RST- SIGMA) INITIAL T /I /O= 1600/650/100 PSI ?RIH WITH MH22 /2XEQF43 /PBMS /RST/ OAL =47', OAW =190# FISHING NECK !SIZE= 1.38" !PUMPED 1.5X WELLBORE VOLUME OF 1% KCL BEFORE LOGGING TO 'ELIMINATE GAS IN WELLBORE !LOGGED 30, 60, 60 FPM UP PASSES FROM 10207' -9600' UNABLE TO DETERMINE FIELD PICK GOC, REFER TO DCS BECAME STUCK IN WEATERFORD PACKER AT 10221' AFTER SETTING DOWN ON IT BETWEEN PASS #2 AND #3. PULLED FREE AFTER PULLING UP TO j `2100# MULTIPLE TIMES. PER WEATHERFORD THE PACKER RELEASE= 2680 #, 'PACKER SHOULD STILL BE IN PLACE. ;FINIAL T /I /O= 0/700/80 PSI '. ** *JOB COMPLETE * ** 8/8/2011; T/I/0= 1480/740/190. Temp =134. Strap conductor (pre -top job). No AL. Conductor' void is 4'10" (1.1 bbls); conductor is 20 ". Cellar is 42" deep. ISV =C. WV, SSV, MV =O. IA, OA =OTG. NOVP. ! 12/15/2011' ** *WELL FLOWING ON ARRIVAL ** *(profile modification) TAGGED 2 -7/8" WFD ER PACKER @ 10,186' SLM W/ 2.25" L.I.B. (Impression of packer top). • ** *JOB IN PROGRESS, CONTINUED ON 12/16/11 WSR * ** 12/16 /2011; ** *CONTINUED FROM 12/15/11 WSR ** *(profile modification) -SET 2 -7/8" x 21' UPPER WFD ER PACKER ASSEMBLY INTO LOWER ANCHOR @' 10,215' ELM. ** *WELL FLOWING ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS * ** FLUIDS PUMPED BBLS 4 DIESEL 32 NEAT METH 256 CRUDE 953 1% KCL 1245 TOTAL TREE = ' McEVOY 6 SAFETY NOS: COMPOSITE WRAP REPAIR SH WELLHEAD = MCEVOY LEAK -DO j! MIT -OA OVER 1200 PSI DUE TO ACTUATOR = OTIS J -2 Z A DESIGNED PRESSURE RATING OF REPAIR AND DO KB. ELEV = 76.9 NOT PUMP METH OR METH BLEND INTO OA DUE TO BF. ELEV = 40.14' CHEMICAL INCOMPATIBILITY W /EPDXY RESIN KOP = 2900' Max Angle = 50 @ 10312' I 2131' I - 1 CAMCO SSSV LAND NIP, ID = 3.813" I Datum MD = 10097' Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD 1VD DEV TYPE VLV LATCH PORT DATE 113 -3/8" 72 #, L -80, ID = 12.348" I-1 2613' I - 4 5 3187 3178 15 LBO DOME RM 16 06/19/11 4 5375 5074 31 LBD SO RM 20 06/19/11 in 3 7014 6452 35 LBD DMY RM 0 03/24/09 2 8260 7474 36 LBD DMY RM 0 05/22/07 I9 -5/8" CSG, 47 #, L -80, ID = 8.681" I-I 4792' I 1 9232 8227 42 LBD DMY RM 0 03/24/09 'TOP OF 9 -5/8" CSG I-I 4792' I ` 1 1 / I 9340' H OTIS XA SLIDING SLEEVE, ID = 3.813" I Minimum ID = 2.372" @ 9474' J I 9$94' I-1 TOP OF PBR TOP 2 -718" LINER IS g 1 9419'j-19-5/8" TIW HBBP PKR, ID = 4.750" I 1 I 9458' I-14-1/2" OTIS X NIP, ID = 3.813" 1 'TOP OF 7" LNR I—I 9462' I TOP OF 2 -7/8" LNR H 9474' 1 • r 1 9474' H DEPLOYMENT SLEEVE I I II I 9490' H4 -1/2" OTIS XN NIP, ID = 3.725" I 14-1/2" TBG, 12.6 #, L -80 BUTT, .0152 bpf, ID = 3.958" I - 1 9522' I , N ---J 9522' 1--- 14 - 1/2" TUBING TAIL WfTH SO SUB I 1 9521' H ELMD TT LOGGED 10/29/93 I I9 -5/8" CSG, 47 #, L -80 BTRS, ID = 8,681" H 9711' 1-41 L. 7" WINDOW (J -22A) 10189' - 10195' 17" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" I—I 10186' I I TOP OF WHIPSTOCK I—I 10186' IRA TAG 1-1 10196' I \ - 10216' I — WFD ER STRADDLE PKR, ••••■•■■ 10= 1.310" (12/16/11) ■ • • • 4 • • * PERFORATION SUMMARY � •- • , REF LOG; SWS RST ON 08/30/00 ` ANGLE AT TOP PERF: 43" @ 10200' Note: Refer to Production DB for historical perf data ` PBTD — 10324' 1 SIZE SPF INTERVAL Opn /Sqz DATE 2" 6 10200 - 10210 0 10/02/00 2" 6 10226 - 10246 0 11/27/00 �R 2" 4 10254 - 10264 0 09/20/00 lik ' rt' 2" 4 10280 - 10300 0 09/03/00 1 2 7/8" LNR, 6.18 #, L -80, .0058 bpf, ID = 2.372" I - 1 10387' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ik 1981 ORIGINAL COMPLETION 06/25/11 MSS/ PJC GLV C/0 (06/19/11) WELL: J -22A 08/26/00 MASKELL CTD SIDETRACK 12/16/11 LEC/ PJC STRADDLE PATCH (12/16/11) PERMIT No: '2001240 06/01/09 MBM/TLH GLV C/0 (03/24/09) API No: 50- 029 - 21698 -01 10/27/09 TTW /SV SAFETY NOTE 1 SEC 9, T11 N, R13E, 682' FNL & 803' FEL 10/27/11 TQ/ PJC SFTY NOTE (COMPOSITE WRAP) 03/26/11 RRD /PJC SET LOWER PKR (03/12/11) 1 BP Exploration (Alaska) 04/28/11 • Schlumberger NO. 5729 Alaska Data 8. Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8. Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 15-09A BBKA-00096 PRODUCTION PROFILE I 93 ••• 03/14/11 1 ... 0‘1 1 17-06 BBKA-00094 INJECTION PROFILE () „( t 4 — Asg 03/10/11 1 teir . 1 C-12B BAUJ-00064 MEM PRODUCTION PROFILE ..., 03/08/11 G-23B BLPO-00079 MEM PRODUCTION PROFILE ' q — Iqi 03/09/11 1 Me I 11 16-08A BJGT-00022 GLS • • — _ ,,.__ 03107/11 1 r... -01 1 02-18B BLP0-00087 Luctii:impty. eximr.1.1111112031111111 1 J-22A BJGT-00023 CBL 03/10111 111.11=11 1 L-210 BLPO-00086 MEM INJECTION PROFILE ' IllY;CYZI 03123111 1 WIWI/ r 1 V-105 BLPO-00091 MEM INJECTION PROFILE ..... ... -, 11=11123013111•11111, 1 V-220 BBSK-00065 INJECTION PROFILEANFL IMgrafir4 . ,1.1—.11MINIIS1111111MAIMIZ:109 1 V-212 8D88 MEM INJECTION PROFILE c • - . 04/03/11 1 te r #a 1 III L-214A BCRJ-00073 INJECTION PROFILE .,„,* , ,-• itie . 03/18/11 1 Fei/We 1 V-223 BAUJ-00071 MEM INJECTION PROFILE gr:„,,,WErellnreigi 1 V-217 BAUJ-00077 V14 111■1114$ 01) II:Jail I i 1 3-05/0-29 BG 411-00043 IEMIIIMMXIMI 1 1-47A1M-20 BLPO-00092 MEM PRODUCTION PROFILE d • * - (3 04/03/11 1 1 1-25A/K-22 BBSK-00057 CBL q -4. - o _ - 03/13/11 I • ,_ 1 S-01C BCUE-00113 MEM CBL r, ..., 03/17/11 i •01;1=111111 1 11-30 BD88-00097 MEM INJECTION PROFILE -ItiptileMIIMIIIIII:1311471:VC4rV 1 04-11A NMI-00134 INJECTION PROFILE UM O - —4 i 03/24/11 1 — ikl; 1 P2-41 BG4H-00044 PRODUCTION PROFILE • 03/22/11 1 an.; IA D-268 BMSA-00009 imomplial .: . rIstimi.1111=101=11:1=11FiTmtviadimi 1 02-18B BLPO-00087 MEM PRODUCTION PROFILE ? as —i Irt. 03/24/11 1 Z-20 BP5G-00010 GLS i lrir -/ 0 0 03/29/11 I e nqs, 1 Y-29A BCUE-00122 MEM LDL t iii ea_.: c ya / 03/20/11 _ 1 D 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Alaska Data 8. Consulting Services Petrotechnical Data Center LI22-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd Anchorage, AK 99503-2838 • 1 k\ 1 2.°V STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSIl"!A REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q WH REPAIR Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ FURMANITE Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ WRAP 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^~ Exploratory ^ _ 200-1240 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-21698-01-00 8. Property Designation (Lease Nam 9• Well Name and Num er: ~ ADLO-028281 J 22A 10. Field/Pool(s): MAR 1 0 201D PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: ~~~~. '~ Total Depth measured 10387 feet Plugs (measured) None feet • true verticai~ 9082.8 feet Junk (measured) None feet Effective Depth measured 10325 feet Packer (measured) 9419 true vertical 9040 feet (true vertical) 8365 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2613 13-3/8"72# L-80 37 - 2613 37 - 2613 5380 2670 Intermediate 9712 9-5/8" 47# L-80 37 - 9712 37 - 8584 6870 4760 Production Liner 727 7" 26# L-80 9462 - 10189 8396 - 8946 7240 5410 Liner 913 2-7/8" 6.16# L-80 9474 - 10387 8405 - 9083 13450 13890 Perforation depth: Measured depth: O 10280 - 10300 O 10254 - 10264 O 10200 - 10210 O 10226 - 10246 True Vertical depth: 9009.87 - 9023.28 8992 - 8999 8954 - 8961 8973 - 8987 _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 SURFACE - 9522 SURFACE -8441 Packers and SSSV (type, measured and true vertical depth) 9-5/8" TIW HBBP PKR 9419 8365 12. Stimulation or cement squeeze summary: r ';~;. ~ ~~ c ~~ Intervals treated (measured): 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: SI Subsequent to operation: 820 35156 931 1081 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N Contact Gary Preble f ,T•i2'~a Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 3/9/2010 ~~ ~ ~ ~ ~ „-..,,.. ~.~r~~,. „~,,,,~ 1'it3DNf~ MAK 11 N1U ~~_ .3•/Z . /o ,~ /~C,~ • J-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/9/2009iT/I/0=35/0/0. Temp=S1. Assist with open bleed for Furmanite composite wrap (SH repair). Maintain 24 hr open bleed on OA during SH Furmanite i wrap. Atmosphere test prior to start of Furmanite wrap, Oxygen=20.7%, LEL's=0%, H2S=0%, C0=0%. Night crew continued open bleed on the OA. Furmanite Techs applied 1st set of layers of carbon fiber. Position heater trunk to allow curing overnight. 3/10/2009 T/I/0=35/0/0. Temp=S1. Maintain open OA bleed for Furmanite composite wrap (SH repair). **Continued from day shift'"'" Maintained open OA bleed .while curing Furmanite filler wraps. Furmanite Techs appllied 2nd set of layers of carbon fiber wrap. Allow to cure overnight. Final T/I/0=35/0+/0. WV=C. SV, SSV, MV=O. IA, OA=OTG. NOVP. 3/10/2009 T/I/0=35/0/0 Temp=S1. Assist Furmanite, hold open bleed (SWH repair). Maintain 24 hr open bleed on OA during Furmanite wrap. Atmosphere test prior to start of Furmanite wrap, Oxygen-20.7%, LEL=O%, H2S=0%, C0=0%. ! .Day crew continued open bleed on OA. 3/11/2009 T/I/O 35/0/0+. SI. Open OA bleed for Furmanite composite wrap SH repair. `Continue open OA bleed while Furmanite crew installs wrap's. Finished `installing wraps and continue open OA bleed. Night crew to continue OA open bleed. Furmanite Techs applied final layers of carbon fiber wrap. Composite Wrap application complete. Positioned heater trunk to allow heat curing for 7 days. 3/11 /2009 3/1 T/I/0=35NAC/0+. Temp=S1. Maintain open OA bleed for Furmanite composite wrap. (SH Repair). Continued from day shift. Maintained an open OA bleed while curing Furmanite wraps from Starting Head to Surface Casing. Final WHP's = 35/VAC/0+. WV = C. SV, SSV, MV = O. IA, OA = OTG. NOVP. ~.~..,.~..~ a _ ~~..~..~ TIO=35/vac/0+. SI. Open OA bleed for Furmanite composite wrap SH repair. Continue open OA bleed from night crew. SI OA bleed @ 1500 hrs, OAP=O psi and monitor OAP BUR. In 30 mins OAP remained unchanged, continue to monitor OAP for another 1.5 hrs OAP has positive pressure. Final W HPs=30/vac/0+ SV,WV=C. SSV,MV=O. IA&OA OTG. NOVP ~~m . ~.~...~... __ _. _ ~ _. 3/13/2009 T/I/0= 35/0/0+. Temp= SI WHPS, (post Furmanite). One heater on location cheating cellar. TP,IAP,OAP unchanged. ?SV,WV= C. SSV,MV= O. IA,OA= OTG. NOVP. • 3/14/2009 T/I/0=30/0+/6. Temp-SI. WHP's (Furmanite). Heater in well house. OAP ,increased 6 psi overnight. Bled OAP from 6 psi to 0+ in 3 mins (all gas). Monitor for 30 mins. OAP unchanged. Final WHPs=30/0+/0+. SV,WV=closed.SSV,MV=open.lA,OA=OTG.NOVP. 3/15/2009 T/I/0=100/0/4. Temp=S1. Monitor WHPs (post Furmanite). Heater installed & working. TP increased 65 psi, IAP unchanged & OAP increased from 0+ to 4 psi since 03/14/09. SV, WV=Closed. SSV, MV=Open. IA & OA=OTG. NOVP. ---- ~, ._ Y.__~. ______ _ ~ ~__,_ . ____..._e .. __ 3/16/2009,T/I/O 100/0/4. Temp=S1. WHPs (post Furmanite). WHPs unchanged !overnight. ~SV, WV=Closed. SSV, MV=Open. IA&OA=OTG. NOVP. 3/17/2009T/I/O= 100/VAC/10 Temp= SI. WHPs (post-Furmanite). TBGP unchanged, IAP on vac, OAP increased 6 psi. 3SV, WV= C. SSV, MV= O. IA, OA= OTG. 3/22/2009 **"**WELL S/I ON ARRIVAL''**** (post furmanite) SET 4 1/2" WHIDDON CATCHER @ 9301' SLM PULLED RA-OGLV FROM STA 1 @ 9219' SLM & RA-LGLV STA 3 @ 7008' SLM, STA 4 @ 5355' SLM, STA 5 @ 3165' SLM SET RM-DGLV IN STA 5 @ 3165' SLM, STA 4 @ 5355' SLM, STA 3 @ 7008' SLM, STA 1 @ 9219' SLM PULLED 4 1/2" WHIDDON CATCHER FROM 9301' SLM f MIT-IA W/ DIESEL TO 3000 LBS PASSED (SEE DATA LOG) ***""CONT ON WSR 3/23/09**""" • 3/22/2009T/I/O=375/400/0. SI. IA FL for S/L. IA FL @ surface. ~S/L in control of well. 3/23/2009. *""`**CONT FROM WSR 3/22/09"*""* (post furmanite) MIT-OA W/DIESEL TO 1200 LBS (NOT ENOUGH FLUID TO FINISH -FULL aBORE WILL COMPLETE) PULLED 4 1/2"WRP FROM 9306' SLM *"""WELL LEFT SI, PAD OP NOTIFIED**"* *"WEATHERFORDWRP MONTHLY RENTAL FOR MONTH 2 (2/16/09 - 3/17/09) & MONTH 3 (3/18/09 - 3/22/09)"" 3/24/2009~T/I/O =130/440/30. Temp = SI. OA FL, pre MITOA (FB). OA FL near 1 surface. ;SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. 3/30/2009 T/I/0=200/500/10 Temp=S1 No leaks on Furminite Wrap, MIT OA FAILED 1200 psi, LLR-OA of 0.25 bpm @ 1100 psi (Verify Furminite Wrap post Startinghead repair) Pumped 7.8 bbls of 25*F crude down OA to reach 1200 psi for MIT OA. 1 st test 1st 15 min lost 1060 psi Attempt LLR-OA. Pumped 18.7 bbls of 90"F crude down down OA @ 0.25 bpm @ 1100 psi. Never saw wet spot on Furminite for 1 HR, OA pressure went from 800 psi to 210 psi in 15 mins after sd pump. Final Whp's=200/500/0. Wing shut, Swab shut, SSV open, casing valves open to gauges. 4/1/2009 T/I/0=130/410/150. Temp SI. Monitor Furmanite wrap post-POP (eval SH repair). *''Note: No SH leaks visible at this time. SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. • 5/9/2009T/I/O=1750/1610/170. Temp=98*. Monitor furmanite wrap post POP (eval SH jrepair). No leaks on the upper or lower SH. Furmanite wrap appears cured as it is dry to the touch and has an even color to it. !SV=Closed. WV, SSV, MV=Open. IA&OA=OTG. NOVP. 5/10/2009 T/I/O- 1750/1610/170. Temp= 98*. Monitor Furmanite wrap post POP (eval SH repair). WHPs unchanged overnight. Furmanite wrap appears to have no ..leaks, w/ even color to it. SV= C. WV, SSV, MV= O. IA, OA= OTG. NOVP. 5/11 /2009 T/I/0= 1750/1610/170. Temp=98. Monitor furmanite wrap post POP, (eval SH repair). WHPs unchanged overnight. fermanite wrap appears to have no leaks, w/ even color to it. *''*NOTE*** IA companion valve has non-threaded "bullit shaped" bullnose, IAP will need to be bled to 0 psi to change-out. SV=O. WV,SSV,MV=O. IA, OA=OTG. NOVP TREE = Mc EV OY 6 WELLHEAD= McEVOY ACTUATOR = KB ELEV = OTIS 76.9 BF. ELEV = 40.14' KOP = 2900' Max Angle = 50 @ 10312' Datum MD = 10097' Datum TVD = 8800' SS 13-3/8" 72#, L-80, ID = 12.348" I-{ 2613' 9-518" CSC, 47#, L-80, ID = 8.681" (-~ 4792' ~ TOP OF 9-518" CS~ 4792' Minimum ID = 2.372" @ 9474' TOP 2-718" LINER TOP OF 7" LNR 9462' 9458' -14-1/2" OTIS X NIP, ID = 3.813" " ' 9474' --rDEPLOYMENT SLEEV E TOP OF 2-718 LNR 9474 ID = 3 725" g4g0' 4-112" OTIS XN NIP 4-112" TBG 12 6# L-80 BUTT 0152 bpf ID = 3 958" 9522' , . g522' 4 1/2" TUBING TAIL WITH SO SUB . , , . , . , 9-518" CSC, 47#, L-80 BTRS, ID = 8.681 ^ 9711' - 9521' ELMD TT LOGGED 10/29/93 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10186' 7" WINDOW (J-22Aj 10189' - 10195' TOP OF WHIPSTOCK 10186' RA TAG 10196' 10196' RA TAG PERFORAT~N SUMMARY REF LOG: SWS RST ON 08/30/00 ANGLE AT TOP PERF: 43 @ 10200' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10200 - 10210 O 10/02/00 2" 6 10226 - 10246 O 11127/00 2" 4 10254 - 10264 O 09/20100 2" 4 10280 - 10300 O 09/03!00 DATE REV BY COMMENTS DATE REV BY COMMENTS 1981 OWGINAL COMPLETION 06/01/09 MBM(TLH GLV Cl0 (03/24109) 08!26!00 ASKEL CTD SIDETRACK 10127/09 TTWlSV SAFETY NOTE 11/14/06 KSBIPJC SET' PX PLUG (11/01!06) 05/25/07 TA/TLH GLV C/O & PX PLUG PULLED 10/16108 GJF/PJC SET' WRP (10!05!08) 06!02/09 CS/TLH WRP PULLED (03123(09) PRUDHOE BAY UNIT WELL: J-22A PERMIT No: 2001240 AFB No: 50-029-21698-01 SEC 9, T11 N, R13E, 682' FNL & 803' FEL BP Explaratian (Alaska] SAFETY ES: **GOMPOSITE WRAP REPAIR SH J ~ ~~ LEAK-DO NOT PUMP METH OR METH BLEND INTO OA DUE TO CHEM INCOMPATIBILITY WIEPOXY RESIN IN WRAP** 2131' CA MCO SSSV LAND NIP, ID = 3.813" GAS LIFT MANDRELS • ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3187 3178 15 LBD DMY RM 0 03/24!09 4 5375 5074 31 LBD DMY RM 0 03/24/09 3 7014 6452 35 LBD DMY RM 0 03/24/09 2 8260 7474 36 LBD DMY RM 0 05/22/07 1 9232 8227 42 LBD DMY RM 0 03/24/09 I I .,,,_.,,.. 9340' OTIS XA SLIDING SLEEVE, ID = 3.813" 9394' TOP OF PBR 9419' 9-5/8" TMJ HBBP PKR, ID = 4.750" PBTD I~ 10324' I 2 718" LNR, 6.18#, L-80, .0058 bpf, ID = 2.372" I 10/01/09 Sehlemherger NO. 5405 Alaska Data Consulting Services Company: State of Alaska 2525 Gambol) Street, Suite 400 Alaska Oil Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job A Log Description Date BL Color CO K -11 AY1M -00033 SBHP SURVEY 0 Jj 09/12/09 1 1 L4 -30 AWL8-00031 PRODUCTION PROFILE Q( /1-3.0.1 08/06/09 1 1 P2 -31 AP3Q -00045 LDL let- (J4:, -94.1 07/11/09 1 1 01-29 6-00009 _PRODUCTION PROFILE /�fJ' 08/11/09 1 1 J -22A 69K 9K -00013 PRODUCTION PROFILE 08/30/09 1-2 B 1 1 W-44 B14B -00071 INJECTION PROFILE I. )T� 1 'e} 09/06/09 1 1 12 -25 13581 -00010 INJECTION PROFILE 1,e.,, a(/ 08/22/09 1 1 L5 -33 AYKP -00051 SBHP SURVEY 9 1,e.,, U it 4 4 J 09/01/09 1 1 P2 -48 B69K -00015 SBHP SURVEY j 09/01/09 1 1 1-28 869K -00016 INJECTION PROFIL ;i., /gr' 3I 09/19/09 1 1 0 -02A AP3Q -00054 IBPILDL (x 07/24/09 1 1 N -10A AXBD -00040 MEM PROD PR a FILE .-(1� p C. 08/25/09 1 1 W -24 AWJI -00044 MEM INJECTION PROFILE /{1f(— [y -O li4fp8/15/0g I 1 V -03 B2NJ -00021 MEM PROD PROFILE ,'a lS f 09/03/09 1 1 H -148 B2WY -00026 MEM PROD PROFILE a ,t 08/27/09 1 1 P1-01 AY1M -00031 INJECTION PROFILE A Q j.' 08/20/09 1 1 P1.05 8581.00009 PRODUCTION PROFIL ti (S (t 08/20/09 1 1 NK -10 02WY -00023 MEM INJECTION PROFILE L Ll /g, 08/22/09 1 1 13.27A 82ND -00019 MEMORY SCMT _Mc_ --I d -4 08/13109 t 1 1 18 -02B B2WY -00021 MEMORY SCMT I1 1 08/19/09 1 1 NK -38A AYKP -00049 USIT i�o �ry I 08/17/09 1 1 06 -09 SWL8-00028 USIT .-t 3 1S 07/30/09 1 1 13.03A 09AKA0150 OH MD/LW, EDIT ay 07/06/09 2 1 C -18B B2NJ -00017 MCNL MRS 08/09/09 1 1 1 1-35/0-25 B69K -00011 RST 08/26/09 1 1 04 -35A AX80.00025 MCNL 4 6 ,1 05113109 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrolechnical Data Center LR2 -1 2525 Gambell Street, Sale 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 t IIII 4 r N O V Y 1 S s, y oat..* 1' a_' t �4u 1 i. IfV~~~ ~~ TR~4~lI/~f1~~4L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 [907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Joe Lastufka 6 LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and >~[ nn P -. .1 ProActive Diagnostic- Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245.6952 '~Ob-/~~I ~ ~ 335 Leak Detection - WLD 25-Dec-08 J-22A 1 Color Log / EDE 50-029-21 2j Correlation Log 21-Dec-08 P2-07 EDE Signed : Date Print Name: C~ 50-029-22469-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SWITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-#M0.IL : pdsanchorage(u~mem®n~Boa.~®rn WEBSITE : ~,nrr~vv.rsael~IOS~/lo --~ C:\DociunenL~ artd Seitings\Owner\Desktop\Transmit_BP.doc~c Schlumberger scANNE.D JAN 3 0 2007 01/26/2007 NO. 4129 '~~ f~ ¡;úo- I dL( Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Field: Prudhoe Bay Well Job# Log Description Date BL Color CD B-26B 11285930 MCNL 06/26/06 1 1 B-10 11225985 RST 07/03/06 1 1 J-21 11217277 RST 08/28/06 1 1 J-06 11321006 RST 08/30/06 1 ~ J-22A 11217478 RST 08/30/06 1 (1 "\ J-12 11243953 RST 08/29/06 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: wrolC) d 'ö/l.. - ;;::)-6(, -Š<2-~~-\- 0) 't ~ Ie taD.-OL-. Received by: - \,j . . F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Permit to Drill 2001240 MD 10387 ~'~ TVD DATA SUBMITTAL COMPLIANCE REPORT 9/9/2002 Well Name/No. PRUDHOE BAY UNIT J-22A Operator BP EXPLORATION (ALASKA) INC 9083 _~ Completion Dat 9/3/2000 Completion Statu l-OIL Current Status l-OIL APl No. 50-029-21698-01-00 UIC N REQUIRED INFORMATION Mud Log N_go Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No T C C L L R R-~~ R R 9847 RST/Porosity SRVY RPT 10127~'" LIS Verification (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop OH / Dataset CH Received Number Comments ~,T'- 9100 10312 Case 10157 10341 Open FINAL 9100 10312 CH FINAL 9100 10312 CH 10100 10387 OH FINAL 10157 10341 CH FINAL 1/3/2001 5/1/2001 1/3/2001 1/3/2001 10/9/2000 5/1/2001 5/1/2001 09847 9100-10312 10127----'"10157-10341 9847 9100-10312 Digital Data 9100-10312 BL, Sepia SPERRY 10100-10387 10127 10157-10341 Digital Data ! O/,~ ~ LIS Verification Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis Start Interval Stop Dataset Sent Received Number Daily History Received? ~r' N Formation Tops ~ N Comments Comments: Compliance Reviewed By: Date: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. . Atm.: Lisa Weepie 333 West 7th Avenue,-Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs" J-22A, ~ AK-MW-00157 April 26, 2001 J-22A: - 2"x 5" MD Gamma Ray Logs' - 50-029-21698-01 ... 2" x 5" TVD Gamma Ray Logs' 50-029-21698-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: SPerry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic BlVd. ' - Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:-, RECEIVED. FlAY 0 1 2001 Al~mkl Oil& (bib ~)ns. Ooflmli~dofl WELL LOG TRANSMITY~ To: State of Alaska April 12, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333. West 7~ Avenue, Suite 100 Anchorage, Alaska MWD Formation Evaluation Logs J-22A,~ AK-MW-00157 ¢ 1 LDWG formatted Disc with verification listing. API#: 50-029-21698-01 PLEASE ACKNOWLEDGE RECEIIrr BY SIGNING AND RETURNING A COPY OF THE TRANSMYrTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:- RECEIVED HAY 0 1 20.01 Alaska 0~1 & Gas Cons.,~ Scbh berger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 781 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date Blueline Sepia Color CD Prints J-22A 20369 CH EDIT RST-SIGMA (PDC) 000830 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 12/7/00 BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-661 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-57t 1 ATTN: Sherrie STATE OF ALASKA ALASKA~ _ AND GAS CONSERVATION COMIV~' ,ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-124 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 50- 029-21698-01 4. Location of well at surface . . a,,,.~~ 9. Unit or Lease Name 682' SNL, 803' WEL, SEC. 09, T11N, R13E, UM ~..: O~ At top of productive interval ~ ~. Prudhoe Bay Unit 3100' NSL, 2156' WEL, SEC. 04, T11N, R13E, UM ....... .: At total depth ~ ..... ~ ~. ..... 10. Well Number J-22A 3164' NSL, 2213' WEL, SEC. 04, T11N, R13E, UM 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 76.94' ADL 028281 12. Date Spudded8/25/2000 113' Date T'D' Reached [14' Date C°mp'' susp'' °r Aband'8/25/2000 9~3~2000 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17, Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 10387 9083 FTI 10325 9040 FTI [] Yes [] NoI (Nipple) 2131' MDI 1900' (Approx,) 22, Type Electric or Other Logs Run MWD, IND, GR, ROP 1'3 I r', I I ^ I 23. CASING, LINER AND CEMENTING RECORD [..) ~ I t.-) I I "J h't I CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" Surface 110' 8 cu }/ds concrete 13-3/8" 72# L-80 / S0095 37' 2613' 17-1/2" 3152 cuft PF 'E', 465 cu ft Permafrost 9-5/8" 47# L-80 37' 9712' 12-1/4" 575 cu ft Class 'G' 7,, 26# L-80 9462' 10189' 8-1/2" 378 cu ft Class 'G' 2-7/8" 6.16# L-80 9474' 10387' 3-3/4" 56 cu ft Class 'G' 24. Perforations op. en to. Producti.on (MD+TVD of Top and 25. TUBING RECORD Bottom and imervah size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9522' 9419' MD TVD MD TVD 10280' - 10300' 9010' - 9023' 10200' - 10210' 8954' - 8961' 261 Ac©, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 25 Bbls of MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 9, 2000 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Flow Tubing 3asing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. 25N 10269' 9002' 24N 10346' 9054' 31. List of Attachments: Summary Of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,,~-~ ~ Title TechnicalAssistant Date I~)" J-22A 200-124 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. , 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-I~,~O~e['=ezplain. ITEM 28: If no cores taken, indicate 'none'. ~"~ [~ ~ ~] i tj .~. Form 10-407 Rev. 07-01-80 BP EXPLORATION page1 of 2 Operations Summary Report Legal Well Name: J-22 Common Well Name: J-22 Spud Date: 2/23/1987 Event Name: REENTER+COMPLETE Start: 8/23/2000 End: Contractor Name: NORDIC CALISTA Rig Release: Group: RIG i Rig Name: NORDIC 1 Rig Number: Date From~ To:Hours Activi~: C:~e Phase :i : DescriPtion of OperatiOns : :: 8/23/2000 16:00 - 18:00 2.00 DRILL PROD1 ACCEPT RIG AT 16:00 HRS, 08/23/00. N/U DOPE. 18:00 - 20:00 2.00 DRILL PROD1 General rig up, spot equipment, M/U hardline, berm tank. 20:00 - 23:30 3.50 DRILL PROD1 Pick up injector head, M/U guide arch, stab CT, M/U CTC. 23:30 - 00:00 0.50 DRILL PROD1 Safety Meeting, regarding recent BP accidents. 8/24/2000 00:00 - 10:30 10.50 BOPSUF; PROD1 Perform initial DOPE pressure / function test to 300/3500 psi. Test floor valve and reel isolation valve 3000/3500 psi. Annular 300/2500 psi. Test gas alarms and emergency shut down systems. Install pressure cap and open well - OK. 10:30 - 11:30 1.00 STWHIP PROD1 MU window milling BHA #1 - HCC diamond window mill and string mill. MU coil conn and stab injector. 11:30 - 13:15 1.75 STWHIP PROD1 RIH with BHA #1. Tag XN nipple at 9489' ELMD and correct depth (+7'). Hold pre-drilling operations and safety meeting with rig and service company personnel. 13:15 - 13:30 0.25 STWHIP PROD1 Mill thru XN nipple 13:30 - 14:15 0.75 STWHIP PROD1 RIH and tag up on whipstock w/pump. Correct depth at pinch point to 10189' and flag pipe. 14:15 - 18:45 4.50 STWHIP PROD1 Start milling.2.7 bpm @ 1850 psi. Have milled 3.0' at 15:45 hrs and 5.5' a t 17:15 hrs. Mill exited casing at this point- depth 10194.5'. \, 18:45 - 20:00 1.25 S'I'WHIP PROD1 Mill formation to 10204 ft. Swap to FIoPro. Ream window area. 20:00 - 20:30 0.50 STWHIP PROD1 Ream window area total of 6 times, dry tag, clean window. 20:30 - 23:00 2.50 STWHIP PROD1 POOH with milling BHA #1. '23:00 - 23:10 0.17 S'I'WHIP PROD1 Kick while trip drill. 23:10 - 23:30 0.33 STWHIP PROD1 Lay out milling BHA. Mill at 3.80", good condition. 23:30 - 23:45 0.25 S-I'WHIP PROD1 PJ Safety Meeting, review BHA make up hazards. 23:45 - 00:00 0.25 STWHIP PROD1 M/U MWD BHA #2 with Sperry MWD Resistivity tool. 8/25/2000 00:00 - 01:15 1.25 DRILL PROD1 Test Sperry Resistivity tool at surface. 01:15 - 03:15 2.00 DRILL PROD1 RIH with drilling BHA. Bit #1, DS49HGJ [used], 1.7 deg. motor 03:15 - 03:30 0.25 DRILL PROD1 Orient TF to 50L. RIH to TD. Correct to TD of 10,204' [+5 ft]. 03:30 - 04:30 1.00 DRILL PROD1 Drilling build / turn section, TF=55L, REP=60 FPH. TD=10226 ft. 04:30 - 04:50 0.33 DRILL PROD1 Orient TF to 80L. 04:50 - 06:00 1.17 DRILL PROD1 :Drilling, TF=90L, REP=70 FPH, TD=10,265, Inc1=47 deg. 06:00 - 09:15 3.25 DRILL PROD1 i Drill ahead trying to hold TF at +/- 90L. TD well per geologist at 10387 ft BKB. 09:15 - 10:15 1.00: DRILL PROD1 POH to window at 250 fph making MAD pass. 10:15 - 10:30 0.25 DRILL PROD1 RIH to bottom - hole in good shape. TD = 10, 387 ft BKB. 10:30 - 12:00 1.50 DRILL PROD1 POH to run 2 7/8" liner. 12:00 - 13:00 '1.00 DRILL PROD1 Stand back injector. LD BHA. 13:00 - 14:00 1.00 DRILL PROD1 Download Sperry memory data. RU to run 2 7/8" liner. Read Logging tool data and make depth correction: (+2'). TD is now 10387'. 14:00 - 14:30 0.50 CASE PROD1 PJSM and hazard identification for running liner. 14:30 - 16:30 2.00 CASE PROD1 Run 30 jts 2 7/8" STL liner. Fill liner at 15 jts in. Run 10 ft pup for space out. 16:30 - 17:15 0.75 CASE PROD1 MU liner deployment tools and install Baker coil conn. Pull and pressure test same. RIH with liner. 17:15 - 20:00 2.75 CASE PROD1 Land liner at TD of 10378 ft. Recip. liner. Pump 5/8" steel ball and disconnect from liner. 20:00 - 22:30 2.50 CASE PROD1 Displace well to 2% KCL water, clean pits. Rig up cementers. Batch up cement. 22:30 - 22:45 0.25 CASE PROD1 Safety Meeting with all personnel. 22:45 - 23:15 0.50 CASE PROD1 Pressure test cement line. Stage 10 BBL, 15.8 PPG, G CMTwith Latex. 15.9 PPG on densitometer. Printed: 8/30/2000 2:15'50 PM BP EXPLORATION Page 2 of 2 Operations Summa Report Legal Well Name: J-22 Common Well Name: J-22 Spud Date: 2/23/1987 Event Name: REENTER+COMPLETE Start: 8/23/2000 End: Contractor Name: NORDIC CALIST^ Rig Release: Group: RIG Rig Name: NORDIC 1 Rig Number: Date From- To Hours ~ACtivi~ : : COde PhaSe DesCripti°n °f operationS 8/25/2000 23:15 - 00:00 0.75 CASE PROD1 Insert CT dart, Displace dart to liner wiper plu with rig pumps at 3.1 BPM/2200 psi. Full returns. On seat at 58.8 BBl. sheared at 3800 psi. Displace at 3 BPM. Bumped plug at 63.6 bbls. Held 1500 psi. Bleed WHP to zero and check floats. Float valves holding. Sting out of liner top. Jet top of liner. PBTD = 10,324 ft. 8/26/2000 00:00 - 02:15 2.25 CEMT PROD1 POOH with liner running tools. Lay out Baker tools. 02:15 - 02:30 0.25 CEMT PROD1 Safety Meeting. 102:30 - 03:30 1.00 CEMT PROD1 RIH with nozzle on 32 jts of CSH workstring in singles. 03:30 - 05:00 1.50 CEMT PROD1 RIH with CT to jet out liner. 05:00 - 05:30 0.50 CEMT PROD1 CMT sample at 200 psi. RIH to PBTD of 10324 ft. clean out liner. 2.4 BPM. 2400 psi. no cement seen. clean to PBTD. 05:30 - 07:45 2.25 CEMT PROD1 POOH while circ. at 2.4 BPM. 2400 psi. 07:45 - 08:00 0.25 CEMT PROD1 PJSM and hazard analysis for LD 1 1/4" CSH workstring. 08:00 - 09:00 1.00 CEMT PROD1 LD CSH workstring and 1 stand 2 3/8" PH6 from derrick. 09:00 - 10:00 1.00 CEMT PROD1 RIH with nozzle on CT to 2000 feet 10:00 - 11:00 1.00 CEMT PROD1 Pressure test liner and lap cement to 2200 psi for 30 min. IA has 550 ~psi to reduce differential across TIW prod packer. Lost 50 psi in 30 rain - acceptable test. 11:00 - 12:00 1.00 RIGD PROD1 Displace MeOH to nozzle and POH with CT laying in at 2:1 up to 200' then 1:1 to surface. Close swab valve. 12:00 - 15:00 3.00 RIGD PROD1 Clean pits. ND BOPE. Install and test tree cap. Rig down cuttings tank. RELEASE RIG FROM WELL J-22A AT 15:00 HRS ON 8/26/2000. TOTAL TIME ON WELL WAS 2 DAYS 23 HOURS. Printed: 8/30/2000 2:15:50 PM Well: J-22A Accept: 08/23~00 Field: Prudhoe Bay Spud: 08/25~00 APl: 50-029-21698-01 Release: 08/26/00 Permit: 200-124 CTD Unit: Nordic #1 Date PRE-RIG WORK 08/18/00 HB&R prior to Eline Rig up kocked-down WHP with 300 bbls of 2% KCL and 35 bbls of Methanol, final pumping WHP = 0 psi. Miru SWS #2150. RIH w/7" Baker Whipstock. Tie-in to CBL (29-Mar-87), set whipstock at 10,186' MD, 8 degrees right of high side looking down hole (RA Tag 10.1' from top of Whipstock). Pulled up then tagged whipstock to verify, tagged at setting depth. POOH. RDMO. 08/20/00 MIRU DS CTU #5 and BP Squeeze Unit. PU BHA #1 (combo squeeze nozzle). Bullhead kill well with 300 bbls of filtered 2% KCL water. RIH, tag whipstock and flag pipe. RU HB&R to hold pressure on IA. Mix and pump 30 bbls of latex cement with additives as described below. Pump 10 bbls below whipstock and lay in remainder. Squeeze to 3000 psi in 500 psi increments. Placed 6.5 bbls behind pipe. Hold squeeze for 45 minutes. Drop ball and contaminate with 33 bbls biozan to 10190' ctmd (whipstock tray). Chase out at 80% with slick water. POST COIL TUBING SIDETRACK - Perf Operation 09/03/00 Shot 2" HSD 4 SPF Powerjets over 10280'- 10300'. Shot while well shut in, as per program. 10/02/00 Perforated from 10200' - 10210' using a 2" HSD at 6 SPF and 60 Deg Phasing with PJ 2006 HMX charges. PBTD not tagged. North Slope Alaska Alaska State Plane 4 PBU_WOA J Pad J.22A Surveyed: 25 August, 2000 ORIGINAL SURVEY REPORT 09105/2000 16:37:20 PM Your Ref: API.500292169801 Surface Coordinates: 5970671.00 N, 643547.00 E (70° 19' 38.4603" N, Kelly Bushing: 76.94ft above Mean Sea Level 148° 50' 08.9514" RECEIVED 0 CT ~, ~ 2000 Nasl~I Oil & Gas Cons. Commiss~, Ancho~ Survey Ref: svylO002 Sperry-Sun Drilling Services Survey Report for J-22A Your Ref: API-500292169801 Surveyed: 25 August, 2000 North Slope Alaska Measured Sub-Sea Ve~ical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Easfings (~) (fi) (~) (~) (~) (~) (fi) 10100;00 41.030 351.050 8801.95 8878.89 3672.17 N 1333.04W 5974316.99 N 642143.94 10186.00 41.110 350.006 8866.79 8943.73 3727.90 N 1342.34W 5974372.53 N 642133.58 10216.31 45.200 342.816 8888.91 8965.85 3748.00 N 1347.25W 5974392.54 N 642128.29 10244.70 46.430 336.186 8908.70 8985.64 3767.05 N 1354.39W 5974411.45 N 642120.79 10275.51 46.870 329.206 8929.87 9006.81 3786.93 N 1364.66W 5974431.13 N 642110.14 10311.71 49.520 321.436 8954.02 9030.96 3809.07 N 1380.02W 5974452.97 N 642094.36 10340.31 46.430 315.656 8973.17 9050.11 3824.99 N 1394.05W 5974468.62 N 642080.03 10363.11 45.290 308.786 8989.06 9066.00 3835.98 N 1406.14W 5974479.38 N 642067.72 10387.00 45.290 308.786 9005.86 9082.80 3846.62 N 1419.38W 5974489.76 N 642054.29 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Dogleg Rate (°/'tOOft) E 0.803 E 21.087 E 17.292 E 16.531 E 17.586 E 18.489 E 22.187 E 0.000 Alaska State Plane 4 PBU_WOA J Pad Vertical Section Comment (ft) 3842.56 Tie-on Survey 3899.06 Window Point MWD Magnetic 3919.71 3939.67 3960.98 3985.36 4003.39 4016.24 4028.93 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 350.440° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10387.00ft., The Bottom Hole Displacement is 4100.13ff., in the Direction of 339.746° (True). RECEIVED OCT G~) ~000 Alaska 011 & ~;; Co~ ~mm~ssm~ ~.nchora~ Continued... 0910512000 16:37:21 PM - 2 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for J.22A Your Ref: API.500292'16980'1 Surveyed: 25 August, 2000 North Slope Alaska Comments Measured Station Coordinates Depth TVD - Northings Eastings (~) (~) (~) (~) 10100.00 8878.89 3672.17 N 1333.04 W 10186.00 8943.73 3727.90 N 1342.34 W 10387.00 9082.80 3846.62 N 1419.38 W Comment Tie-on Survey Window Point Projected Survey Alaska State Plane 4 PBU_WOA J Pad Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0,00 0.00 10186.00 8943,73 To Measured Vertical Depth Depth (~t) (ft) 10186.00 8943.73 10387.00 9082.80 Survey Tool Description ^K-1 BP_HG MWD Magnetic RECEIVED OCT O ~ 2000 Alaska 0il & Ga; ~n~. Oommmmm, DrillQuest 1,05.05 0910512000 16:37:22 PM - 3 - ALASKA OIL AND GAS CONSERVATION CO~IpllSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit J-22A BP Exploration (Alaska) Inc. Permit No: 200-124 Sur Loc: 682'SNL, 803'WEL, Sec. 09, T1 IN, R13E, UM Btmhole Loc. 3167'NSL, 2182'WEL, Sec. 04, T1 IN, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this / ~ d--~ day of August, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASI~{r IL AND GAS CONSERVATION COM~ ,SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Ddll [] Reddll 1 lb. Type of well [] Exploratory [] Stratigraphic Test B Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 76.94' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028281 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.O25) 682' SNL, 803' WEL, SEC. 09, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 2836' NSL, 2108' WEL, SEC. 04, T11N, R13E, UM J-22A Number 2S100302630-277 At total depth 9. Approximate spud date 3167' NSL, 2182' WEL, SEC. 04, T11N, R13E, UM 08/23/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028278, 2112' MDI No Close Approach 2560 10376' MD / 9002' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10200' Maximum Hole Angle 45 ° Maximum surface 2244 psig, At total depth (TVD) 8800' / 3300 psig i8. Casing Program "- Specifications Setting Depth Size Tt ~1~ BOttom Quantitv of Cement Hole Casinq Wek;Iht Grade Coupling Len(;Ith MD TVD MD TVD (include staoe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 901 9475' 8329' 10376' 9002' 51 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10568 feet Plugs(measured) ORIGINAL true vertical 9228 feet Effective depth: measured 10509 feet Junk (measured) Fill at 10509' (07/89) true vertical 9185 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 30" 8 cu yds concrete 110' 110' Surface 2576' 13-3/8" 3617 cu ft Permafrost 'E' 2613' 2613' Intermediate 9675' 9-5/8" 575 cu ft Class 'G' 9712' 8584' Production Liner 1106' 7" 378 cuft Class 'G' ~.--~ ~ .~ ...... 946~.':.~;~1~Q~68' 8396' - 9228' Perforation depth: measured 10266' - 10318', 10335'- 10345' [-~?,.; L~ '~, ~ ~',~:-:~'';:'''~,~ ~ true vertical 9004' - 9043', 9056' - 9063' . .~,.~ 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble. 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge . Signed TedStagg ~~'! Title CT Drilling Engineer Date Permit Number (_~ APl Number ApAroval D_ate,,,^ See cover letter ~ "'/Z! 50- 029-21698-01 ~ "'('7'"eMU for other requirements COnditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Yes ~'No Hydrogen Sulfide Measures ~ Yes I-I No Directional Survey Required ~;a Yes r'3 No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~,3500 psi for CTU Other: ORIGINAL SIGI~E; by order of ~;).~/? _Approved By D T~vlnr .~,~ ,:-~ Commissioner the commission Date "~) Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX J-22a Sidetrack Summary of Operations: J-22 is currently shut in due to high GOR and a split in the 7" liner at 10,258'. The J-22a sidetrack will be a replacement wellbore to access remaining lower Zone 2 reserves. This sidetrack will be conducted in two phases. ~,.,.~e~Phase 1: Set Whipstock, Downsqueeze cement, Mill window. Planned for August 18, 2000. · E-Line will set the whipstock at approx. 10,190'. · Service coil will downsqueeze approx. 20 bbls cement to shut off existing perfs. · Service coil will mill the window. Phase 2: Drill and Complete sidetrack: Planned for August 23, 2000. Drilling coil will be used to drill and complete the directional hole as per attached plan. The sidetrack will be completed with a cemented liner. Top of 2 7/8" to be approx. 9,475" MD (8329'ss) with top of liner cement approx. 9,990'MD. This will leave top of liner cement approx. 200 ft above the window. Approx. 9 bbls cement will be used for this liner cement job. Mud Program: · Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L cemented liner will be run from TD to approx. 9,475' MD. Top of liner cement will be at approx. 9,990' MD. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over all of the open hole section. · A real time Resistivity Log will be run in open hole. Hazards The split in the liner presents some risk to successfully setting a whipstock approx. 60 ft above the split. No lost circulation is expected. Max. recorded H2S on J Pad is 90 ppm. Reservoir Pressure Res. press, is estimated to be 3300 psi at 8800ss. Max. surface pressure with gas (0.12 psi/fi) to surface is 2244 psi. TREE: McEVOY 6" WELLHEAD: McEVO¥~:~ ACTUATOR: OTIS KOP: 2600' MAX ANGLE: 42° 4-1/2", 12.6#/ft, L-80, BUTT TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT 9-5/8", 47#/ft, L-80, NSCC I 4792' I o.o. I I 7" LINER 9462' Whipstock to be set approx. 10190' in Zone 2C. Existing perfs to be downsqueezed past whipstock. PERFORATION SUMMARY REF: LOG: BHCS 3-6-87 SIZE SPF INTERVAL OPEN/SQZ'D 3-3/8 4 10266 - 10318 OPEN 3-3/8 4 10335 - 10345 OPEN PBTD I 10523'1 7", 26#/ft, L-80, IJ4S 10568'I Comple on KB. ELEV = 78.74' BF. ELEV =. 40.14' SSSV LANDING NIPPLE (CAMCO)(3.813" ID) I 2131' GAS LIFT MANDRELS OTIS LBD w/RA LATCH N°- MD(BKB) TVDss - #5 3187 3100 #4 5375 4997 #3 7014 6375 #2 8260 7396 #1 9232 8149 SLIDING SLEEVE OTIS XA I 9340'1 (3.813" MIN. ID) TOPOFPBR I 9394' I 9-5/8" PACKER II (TIW HBBP)(4.750"ID) 9419' 4-1/2", 12.6#/ft, L-80 TAILPIPE 4-1/2 .... X" NIPPLE I I (OTIS) (3.813" ID) 4-1/2 .... XN" NIPPLE ~ I (OTIS)(3.725" ID) 4-1/2" SHEAROUT SUBI (ELMD) 9458' 9490' 9522' 2 7/8" liner cement top to be approx. 200 ft above window, in mid-Zone 4, leaving room for future sidetrack. J-22 4,500 I -2,000 4,000 3,500 -1,500 -1,000 -500 X distance from Sfc Loc JWell Name J-22 J CLOSURE JDistance 4,093 ft Az 339 deg NEW HOLE E/W (X) N/S Of) Kick Off -! ,415 3,711 TD -1,460 3,824 Store Plone 642,086 5,974,494 Surface Loc 643,546 5,970,670 DLS de~l/100 Tool Face Length curVe 1 " 6 0 ~0 CurVe 2 14 -45 30 CurVe 3 14 -90 130 180 Drawn: 8/9/2000 16:41 Plan Name: Case 101 J-22 Verlical Section 0 8500 8550 8600 8650 8700 8750 8800 8850 8900 8950 9000 9050 9100 Path Distance (Feet) 500 1,000 1,500 I I Angle @ K.O.= 41 deg MD:10200 Tot Drld:176 ft 10376 TD Marker Depths ~::)ri~l Wellbore · rzs I e,ze~l, TVD I 8,859lft TVD .o? I 8,9991ft TVD TSAD I 8,623Jft TVD JKickOff I 8,877JftTVD 10,200lft MD IDeprtr @KO 3,986 fi' I MD KO Pt lO,200J MD New Hole 176J I Total MD 10,376J TVD TD 9,002J Curve 1 DL$ de~l!100 6 Tool Face Length 20 Curve 2 14 -45 30 Curve 3 14 -90 130 180 Drawn: 8/9/2000 16:41 Plan Name: Case 101 2 3/8" CT Pack-Off Lubricat°r~ I J-22a CT Drilling & Completion BOP UJ 12" 36" 22.5" 7 1/16" Annular I I Blind/Shear 7 1/16" Pipe/Slip -" --- 2 3/8" _ I I ~,, ,_ _ ~...x~...oo. o.,,~_ _ Ill 7 '1/~ 6"× $,ooo p~i I I 7/8" 3/8" SWAB OR MASTER VALVE 1. Type of Request: i~ STATE OF ALASKA ( ALAS OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate I-I Alter Casing [] Repair Well [] Pull Tubing [] Variance i-I Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate [] Other Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 682' SNL, 803' WEL, SEC. 09, T11N, R13E, UM At top of productive interval 2836' NSL, 2108' WEL, SEC. 04, T11N, R13E, UM At effective depth 3254' NSL, 2179' WEL, SEC. 04, T11N, R13E, UM At total depth 3293' NSL, 2187' WEL, SEC. 04, T11 N, R13E, UM 5. Type of well: I~! Development r"l Exploratory r"l Stratigraphic r-I Service A~ch0rage 6. Datum Elevation (DF or KB) KBE = 76.94' ' 7. Unit or Property Nam'~ Prudhoe Bay Unit 8. Well Number J-22 9. Permit Number 187-017 10. APl Number 50-029-21698-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured Effective depth: casing true vertical measured true vertical Structural Conductor Surface Intermediate Production Liner 10568feet 9228feet 10509 feet 9185feet Length 110' 2576' 9675' Plugs (measured) Junk (measured) Fill at 10509' (07/89) Cemented 8 cu yds concrete 3617 cu ft Permafrost 'E' 575 cuft Class 'G' Size 30" 13-3/8" 9-5/8" MD TVD 110' 110' 2613' 2613' 9712' 8584' 1106' 7" 378 cuft Class 'G' 9462' - 10568' 8396' - 9228' Perforation depth: measured true vertical 10266' - 10318', 10335' - 10345' 9004'-9043', 9056'-9063' ORIGINAL Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 9522' Packers and SSSV (type and measured depth). 9-5/8" TIW ,HBBP' packer at 9419'; 4-1/2" Camco SSSV Landing Nipple at 2131' 13. Attachments I~I Description Summary of Proposal 14. Estimated date for commencing operation August 18, 2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Numben Ted Stagg, 564-4694 15. r-i Detailed Operations Program I"! BOp Sketch Status of well claSsifications as: I~ Oil [] Gas r-I Suspended Service Prepared By Name/Number: rerrie Hubble, 564-4628 17. I hereby certify that the foregoin~q !s true and correct to the best of my knowledge Signe~ Ted Stagg ~.~,~~ ~ Title C TDrilling~E~gineer Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev. 06/15/88 Approval No. 3 0 0 '-' ~ ~" Commissioner Date Submit In Tripl'icate / DATE / CHECK NO. H 172566 fe,o3/oo I I ~)0i725&& v,-~ ~i..t=,:31~t) I ~ I t u DATE INVOICE / cREDrr MEMO DESCRIPTION GROSS DISCOUNT NET ~80~00 :KOSO200d ' 100. O0 1~0."00 HANDLIi~IG INST: TERR [E Xq&28 ..... rile ATTACHED CHECK IS I# PA~'C-'~.'T ~ .r. MS DE~RiBED ABOVE. B I[e]l I1~-~1 [] ~ 100- O0 100. O0 PAY '!i i!i:..:;i i; ..././:.:~ii?.i!!!: ;?.~. ,o,:~.:V^UD AFTER ~20 D~VS :." ..: .::....- .:':'. ...... ANCHORAGE AK 99501 III II ? ~! 5~3 ~,Il" I:O[i II ~]l:l ~ll~l~ 51: Ol:ll~l~ h ]. ~ll" WELL PERMIT CHECKLIST FIELD & POOL CLASS ADMINISTRATION 1. ^?5 . 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. ~'.. tj *~D 13. WELL NAME. ,,,/-. 2-?_-~ PROGRAM: exp. ENGINEERING Permit fee attached ....................... Lease number appropriate ................... Unique well name and.number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party .................. . Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved...' 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet~regulation ....... ...< ....... 26. BOPE press rating appropriate; test to .~c;(~(,.~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOL AREA UNIT# wellbore seg. ann. disposal para req ON/OFF SHORE (~ N IGEOLOGY 30. .31. 32. ~- :34. Data presented on potential overpressure zones y ' ';;; -?../4:-. ,,ff__ ~ ~ ~~ 9,,,/~ Se,sm,c analysts of shallow gas zones .......... .".. ,,, ~~N ~ ~=w-~~ ~- Seabed condition su~ey (if.off-shore) ............ ~ ~ Y N - ~~'~ Contact name/phone for weekly progress repoffs [exp~~ onlY] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and . (E) will ,not circumvent 20 AAC 25.252 or 20. AAC 25.412. Y N GEOLOGY: ENGINEERING: UlClAnnular ' "C(~MMISSIoN: .. Comments/Instructions: Z 0 -...I Z -.-I -1'" c:~nsoffiCe\wordian~diana\checklist (rev. 02/17100) ... 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 APPENDIXi. No special 'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Apr 10 09:24:04 2001 Reel Header Service name ............. LISTPE Date ..................... 01/04/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/04/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 1 AK-MW-00157 B. JAHN D. MASKELL / J-22A 500292169801 BP Exploration (Alaska), Inc. Sperry Sun 09-APR-01 MAD RUN 1 AK-MW-00157 B. JAHN D. MASKELL / 9 lin 13E 682 803 76.94 .00 .00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) .000 7.000 10186.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC GR LOG (CPNL) OF 8/30/00. THIS WELL KICKS OFF J-22 AT 10186' MD, 8867' SSTVD (TOP OF WHIPSTOCK). ALL MWD LOG AND HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. o A MADPASS (MAD) WAS PERFORMED WHILE TRIPPING OUT OF THE HOLE AFTER MWD RUN 1. THIS DATA IS PRESENTED AS A TAIL TO THIS LOG. 5. MWD RUN 1 REPRESENTS WELL J-22A WITH API % 50-029-21698-01. THIS WELL REACHED A TOTAL DEPTH OF 10387' MD, 9006' SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY SHALLOW SPACING SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME CURVES WITH THE EXTENSION "M" ARE MEASURED AFTER DRILLING (MAD) $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH GR 10157 5 RPX 10174 0 RPS 10174 0 RPM 10174 0 RPD 10174 0 FET 10205 5 ROP 10207 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) -- BASELINE DEPTH 10157 5 10158 5 10160 5 10164 5 10166 5 10169 0 10173 5 10175 0 10185 0 10187 0 10195 0 10199 0 10207 5 10222 0 10227 0 10230 0 10234 5 10235 5 10239 0 10239 5 10242 0 10246.0 10249 5 10254 5 10265 5 10267 5 10270 0 10274 5 10277 0 10281 5 10283.5 10387.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: GR 10161 0 10162 0 10163 5 10169 0 10171 5 10173 5 10175 5 10176 5 10187 0 10188 5 10195 5 10199 5 10207 5 10222 5 10227 0 10230 5 10235 0 10236 0 10238 5 10239 5 10241 0 10244 5 10249 5 10254 0 10265 5 10268 0 10269 5 10274 5 10277 5 10281 0 10283 0 10387 0 STOP DEPTH 10341.5 10352.5 10352.5 10352.5 10352.5 10352.5 10387.5 EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. BIT RUN NO MERGE TOP MERGE BASE 1 10161..0 10387.0 $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Last Name Service Unit Reading DEPT 10387 5 ROP MWD 10387 5 GR MWD 10341 5 RPX MWD 10352 5 RPS MWD 10352 5 RPM MWD 10352 5 RPD MWD 10352 5 FET MWD 10352 5 FT FT/H API OHMM OHMM OHMM OHMM HR Min 10157.5 2.86 17 03 0 33 0 14 0 12 0 16 0 48 Max 10387.5 1785.61 167.8 2000 2000 1751.98 1905.76 1.75 Mean 10272.5 82.276 28.073 63.5551 40.4287 23.0523 39.9529 1.11953 Nsam 461 362 369 358 358 358 358 295 First Reading 10157.5 10207 10157.5 10174 10174 10174 10174 10205.5 First Reading For Entire File .......... 10157.5 Last Reading For Entire File ........... 10387.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX RAT FET $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: .5000 START DEPTH 10158.0 10175 5 10175 5 10175 5 10175 5 10200 5 10206 5 STOP DEPTH 10343 5 10354 5 10354 5 10354 5 10354 5 10387 5 10354 5 MAD RUN NO. MAD PASS NO. MERGE TOP 1 0 10161.0 MERGED MAD PASS. $ MERGE BASE 10387.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HR 4 1 68 28 8 Last Name Service Unit Min Max Reading DEPT FT 10158 10387.5 10387.5 RAT MAD FT/H 79.95 312.28 10387.5 GR MAD API 15.63 163.23 10343.5 RPX MAD OHMM 0.2 2000 10354.5 RPS MAD OHMM 0.14 2000 10354.5 RPM MAD OHMM 0.11 2000 10354.5 RPD MAD OHMM 0.37 2000 10354.5 FET MAD HR 0.5149 6.3211 10354.5 Mean 10272.8 158.667 28.6534 24.9742 72.1084 114.834 129.853 3.22698 Nsam 460 375 372 359 359 359 359 297 First Reading 10158 10200.5 10158 10175.5 10175.5 10175.5 10175.5 10206.5 First Reading For Entire File .......... 10158 Last Reading For Entire File ........... 10387.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/10 Maximum Physical Record..65535 File Type ................. LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10161 0 RPD 10176 0 RPM 10176 0 RPS 10176 0 RPX 10176 0 FET 10205 5 ROP 10207 0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 10341.0 10352.0 10352.0 10352.0 10352.0 10352.0 10387.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 25-AUG-00 Insite 4.05.2 0.43 Memory 10387.0 41.1 49.5 TOOL NUMBER 72829 PB01613RF3 3.750 FLO PRO 8.65 .0 9.0 24500 7.8 .160 .063 .220 .160 55.0 150.0 55.0 55.0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD010 FT/H 4 1 68 MWD010 API 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Last Name Service Unit Reading DEPT FT 10387 ROP MWD010 FT/H 10387 GR MWD010 API 10341 RPX MWD010 OHMM 10352 RPS MWD010 OHMH 10352 RPM MWD010 OHMM 10352 RPD MWD010 OHMM 10352 FET MWD010 HR 10352 Min 10161 2.86 17 03 0 33 0 14 0 12 0 16 0 48 Max 10387 1785.61 167.8 2000 2000 1751.98 1905.76 1.75 Mean 10274 82.4595 28.2148 59.4548 35.1023 22.2134 39.9237 1.11609 Nsam 453 361 361 353 353 353 353 294 First Reading 10161 10207 10161 10176 10176 10176 10176 10205.5 First Reading For Entire File .......... 10161 Last Reading For Entire File ........... 10387 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MAD Curves and log header data for each pass.of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY .5000 1 0 VENDOR TOOL CODE START DEPTH GR RPS RPX RPM RPD RAT FET $ LOG HEADER DATA DATE LOGGED: SOFTWARE 10161 5 10177 0 10177 0 10177 0 10177 0 10201 0 10206 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY {LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): STOP DEPTH 10343.0 10354.0 10354.0 10354.0 10354.0 10387.0 10354.0 25-AUG-00 Insite 4.05.2 0.43 Memory 10387.0 41.1 49.5 TOOL NUMBER 72829 PB01613RF3 3.750 FLO PRO 8.65 .0 9.0 24500 7.8 .160 55.0 Dat MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ a Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 0 RAT MAD010 FT/H 4 1 68 4 GR MAD010 API 4 1 68 8 RPX MAD010 OHMM 4 1 68 12 RPS MAD010 OHMM 4 t 68 16 RPM MAD010 OHMM 4 1 68 20 RPD MAD010 OHMM 4 1 68 24 FET MAD010 HR 4 1 68 28 .063 .220 .160 150.0 55.0 55.0 Channel 1 2 3 4 5 6 7 8 Last Name Service Unit Min Max Mean Reading DEPT FT 10161.5 10387 10274.3 10387 RAT MAD010 FT/H 79.95 312.28 158.359 10387 GR MAD010 API 15.63 163.23 28.8148 10343 RPX MAD010 OHMM 0.2 2000 25.1981 10354 RPS MAD010 OHMM 0.14 2000 72.7848 10354 RPM MAD010 OHMM 0.11 2000 112.132 10354 RPD MAD010 OHMM 0.37 2000 132.782 10354 FET MAD010 HR 0.5149 6.3211 3.22538 10354 Nsam 452 373 364 355 355 355 355 296 First Reading 10161.5 10201 10161.5 10177 10177 10177 10177 10206.5 First Reading For Entire File .......... 10161.5 Last Reading For Entire File ........... 10387 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/04/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/04/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
