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Home My WebLink About192-1357. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU AGI-03 Install Tbg patch over SSSVN Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 192-135 50-029-22318-00-00 11540 Conductor Surface Intermediate Production Liner 8536 76 4023 10887 784 11496 20" 13-3/8" 9-5/8" 7" 8503 36 - 112 37 - 4060 34 - 10921 10754 - 11538 36 - 112 37 - 3483 34 - 8068 7942 - 8535 unknown 470 2270 4760 7020 none 1490 4930 6870 8160 11080 - 11473 7" 26# x 7-5/8" 29.7# L-80 33 - 10672 8187 - 8485 Structural 5-1/2" TNT , 10559 , 7794 7" A-1 , 2143 , 2103 10559 , 10679 7794 , 7885 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0034628 , 0028301 33 - 7880 0 0 0 204825 0 0 0 225 0 3270 323-580 13b. Pools active after work:PRUDHOE OIL 5-1/2" Baker SB-3A , 10679 , 7885 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 4:21 pm, Jun 13, 2024 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.06.13 13:35:54 - 08'00' Eric Dickerman (4002) DSR-6/13/24 RBDMS JSB 061924 WCB 9-9-2024 ACTIVITYDATE SUMMARY 12/27/2023 CTU #9 1.75" coil 0.156WT 16520' Objective: Pull A-1 injection valve, L&K, Mill 6" ID BP6i landing nipple to 6.10" ID. Standby for WS to RU Nabors 7" bops. ***In progress*** 12/28/2023 CTU #9 1.75" coil 0.156WT 16520' Objective: Pull A-1 injection valve, L&K, Mill 6" ID BP6i landing nipple to 6.10" ID. 7" BOPs rigged up and PT'd. MIRU. Trying to Test the BOP. Got it wrapped with a parachute. RU re-Circ skid to UR and Return Tank. Unable to get blind shear and pipe slips to pass. Nabors rep called out to swap out ram seals. Scaffold called out for work platform. ***In progress*** 12/29/2023 CTU #9 1.75" coil 0.156WT 16520' Objective: Pull A-1 injection valve, L&K, Mill 6" ID BP6i landing nipple to 6.10" ID. RU scaffolding for work platform to swap out BOP ram seals. Still Trying to get BOPs tested. Unable to get bops tested. Job delayed until BOPs get troubleshooted at Nabors shop. ***In progress*** 12/30/2023 CTU #9 1.75" coil 0.156WT 16520' Objective: Pull A-1 injection valve, L&K, Mill 6" ID BP6i landing nipple to 6.10" ID. RDMO ***Job incomplete*** 1/8/2024 CTU #9 1.75" coil 0.156WT Objective: Fish A-1 injection valve, Mill BP6-i safety valve nipple. Unit still in shop with mechanical issues. Hyd oil showing up in marco gear box. Snow Removal. Well Support RU. Start NU 7" Nabor BOPs. ***Continue on WSR 1/9/23*** 1/9/2024 CTU #9 1.75" coil 0.156WT Objective: Fish A-1 injection valve, Mill BP6-i safety valve nipple. NU 7" Nabor BOPs. PT. MIRU CTU 9. Function BOPs. RU scaffolding/install hooch. BOP Test ***Continue on WSR 1/10/24*** 1/9/2024 Assist CTU, Pump 73 bbls 60/40 @ 90* into Coils. Assist CTU with BOP test. ***Job Continued 1-10-24*** Daily Report of Well Operations PBU AGI-03 Daily Report of Well Operations PBU AGI-03 1/10/2024 CTU #9 1.75" coil 0.156WT Objective: Fish A-1 injection valve, Mill BP6-i safety valve nipple. Finish 7" Nabor BOP Test. MU and RIH w/ YJ Fishing BHA baited w/ 7" PRS. Tag @ 2124.8' CTM / 2130' Mech twice. POOH. NO Fish A-1 Inj Valve. RIH. Tag @ 2126.1 CTM / 2129' Mech. Tag while pump down CTBS. Dry Tag 3rd time. POOH. NO Fish A-1 Inj Valve. Add Centralizer w/ baited 7" PRS. RIH. Tag same spot. PUH 4k over break back over. Tried pumping down CTBS. POOH. NO Fish A-1 Inj Vavle. MU Baited Slim Line pulling tool. RIH. Tag 2124 ctm / 2129 Mech. **Perform Well Control Drill / Leak at kill port off BOPs and then H2S Monitor goes*** POOH, Recovered A-1 Injection valve. M/U JSN, RIH to 9800' start killing well form bottom ***Continued to WSR on 1/11/24*** 1/10/2024 ***Job Continued from 1-09-24*** Assist CTU. Pumped 1 bbls 60/40 to do Low and High BOP test. 1/11/2024 CTU #9 1.75" coil 0.156WT Objective: Fish A-1 injection valve, Mill BP6-i safety valve nipple. Continue killing well form bottom. RDMO CTU & Re-Circ Skid. WOW ***Job NOT Complete / WOW*** 1/14/2024 CTU #9 1.75" coil 0.156WT / Job Scope: Fish A-1 injection valve, Kill Well. Mill BP6- i safety valve nipple. Mobilize CTU 9 from Slb Shop. Snow Removal. MIRU Re-Circ Skid & CTU 9. Function test BOPs ***Continued to WSR on 1/14/24*** 1/15/2024 CTU #9 1.75" coil 0.156WT / Job Scope: Fish A-1 injection valve, Kill Well. Mill BP6- i safety valve nipple. Finish R/U. M/U 2.5" JSN RIH to load well from bottom up. POOH Circ. BD JSN BHA. MU YJ 6.125" Parabolic Mill BHA. RIH. Start Milling BP 6-i nipple @ 2124.4' CTM. Mill nipple, RIH 1.5ft past and tagging with no motorwork. Attempt multiple times with same result. POOH to inspect BHA ***Continued to WSR on 1/16/24*** 1/16/2024 CTU #9 1.75" coil 0.156WT / Job Scope: Fish A-1 injection valve, Kill Well. Mill BP6- i safety valve nipple. RIH after swapping out 2-7/8" motor. Continue milling landing nipple. Keep stalling, not making anymore footage. POOH. Bit wore on sides. Gauge 6.1". (going to reconfigure Bit - take couple day's). BD YJ BHA. MU 2.5" JSN. RIH FP well. RDMO CTU 9. ***Job Not Complete*** 1/30/2024 CTU#9 1.75" CT. Job Scope: Mill SSSV Nipple. MIRU CTU. Build hooch around Nabors BOP's. ***In Progress*** Daily Report of Well Operations PBU AGI-03 1/31/2024 CTU#9 1.75" CT. Job Scope: Mill SSSV Nipple Perform BOP Test on Nabor's 7-1/16" BOP's. Stack riser and make up tools and PT. RIH w/ 3" Nozzle to 9750' CTM. Circulate in 1% Slick KCL to kill well. RIH w/ Yellow Jacket 6.10" Parabolic Milling BHA ( 6.06" Stabilizer above the motor). Displace Coil to Slick KCL. Dry Tag SVLN at 2076' (electronic counter was slipping while Rih). Establish free spin. Begin time milling. Milling time = 2hrs at midnight, 1 stall. ***Continue Job on 2/1/2024*** 2/1/2024 CTU#9 1.75" CT. Job Scope: Mill SSSV Nipple Continue Milling SSSV Nip. Mill on nipple an additional 1hr (3hrs total). Mill thru SSSV Nipple. Reciprocate across nipple. Dry drift thru SSSV Nipple clean. Pooh. Freeze Protect Coil w/ Diesel. At surface gauge mill. 6.125" Go, 6.06" Nogo (same as before mill was run). RIH w/ 3.0" Nozzle. Lay in diesel FP from 2600'. RDMO ***Job Complete*** 2/2/2024 ***WELL S/I ON ARRIVAL*** STAND BY FOR KILL LINE INSTALLATION. ***CONTINUED ON 2-3-24*** 2/3/2024 ***CONTINUED FROM 2-2-24*** DRIFTED THROUGH SVLN W/ KEYLESS DB LOCK & ISO SLEEVE (6.05" nogo). SET LOCK RELEASING TOOL @ 9861' SLM. JARRED DOWN ON LOCK RELEASING TOOL W/ 2.72" BLIND BOX. PULLED DSSSV FROM 9861' SLM. RAN 3" PUMP BAILER TO 10,684' SLM. ~2 CUPS OF SCHMOO; METAL MARKS ON BAILER BOTTOM. RAN 5 1/2" GR TO 10,682' SLM. UNABLE TO LATCH RHC PLUG. ***WSR CONTINUED ON 2-4-24*** 2/4/2024 ***WSR CONTINUED FROM 2-3-24*** RAN KJ, AND 5 1/2" GR TO 10,682' SLM. UNABLE TO LATCH RHC PLUG BODY. RAN 10' x 2.5" PUMP BAILER TO 10,682' SLM (EMPTY, W/ METAL MARKS ON BAILER BOTTOM). RAN KJ, 4.50" CENT, DE-CENT, AND 4.40" LIB TO 10,684' SLM (LIB shows fishneck on outter edge, and 2 metal gouges on face). RAN 5 1/2" BRUSH & 3.8" MAGNET TO 10,684' SLM, NO RECOVERY RAN 3 1/2" PUMP BAILER, MULESHOE WICKER BASKET BOTTOM TO 10,684' SLM, RECOVERED VARIOUS SMALL METAL CHUNKS & BRASS NOSECONE FROM E-LINE CUTTER ATTEMPTED TO LATCH RHC FISHING NECK W/ NO LUCK RAN 3 1/2" PUMP BAILER, MULESHOE WICKER BASKET BOTTOM TO 10,684' SLM, RECOVERED 3 SMALL METAL CHUNKS RAN 3" PUMP BAILER TO 10,684' SLM, NO RECOVERY RAN 3.5" MAGNET TO 10,684' SLM, NO RECOVERY RAN 3.8" BARBELLED CENTRALIZERS & POCKET BRUSH W/ 4" BRISTLES TO 10,684' SLM. RAN 2.5" PUMP BALIER TO 10,684' SLM (NO RETURNS). RAN 5 1/2" GR TO 10,684' SLM. UNSEATED RHC PLUG BODY. HUNG UP IN X NIPPLE @ 10,595' MD; SHEARED GR. ***WSR CONTINUED ON 2-5-24*** Daily Report of Well Operations PBU AGI-03 2/5/2024 ***WSR CONTINUED FROM 2-4-24*** MULTIPLE BAILER & GS RUNS ATTEMPTING TO FISH RHC FROM 10,684' SLM. ABLE TO MOVE RHC TO X NIPPLE @ 10,595' MD, BUT UNABLE TO STAY LATCHED. RAN 3.80" BAR BELL AND 3.68" LIB TO 10,686' SLM (DEBRIS IN MIDDLE OF LIB). RAN 2.5" HYD BAILER W/ 3.50" FINGER BASKET TO 10,686' SLM. FLUID IN BAILER; NO SOLIDS. ***WSR CONTINUED ON 2-6-24*** 2/6/2024 ***WSR CONTINUED FROM 2-5-24*** RAN 2 1/2" HYDROSTATIC BAILER W/ 3.50" RUBBER GETTER BTM TO 10,684' SLM, NO RECOVERY RAN 3.8" BARBELL CENTRALIZERS & WIRE GRAB SPEAR TO 10,684' SLM RAN 5 1/2" BRUSH & 2.6" MAGNET TO 10,684' SLM, NO RECOVERY RAN 3" PUMP BAILER TO 10,684' SLM, NO RECOVERY RAN BAITED 5 1/2" GS (trimmed some metal off the core bottom), TO 10,684' SLM, ABLE TO GRAB RHC BUT STILL SLIPS OFF IN X NIPPLE @ 10,595' MD RETRIED BAITED 5 1/2" GS (trimmed a little more off bottom) W/ SAME RESULTS, MARKS ON BTM OF CORE RAN 4.5" BARBELL CENTRALIZERS & 2.59" CHISEL TO 10,684' SLM. JAR DOWN 30 MINS. RAN 3.5" PUMP BAILER TO 10,684' SLM (NO RECOVERY). RAN 4.50" BARBELL AND 3.0" STAR BIT TO 10,686'. JAR DOWN 20 MINS. RAN 2.5" HYD BAILER W/ 3.50" FINGER BASKET TO 10,687' SLM. NO RECOVERY. ***CONTINUED ON 2-7-24*** 2/7/2024 ***WSR CONTINUED FROM 2-6-24*** RAN 5 1/2" GR TO RHC @ 10,684' SLM. ABLE TO LATCH, BUT SLIPPING OFF. RAN 4.5" BAR-BELL AND 3" LIB TO 10,684' SLM. DEBRIS IN CENTER OF LIB FACE. RAN 4.5" CENT, 2' x 1 7/8", 4.5" CENT, 2.55" ROLLER DOG TO 10,684' SLM; NO SUCCESS. RAN 5 1/2" G-FISHING NECK SPEAR TO 10,684' SLM; UNABLE TO LATCH. RAN 4.50" BAR-BELL AND SPOON CHISEL (C-7) TO 10,684' SLM; JARRED DOWN 20 MINS. RAN 5 1/2" GS (DOGS SIMILAR TO SUPER GS) TO 10,684' SLM, UNABLE TO LATCH. RAN 4.50" BAR-BELL, AND 3.70" LIB TO 10,685' SLM. DEBRIS IN CENTER OF FACE. ***WSR CONTINUED ON 2-8-24*** Daily Report of Well Operations PBU AGI-03 2/8/2024 ***WSR CONTINUED FROM 2-7-24*** RAN 4.50" BARBELL w/ 5-1/2" GU BODY (went in f/n ~1/2") RAN 2.50" HYDROSTATIC BAILER w/ 4.5 BELL GUIDE FLUTTER BASKET (recovered 1 small piece of non ferrous metal) RAN 4.50" BARBELL w/ 3.63" MULESHOE BOX TAP (one tattle tale pin sheared) RAN 4.50" BARBELL w/ 3" SAMPLE BAILER w/ MULESHOE GATOR TOOTH BOTTOM (teeth bent inwards) RAN 4.50" BARBELL w/ BOX TAP (no recovery) RAN 5' x 3.5" PUMP BAILER, GATORED TOOTH BOTTOM (didn't go inside f/n) RAN 4.50" BARBELL w/ SALMON MOUTH BOX TAP (spread outward w/ mark 1/2" inside) RAN 4.50" BARBELL w/ DUAL SALMON MOUTH GATORED BOTTOM (small pieces left in hole) RAN 4.50" BARBELL w/ 3.50" MAGNET (recovered missing piece of bottom). RAN 4.50" BARBELL AND 3.50" HOLLOW CORE LIB. ***WELL SECURE ON DEPARTURE*** 3/20/2024 ***WELL S/I ON ARRIVAL*** RAN 10' X 3" PUMP BAILER, FLAPPER BOTTOM, XO, 4.50" FLUTTER CAGE S/D @ 10,683' SLM RECOVERED LARGE PIECE OF CHEM CUTTER (4" O.D., 4-1/4" LONG) RAN 5-1/2" GR, S/D @ 10,683' SLM (FRICTION BITES) RAN 10' X 3" PUMP BAILER MSFB, S/D @ 10,683' SLM ***CONTINUE 3/21/24*** 3/21/2024 ***CONTINUE FROM 3/20/24*** RAN 10' X 3" PUMP BAILER, MSFB, S/D @ 10,683' SLM (recovered several small pieces of metal) RAN 5-1/2" GR, S/D @ 10,683' SLM, SMALL FRICTION BITES RAN 4-1/2" GS W/ (MODIFIED FISH NECK SPEAR), S/D @ 10,683' SLM RAN 2-1/2" SB W/ (MODIFIED FISH NECK SPEAR PRONG), S/D @ 10,683' SLM RAN KJ, 4-1/2" GR, S/D @ 10,679' SLM, 10MIN OF JARRING & SPEAR SLIPS FREE RAN 3" PUMP BAILER, 4.5" FINGER BASKET TO 10,685' SLM, NO RECOVERY RERAN 4-1/2" GS W/ (MODIFIED FISH NECK SPEAR & PRONG) TO 10,683' SLM W/ SAME RESULTS, 10 MIN OF JARRING & SPEAR COMES FREE RAN A BARBELLED 3.69" LIB, SHOWED A CLEAN RING FROM 4" INSIDE FISHING NECK PLANTED 5 1/2" G FISHING NECK SPEAR IN RHC BODY @ 10,685' SLM, GOT THE RHC BODY MOVING, HANGING UP IN X NIPPLE @ 10,595' MD SECOND ATTEMPT TO GET RHC BODY THROUGH X NIPPLE @ 10,595' MD, NOT STICKING IN NIPPLE, GR SHEARED RAN 4 1/2" GR TO RECOVER FISHING NECK SPEAR RAN 5-1/2" GR (modified dogs) S/D @ 10,685' SLM (able to pull up to 10,595' MD, slips off) RAN 3.80" CENT. XO, 3-1/2" BLB, POCKET POKER, S/D @ 10,687' RAN 3.75" CENT. 2' X 1-7/8" STEM, 3.80" CENT. XO 2.11" MAGNET, 2.70" MAGNET, S/D @ 10,687' ***CONTINUE 3/22/24*** Daily Report of Well Operations PBU AGI-03 3/22/2024 ***CONTINUE FROM 3/21/24*** OOH W/ MAGNET RUN (recovered meta shavings) RAN 4.54" CENT. 4.40" LIB, S/D @ 10,687' SLM (shows partial 5-1/2" FN) RAN 5-1/2" GR, 5-1/2" BAIT SUB, TAPERED TAP FOR 5-1/2" FN, S/D @ 10,685' SLM, ABLE TO GET BITES BUT SLIPPING OFF RAN 5 1/2" G FISHING NECK SPEAR TO RHC @ 10,685' SLM, ABLE TO GET BITES BUT SLIPPING OFF RAN MODIFIED FISHING NECK SPEAR & INNER PRONG TO RHC @ 10,685' SLM, ABLE TO GET 10 MINUTES OF JARRING BEFORE SLIPPING OUT, GRAPPLES WERE PUSHED INTO EXPANDER MANDREL RESET MODIFIED FISHING NECK SPEAR W/ BK-DGLV INSIDE (smaller od than the original prong so it can push the grapples outward) RAN 4.5" BARBELL CENTRALIZERS, 2.5" BLIND BOX TO TAP DGLV INTO GRAPPLE RAN 4-1/2" GS S/D @10,687' SLM (PUH TO X-NIPPLE @ 10,595' MD) RAN 4-1/2" GS S/D @ 10,595' MD (sticks sometimes, 3 hours jarring) ***CONTINUE 3/23/24*** 3/23/2024 ***CONTINUE FROM 3/22/24*** RAN 4-1-1/2" GS S/D @ 10,612' SLM (attempt to pass through x-nip @ 10,595' MD) RAN 4-1/2" GS S/D @ 10,678' SLM (attempted to pass through x-nip @ 10,595' md, wire parted leaving ~2,316' of wire in hole) RAN 4.25" BLIND BOX TO TOP OF TOOLSTRING @ 10,659' SLM, CUT WIRE ON TOP OF ROPE SOCKET WIRE BALLED UP AROUND TOOLSTRING WHILE PULLING OOH, LOST ACTION, WORKED UP TO 1,286' SLM, STOPPED TO AVOID BRING BALLED WIRE ACROSS TREE VALVES DROPPED A 4.50" CENTRALIZER, 2' OF 1 7/8" STEM, 1 7/8" GO-DEVIL, WIRE DIDN'T CUT DROPPED A HES KINLEY CUTTER, WIRE DIDN'T CUT (1-3/4" FN W/ 3 dots on top) ***CONTINUE 3/24/24*** 3/23/2024 T/I/O = 300/0/100. Temp = SI. T FL (SL req). T FL @ (near surface). SL in control of well upon departure. 5:15 3/23/2024 TFS Unit 4 Assist SL, Pump 7 BBLS 60/40 to load TBG, SL in control of well upon departure Daily Report of Well Operations PBU AGI-03 3/24/2024 ***CONTINUE FROM 3/23/24*** DROPPED 2ND KINLEY CUTTER, WIRE CUT @ 1,286' SLM RIG DOWN, MOVE OUT ***WELL LEFT S/I*** ****3 CUTTER BARS LIH DETAILS IN LOG**** 1- CENTRALIZED GO-DEVIL DIDN'T CUT 1- KINLEY 1-3/4" FN 3-DOTS ON TOP, DIDN'T CUT 1- KINLEY 1" FN (1-3/8" JD PULLING TOOL) CUT @ 1,286' SLM ***2 SLICKLINE TOOLSTRINGS, MODIFIED SPEAR, & 2,316' OF .125" SLICKLINE*** SLICKLINE TOOL STRING 1: 1.75" RS, QC, 8' X 2-5/8" STEM, QC, 2-1/8" OJ, QC, KJ LSS, QC, KJ, 4-1/2" GS. OAL = 26'. MODIFIED SPEAR - OAL = 27", 4.5" od, 3.11" ID down to grapple body, 1.69" ID on grapple body SLICKLINE TOOL STRING 2: 1.75" RS, QC, 5' x 2 5/8", QC, 1 3/4" OJ'S,QC, 2 1/8" TUBE JARS, QC, 4.25" BLIND BOX. OAL = 20.75' 4/6/2024 T/I/O=550/0/100 (Assist E-Line Patch/Tubing liner) TFS Unit 3 Pumped 15 bbls Neat meth down TBG to attempt load< TBG pressured up and job postponed Well left in Yellow Jacket control upon departure FWHP= 2400/0/100 4/6/2024 YellowJacket E-Line Jobe Scope: Run camera to top of fish Shop test YJ WL Valves. Well Support LD Gate valve and 27' riser off tree. Install 7" flanged 7" Otis connection on top of P-sub and PT to 4000 psi. MIRU Eline and Thunderbird Pump. PT TBird pump/ lines to 4000 psi. On-line w/ neat meth 1 bpm. pressured up from 550 to 3200 psi w/ 6 bbls away. Holding. Bled to bleed trailer (mostly gas). Appeared well flowing @ ~325 psi. Bleed additional 25 mins (gas). SI and attempt to bullhead. Pressured up 3200 psi w/ 9 bbls away. Bled back to 550 psi. Gas and fluid (~4 bbls fluid returned). RD E-Line and TBird pump. Swab stem stripped. WS to replace valve. ***Job incomplete - unable to pump clear fluid for video log*** 4/7/2024 T/I/O = 440/0/100. Temp = SI. T FL (Slickline). T FL @ surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:00 4/8/2024 ***PREP FOR UPCOMING FISHING JOB*** 4/9/2024 ***WELL S/I ON ARRIVAL*** R/U .160" WIRE & 7" GEAR, CRANE SWAP TO 125 CRANE ESTABLISH MINIMUM CLOSING PRESSURE FOR BOTH SET OF WLV'S (600 psi UPPER SET, 450 psi LOWER SET) TEMPS BELOW -20 (MINIMUM WORKING TEMP FOR MANLIFT). PULLED UPPER CUTTER BAR (W/ 1.0" F/N) FROM 1324' SLM. LATCHED LOWER CUTTER BAR @ 1324' SLM. JARRED 1 HOUR AND TOP SUB ON TUBE JARS BROKE OFF ROD CURRENTLY SETTING UP TO FISH TUBE JARS AND OVESHOT ***CONTINUED ON 4-10-24*** Daily Report of Well Operations PBU AGI-03 4/10/2024 ***WSR CONTINUED FROM 4-9-24*** PULLED BROKEN TUBE JARS AND SHEARED WEATHERFORD RELEASABLE OVERSHOT FROM 1307' SLM. PULLED 4.50" CENT / GO-DEVIL ASSY FROM 1315' SLM. PULLED 2nd KINLEY CUTTER FROM 1,326' SLM. RAN 4.65" LIB TO 1329' SLM. WIRE ON SIDES OF LIB; FACE ALSO HAS SOME MARKS FROM WIRE. RAN 7" BRUSH, AND 5.90" WIRE FINDER TO 1328' SLM. NO SIGN OF WIRE UP HIGHER, AND NO OVERPULLS. MANLIFT OPERATIONS SUSPENDED DUE TO WIND. CONDUCT WELL CONTROL DRILL W/ WSL. ***CONTINUED ON 4-11-24*** 4/11/2024 ***CONTINUED FROM 04/11/2024 WSR*** RAN 4-1/2" GS, 4-1/2" BAIT SUB, 7" BRUSH, 7" BRUSH, 4.50" 3 PRONG WIRE GRAB TO 1331' SLM. PULLED LARGE BALL OF WIRE (majority of est 2316' of lost wire), AND 26' UPPER FISH TOOLSTRING. ***Had to cut wire w/ swab; suspect more wire & possible stragglers remain in well. FUNCTION TEST WLV's & PT WLV RAMS ON TREE. IN HOLE W/ 4-1/2" GS, 4-1/2" BAIT SUB, 7" BRUSH, 7" BRUSH, 4.50" 3 PRONG WIRE GRAB. ***WSR CONTINUED ON 4-12-24*** 4/12/2024 ***WSR CONTINUED FROM 4-11-24*** PULLED 170' BALL OF WIRE FROM 32' SLM. STRIPPED ADDITIONAL 140' OF WIRE. LAID DOWN FOR WELL SUPPORT TO RIG DOWN RISER FROM WELLHEAD. SEND WLV'S TO SHOP TO BE STUMP TESTED. WINDS TO 40 MPH. MOVE TO WEATHER TICKET. ***CONTINUED ON 4-13-24*** 4/13/2024 ***WSR CONTINUED FROM 4-12-24*** OFF WEATHER HOLD, RIG BACK UP w/ .160" WIRE RAN DUAL 7" BRUSHES w/ 4.50" 3 PRONG WIRE GRAB TO 5-1/2" XO @ 10,503' MD (no wire) PERFORM WELL CONTROL & MAN DOWN DRILL w/ DAY CREW & WSS RAN 5-1/2" BRUSH w/ 4.50" 3 PRONG WIRE GRAB, LIGHTLY SD ON ROPE SOCKET @ 10,663' SLM (no wire). RECOVERED LOST TOOLSTRING FROM 10,663' SLM. PULLED SPEAR AND RHC PLUG BODY FROM 10,684' SLM. ABLE TO GET RHC STUCK IN X NIPPLE @ 10,595' MD (shear gs, RHC stays in nipple). PULLED RHC PLUG BODY FROM 10,595' MD (SEVERLY DEFORMED, AND GOUGED. FISHNECK BULGED). RAN 3.50" PUMP BAILER TO 10,684' SLM. 2 CUPS OF SAND, AND 1 CUP OF ASSORTED METAL DEBRIS. IN HOLE W/ 5 1/2" BRUSH, AND 2.60" MAGNET. ***CONTINUED ON 4-14-24*** Daily Report of Well Operations PBU AGI-03 4/14/2024 ***WSR CONTINUED FROM 4-13-24*** RAN 5 1/2" BRUSH AND 2.60" MAGNET TO 10,687' SLM. RECOVERED 2" PIECE OF WIRE. RAN 12' x 3 1/2" PUMP BAILER W/ FLUTTER CAGE TO 10,688' SLM. RECOVERED 1" x 1" x 1/2" CHUNK OF METAL. BAILED SAND FROM 10,688' TO 10,692' SLM LAY DOWN & SWAP TO .125C BAILED SAND FROM 10,692' SLM TO 10,697' SLM RAN 3.85" GAUGE RING w/ 5-1/2" BRUSH TO 10,697' SLM BAILED SAND FROM 10,697' SLM TO 10,707' SLM RAN 4.40" GAUGE RING w/ 5-1/2" BRUSH TO 10,710' SLM. BAILED SAND FROM 10,709' SLM TO 10,718' SLM. IN HOLE W/ 5 1/2" BRUSH AND 4.40" GAUGE RING. ***WSR CONTINUED ON 4-15-24*** 4/15/2024 ***WSR CONTINUED FROM 4-15-24*** RAN 5 1/2" BRUSH AND 4.40" GAUGE RING TO 10,717' SLM BAILED SAND FROM TOP OF PXN PRONG @ 10,718' SLM. RAN 2 1/2" RS IN 3.60" BELL GUIDE TO PXN PRONG @ 10,716' SLM. 1000# OJ LICK AND 1200# OJ LICK AND RS SHEARS. RAN 2 1/2" SB IN 3.60" BELL GUIDE TO PRONG @ 10,716' SLM. HIT 1200 - 1500# OJ LICKS 10 MINS (SHUCKED A DOG AND SPLIT SB SKIRT). RAN 4.50" CENT, 2-1/2" JD IN 3.60" BELL GUIDE, HIT 1800# JAR LICK FOR 18 MINS, PULLED PRONG FROM PXN PLUG BODY @ 10,747' MD BAILED SAND W/ 3 1/2" PUMP BAILER FROM 10,716' SLM TO 10,722' SLM. BAILED W/ 2 1/2" PUMP BAILER FROM 10,722' TO 10,724' SLM. RAN 4 1/2" GR TO 10,722' SLM; UNABLE TO LATCH PLUG BODY. IN HOLE W/ 4.50" CENT, 3' x 1.875" STEM, 4.50" CENT, 2' x 1.875" STEM, AND 4.40" LIB. ***CONTINUED ON 4-16-24**** 4/16/2024 ***WSR CONTINUED FROM 4-15-24*** RAN 4.50" BAR BELL & 4.40" LIB TO 10,724' SLM. SHOWS 5 1/2" G FISHNECK. RAN 4.50" BAR BELL & 3.68" LIB TO 10,724' SLM. SHOWS FILL. RAN 2 1/2" PUMP BAILER TO 10,724' SLM. (bailer wedged in plug body, recovered 1 quart of sand, flat mark on tip of bailer bottom) RAN 4 1/2" GR TO 10,722' SLM. GOT 1 BITE, 800# OJ LICK AND SLIPPED OUT. UNABLE TO RE-LATCH. RAN 5 1/2" BRUSH AND 2.60" MAGNET TO 10,722' SLM. ONLY METAL SHAVINGS. RAN 5-1/2" BRUSH & 4.54" GAUGE RING TO 10,724' SLM RAN 3" PUMP BAILER TO 10,722' SLM, (no metal marks, 1 cup sand recovered) RAN 5-1/2" BRUSH w/ 1" POCKET POKER (4" BRISTLES) TO 10,724' SLM RAN 3-1/2" PUMP BAILER TO 10,724' SLM (recovered ~1 cup of sand). RAN 3 1/2" PUMP BAILER TO 10,724' SLM (wedged bailer in lock, stripped rod out of bailer). RAN 4.40" BELL GUIDE AND 3" JD TO RECOVER BAILER FROM 10,710' SLM (1 cup of sand). RAN 4 1/2" GR TO 10,724' SLM. GET 1 BITE AND SLIP OUT. GR SHEARED. ***CONTINUED ON 4-17-24*** Daily Report of Well Operations PBU AGI-03 4/17/2024 ***WSR CONTINUED FROM 4-16-24*** RAN 4.50" BAR BELL AND 2.50" STAR BIT TO 10,724' SLM. JARRED DOWN 20 MINS W/ NO DEPTH GAIN. RAN MADE 2 RUNS W/ 10' x 2" DD BAILER TO 10,724' SLM. JARRED DOWN 35 MINS W/ NO DEPTH GAIN (1/2 CUP OF SAND). RAN 4 1/2" GR W/ SHORT CORE TO 10,724' SLM. ABLE TO STICK GR AND HIT LIGHT OJ LICKS, BUT GR SUCKS OUT (appears to be sand). RAN 2.75" CENT w/ 2-1/2" PUMP BAILER TO 10,720' SLM, (recovered 1 cup, saw teeth bent inward, no metal marks) RAN 4.50" CENT BARBELL w/ STAR BIT S-3 TO 10,726' SLM RAN 3" PUMP BAILER TO 10,724' SLM (recovered ~1 gal sand) RAN 3" PUMP BAILER TO 10,725' SLM (no recovery, marks from p-sub on bottom of lock). PULLED PXN PLUG BODY FROM 10,747' MD. RAN 3.80" CENT AND 2.5" SAMPLE BAILER; TAGGED @ 11,432' SLM (11,454' MD) 19' OF PERFS COVERED. DRIFTED CLEANLY W/ 10' x 5.75" BAR BELL ASSY TO 2200' SLM. ***WELL S/I ON DEPARTURE*** 5/9/2024 ***WELL S/I ON ARRIVAL*** RAN 7" Z-6, 5.92" DB LOCK (no lugs or packing) W/ XO (5.93" OD) & 5-1/2" GR, 5.85" x 15' 11" PATCH DRIFT (22' 6" total) TO 2,200' SLM, NO ISSUES ***WELL LEFT S/I ON DEPARTURE*** 5/11/2024 *** WELL FLOWING ON ARRIVAL *** OBJECTIVE: SET WEATHERFORD PATCH RIG UP YJ ELINE AND WEATHERFORD PATCH PT PCE 300 PSI LOW /3600 PSI HIGH. RUN #1 W/ ( CH 1'/ 1.435" ) ( CCL 1.58'/ 3.125" ) ( QC .97'/ 3.125" ) ( FH .25'/ 3.400" ) ( BKR20 5.72'/ 3.84" ) ( WEATHERFORD 19'/ 6.500" ) SET MID ELEMENT OF THE PATCH AT 2135' / CCL OFFSET 15.3' / CCL STOP DEPTH 2119.7' TOP OF PACKER AT 2128', BOTTOM OF PACKER AT 2146' *** WELL SHUT IN ON DEPARTURE, READY FOR COIL *** 5/12/2024 LRS CTU 1, 1.5" Blue coil. Job Objective: Set upper WFT patch and test Travel to location. MIRU CTU. Perform BOP test. Install BOP extension hoses. Make up Baker CTC/MHA. Install spools for riser. Make up patch to coil MHA and RIH. Latch lower anchor at 2127 CTM. Overpull 5K and hold for 2 minutes to confirm latch. Line up to purge control line and cannot pump in. Begin troubleshooting. ***Job Continued on 5/13/2024*** 5/13/2024 LRS CTU #1, 1.5" Blue Coil. Job Objective: Set Upper WFT Patch and Pressure Test Continue troubleshooting control line. Could not pump down the control line. Relay results to OE. Decision made to set the patch. Pump 5/8" ball and set the top patch section. Top of patchset at 2116MD. See well picture file for schematic. POOH and pressure test the control line to 4383 psi for 30 minutes (lost 49/23 psi) = ***Pass***. Stack down riser and RDMO. Pad op noitified of well status on departure. ***Job Complete*** 5/16/2024 A-1 SSSV Passed State Test Set Upper WFT Patch and Pressure Testj Continue troubleshooting control line. Could not pump down the control line. Relaygy results to OE. Decision made to set the patch. Pump 5/8" ball and set the top patch section. Top of patchset at 2116MD. See well picture file for schematic. POOH and pressure test the control line to 4383 psi for 30 minutes (lost 49/23 psi) = ***Pass***. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU AGI-03 Install Tbg patch over SSSVN Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 192-135 50-029-22318-00-00 ADL 0034628 , 0028301 11540 Conductor Surface Intermediate Production Liner 8536 76 4023 10887 784 10747 20" 13-3/8" 9-5/8" 7" 7937 36 - 112 37 - 4060 34 - 10921 10754 - 11538 2600 36 - 112 37 - 3483 34 - 8068 7942 - 8535 unknown (2) 470 2270 4760 7020 10747 1490 4930 6870 8160 11080 - 11473 7" 26# x 7-5/8" 29.7# L-80 23 - 106728187 - 8485 Structural 5-1/2" TNT , 5-1/2" Baker SB-3A No SSSV Installed 10559 , 10679 / 7794 , 7885 Date: Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 11/1/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.10.20 19:15:39 - 08'00' Bo York (1248) 323-580 By Grace Christianson at 1:25 pm, Oct 23, 2023 MGR01NOV23 * 30 minute charted test to 4000 psi of tubing patch by pressuring up on control line. * 24 hour notice to AOGCC for opportunity to witness check valve function test. 10-404 SFD 10/23/2023 DSR-10/24/23&': Gregory Wilson Digitally signed by Gregory Wilson Date: 2023.11.01 15:07:32 -08'00'11/01/23 RBDMS JSB 110223 AGI-03 PTD:192135 Well Name:AGI-03 API Number:500292231800 Current Status:Shut-In Rig:Interventions wellwork Estimated Start Date:11/01/2023 Estimated Duration:3 Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd:N/A Regulatory Contact:Carrie Janowski Permit to Drill Number:192135 First Call Engineer:Dave Bjork 907-564-4672 907-440-0331 Second Call Engineer:Eric Dickerman 907-564-4061 307-250-4013 Current Bottom Hole Pressure:3,480 psi @ 8,800’ TVD 7.6 PPGE | calc from shut in WHP Max. Anticipated Surface Pressure:2,600 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2,600 psi (Taken on 08/09/21) Min ID:4.455” ID ‘XN’ nipple @ 10,747’ MD Max Angle:53 Deg @ 9,602’ Brief Well Summary: AGI-03 was drilled in January 1993 and completed as a 7” monobore injector. The wellbore was in continuous service until Aug 21. An MIT-IA failed in August 21. A plug was set and the tubing was MIT-T to 3,727-psi, a CMIT-TxIA failed at 1.3gpm @ 3,500-psi. A LDL indicated leakpoints at 10,690’ (production packer) and 6,938’. A RWO was performed to repair the PC leaks. The wellbore had brief on-time due to a restriction. The isolation sleeve covering the SCSSV was unable to be retrieved. The SCSSV isolation sleeve is sitting at the 7” crossover above the packer. The plugs used to isolate the reservoir were unable to be completely removed due to the reduced ID in the isolation sleeve. Objective: Mill out the 7” the no-go in the BP6-i nipple. Recover the isolation sleeve, recover the slickline plugs. Set a patch across the BP6-i with integral check valve. The patch will also have an X profile for future isolation/securing and secondary check valve installation if necessary. Proposed Procedure: 1. Service coil. Mill out the 6.0” ID BP6i landing nipple to 6.10” 2. Slickline – Recover the isolation sleeve. Recover the 4.56” X lock, Recover the 4.56” PXN plug 3. E-line – Set onetrip Weatherford EL patch across BP6i nipple with integral A-1 injection valve and 3.81 X profile. Test patch integrity to 4,000-psi down the control line. 4. Integrity - Function test the Injection valve after wellbore has stabilized injection. 24 hour notice to AOGCC for oportunity to witness function test. - mgr 30 minute charted patch test (through control line) to 5000 psi. - mgr AGI-03 PTD:192135 Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. MOC form AGI-03 PTD:192135 Wellbore Schematic Proposed Wellbore Schematic AGI-03 PTD:192135 AGI-03 PTD:192135 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. 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Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC AGI-03 PRUDHOE BAY UNIT AGI-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/21/2022 AGI-03 50-029-22318-00-00 192-135-0 G SPT 7885 1921350 1971 3288 3293 3295 3296 289 509 479 448 4YRTST P Adam Earl 10/21/2022 MIT-IA 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: PRUDHOE BAY UNIT AGI-03 Inspection Date: Tubing OA Packer Depth 508 2404 2396 2389IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE221023105906 BBL Pumped:2.2 BBL Returned:2.4 Wednesday, December 21, 2022 Page 1 of 1 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU 2SHUDWLRQV 3HUIRUPHG 2SHUDWRU1DPH $GGUHVV :HOO&ODVV%HIRUH:RUN3HUPLWWR'ULOO1XPEHU $3,1XPEHU :HOO1DPHDQG1XPEHU /RJV/LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$&)LHOG3RROV $EDQGRQ 6XVSHQG 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 3HUIRUDWH 3OXJ3HUIRUDWLRQV 5HHQWHU6XVS:HOO 2WKHU6WLPXODWH )UDFWXUH6WLPXODWH $OWHU&DVLQJ 3XOO7XELQJ 5HSDLU:HOO 2WKHU &KDQJH$SSURYHG3URJUDP 2SHUDWLRQVVKXWGRZQ 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ &DVLQJ /HQJWK 6L]H 0' 79' %XUVW &ROODSVH 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If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗ůŝŶƚDŽŶƚĂŐƵĞͲ;ͿфĐŵŽŶƚĂŐƵĞΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗^ĂƚƵƌĚĂǇ͕:ƵŶĞϰ͕ϮϬϮϮϴ͗ϬϱWD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖tĂůůĂĐĞ͕ŚƌŝƐ;K'ͿфĐŚƌŝƐ͘ǁĂůůĂĐĞΛĂůĂƐŬĂ͘ŐŽǀх Đ͗ĂǀŝĚũŽƌŬфĂǀŝĚ͘ũŽƌŬΛŚŝůĐŽƌƉ͘ĐŽŵх͖ŶĚƌĞǁKŐŐфŶĚƌĞǁ͘KŐŐΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗'/ͲϬϯŝŶŝƚŝĂůƌŝŐD/dͲd͕D/dͲ/ /ŶŝƚŝĂůƌŝŐD/dͲdĂŶĚD/dͲ/ĨŽƌ'/ͲϬϯŝƐĂƚƚĂĐŚĞĚ͘/ĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐƉůĞĂƐĞůĞƚŵĞŬŶŽǁ͘ ůŝŶƚDŽŶƚĂŐƵĞ ,ŝůĐŽƌƉ^D/ŶŶŽǀĂƚŝŽŶ ϵϬϳͲϲϳϬͲϯϬϵϰKĨĨŝĐĞ ϵϬϳͲϲϳϬͲϯϬϳϬŽŐŚŽƵƐĞ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ubmit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1921350 Type Inj N Tubing 0 4150 4116 4104 Type Test P Packer TVD 7885 BBL Pump 4.5 IA 0 850 850 850 Interval I Test psi 4000 BBL Return 4.5 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1921350 Type Inj N Tubing Open Open Open Open Type Test P Packer TVD 7885 BBL Pump 4.0 IA 0 4136 4112 4102 Interval I Test psi 4000 BBL Return 4.0 OA 100 800 800 800 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Hilcorp North Slope, LLC. Notes: Prudhoe Bay/ PBU/ AGI Pad Clint Montague 05/31/22 Notes:Initial Rig MIT-T. Waived by Adam Earl. Notes: Notes: Notes: PBU AGI-03 PBU AGI-03 Notes:Initial Rig MIT-IA. Waived by Adam Earl. Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec hanicall Integrityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Form 10-426 (Revised 01/2017)2022-0531_MIT_PBU_AGI-03_2tests 5(9,6(' 9 9 9 9 9 9 9 9 3DFNHU79'UHYLVHG -5HJJ 7885 7885 MIT-T. MIT-IA. 3DFNHU79'UHYLVHG 5HJJ-DPHV%2*& )URP&OLQW0RQWDJXH&FPRQWDJXH#KLOFRUSFRP! 6HQW6DWXUGD\-XQH30 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*&:DOODFH&KULV'2*& &F'DYLG%MRUN$QGUHZ2JJ 6XEMHFW$*,LQLWLDOULJ0,770,7,$ $WWDFKPHQWV0,73%8$*,[OV[ /ŶŝƚŝĂůƌŝŐD/dͲdĂŶĚD/dͲ/ĨŽƌ'/ͲϬϯŝƐĂƚƚĂĐŚĞĚ͘/ĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐƉůĞĂƐĞůĞƚŵĞŬŶŽǁ͘ ůŝŶƚDŽŶƚĂŐƵĞ ,ŝůĐŽƌƉ^D/ŶŶŽǀĂƚŝŽŶ ϵϬϳͲϲϳϬͲϯϬϵϰKĨĨŝĐĞ ϵϬϳͲϲϳϬͲϯϬϳϬŽŐŚŽƵƐĞ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ubmit to: OOPERATOR: FIEL D / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 192-135 Type Inj N Tubing 0 4150 4116 4104 Type Test P Packer TVD 7794 BBL Pump 4.5 IA 0 850 850 850 Interval I Test psi 4000 BBL Return 4.5 OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 192-135 Type Inj N Tubing Type Test P Packer TVD 7794 BBL Pump 4.0 IA 0 4136 4112 4102 Interval I Test psi 4000 BBL Return 4.0 OA 100 800 800 800 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec hanical Integrity Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov PBU AGI-03 Notes:Initial Rig MIT-IA; witness waived by A. Earl (AOGCC) Notes: Hilcorp North Slope, LLC. Notes: Prudhoe Bay/ PBU/ AGI Pad Clint Montague 05/31/22 Notes:Initial Rig MIT-T; witness waived by A. Earl (AOGCC) Notes: Notes: Notes: PBU AGI-03 Form 10-426 (Revised 01/2017)2022-0531_MIT_PBU_AGI-03_2tests 9 9 9 9 9 9 9 9 9 9 9 9 9 9 -5HJJ CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Gas Injector AGI-03 (PTD #1921350) RWO Complete Date:Wednesday, June 8, 2022 2:05:02 PM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, June 5, 2022 6:55 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Gas Injector AGI-03 (PTD #1921350) RWO Complete All, Gas Injector AGI-03 (PTD #1921350) rig work over is complete. A rig MIT-IA passed to 4102 psi on 06/01/22 which verifies two mechanical well barriers. The well is now classified as OPERABLE and can be put on injection. An online AOGCC witnessed MIT-IA will be performed once the well is thermally stable. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity Sent: Saturday, August 21, 2021 9:46 AM To: Alaska NS - PB - Field Well Integrity <PBWellsIntegrity@hilcorp.com>; chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Gas Injector AGI-03 (PTD #1921350) Production casing / packer leak Mr. Wallace, Gas Injector AGI-03 (PTD #1921350) has a PC leak (6937’ MD) and a leak at the packer (10679’ MD) identified during a leak detect log on 08/18/21. The liquid leak rate on the IA is established at 1.3 GPM at 3600 psi. The well has been secured with a tubing tail plug and passed MIT-T to 3727 psi on 08/10/21. DHD / operations will monitor the IA liquid level daily for any indication of gas in the IA or changes in casing pressure. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, August 4, 2021 5:13 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector AGI-03 (PTD #1921350) failed AOGCC MIT-IA Mr. Wallace, Gas Injector AGI-03 (PTD #1921350) failed its regulatory 4-year AOGCC witnessed MIT-IA today (08/04). The well is now classified as UNDER EVALUATION for up to 28 days. It has been shut-in as the diagnostic plan does not require the well to be online. Plan forward: 1. Slickline: Set TTP, Set DSSSV 2. Fullbore: MIT-T, CMIT-TxIA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT AGI-03 JBR 06/15/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Tested with 4" and 7" test joints, Upper Kelly failed and was chaged out. I did not witness the retest. Closer times, Annular=8sec, UPR,LPR and blinds=8sec, both HCR's=1sec. Total of 20 precharge bottles all @ 1000psi each. Test Results TEST DATA Rig Rep:M. VanhooseOperator:Hilcorp North Slope, LLC Operator Rep:Shane Barber Contractor/Rig No.:Hilcorp Innovation PTD#:1921350 DATE:5/25/2022 Type Operation:WRKOV Annular: 250/4000Type Test:INIT Valves: 250/4000 Rams: 250/4000 Test Pressures:Inspection No:bopBDB220528050703 Inspector Brian Bixby Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 13.5 MASP: 2600 Sundry No: 321-615 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 1 F Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 1 4 1/2x7 P #2 Rams 1 Blinds P #3 Rams 1 2 7/8x5 1/2 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P Kill Line Valves 2 3 1/8 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3050 Pressure After Closure P1500 200 PSI Attained P23 Full Pressure Attained P92 Blind Switch Covers:PYES Nitgn. 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'DWH 3UHSDUHG 2SHUDWLRQV(QJLQHHU 'DWH MEMORANDUM To: Jim Regg P.1. Supervisor l I FR0IN1: Brian Bixby Petroleum Inspector Well Name PRUDHOE BAY UNIT AGI -03 Insp Num: mitBDB210825110740 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 25, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Nonh Slope, LLC AGI -03 PRUDHOE BAY UNIT AGI -03 Sre: Inspector Reviewed By: P.I. Supry t� Comm API Well Number 50-029-22318-00-00 Inspector Name: Brian Bixby Permit Number: 192-135-0 Inspection Date: 8/4/2021 - Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI -03 Inj TypeJ TVD 7885 Tubing 3300 3300- 3300 PTD 1921350 Type SPT Test psi, 1971 jA 1970 2205 1983 BBL Pumped: BBL Returned: p 3 / OA 128 + - - - 128' 128 ' - -- - Interval4YRTSr P/F F - 1 - - Notes: Pressured IA back up to 2205psi and it lost over 10% - in 16 minutes. k4r 5f— Wednesday, August 25, 2021 Page I of I MEMORANDUM TO: Jim Regg 112, IZe Z 1 P.I. Supervisor "1 FROM: Brian Bixby Petroleum Inspector Well Name PRUDHOE BAY UNIT AGI -03 Insp Num: mitBDB210804150905 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 25, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC AGI -03 PRUDHOE BAY UNIT AGI -03 Sre: Inspector Reviewed By: P.I. Supry �.1 V� Comm API Well Number 50-029-22318-00-00 Inspector Name: Brian Bixby Permit Number: 192-135-0 Inspection Date: 8/4/2021 ' Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ---- -_ -._-_ . I -- 1971 IA 396 2205-1970- T - - Well .AGI 03 YP J g 3300 - Type n Tubing i, PTD 1921350 SPT 'Test psi _ 1970- -- ' - T 3 -Type - - P --- --- - � - - -- T e Test BBL Pumped: "BBL Returned OA 63 13s - 1zs Interval 4YRTST Ip/F F Notes: Test failed within first 15 minutes. Pressured IA back up in subsequent test (mitBDB210825110740). Wednesday, August 25, 2021 Page 1 of I From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Gas Injector AGI-03 (PTD #1921350) Production casing / packer leak Date:Wednesday, August 25, 2021 11:20:46 AM Attachments:image001.png From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Saturday, August 21, 2021 9:46 AM To: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Gas Injector AGI-03 (PTD #1921350) Production casing / packer leak Mr. Wallace, Gas Injector AGI-03 (PTD #1921350) has a PC leak (6937’ MD) and a leak at the packer (10679’ MD) identified during a leak detect log on 08/18/21. The liquid leak rate on the IA is established at 1.3 GPM at 3600 psi. The well has been secured with a tubing tail plug and passed MIT-T to 3727 psi on 08/10/21. DHD / operations will monitor the IA liquid level daily for any indication of gas in the IA or changes in casing pressure. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, August 4, 2021 5:13 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Gas Injector AGI-03 (PTD #1921350) failed AOGCC MIT-IA Mr. Wallace, Gas Injector AGI-03 (PTD #1921350) failed its regulatory 4-year AOGCC witnessed MIT-IA today (08/04). The well is now classified as UNDER EVALUATION for up to 28 days. It has been shut-in as the diagnostic plan does not require the well to be online. Plan forward: 1. Slickline: Set TTP, Set DSSSV 2. Fullbore: MIT-T, CMIT-TxIA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Wednesday, August 4, 2021 5:13 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Aras Worthington; Oliver Sternicki; Alaska NS - PB - Field Well Integrity Subject: UNDER EVALUATION: Gas Injector AGI -03 (PTD #1921350) failed AOGCC MIT -IA Mr. Wallace, Gas Injector AGI -03 (PTD #1921350) failed its regulatory 4 -year AOGCC witnessed MIT -IA today (08/04). The well is now classified as UNDER EVALUATION for up to 28 days. It has been shut-in as the diagnostic plan does not require the well to be online. Plan forward: 1. Slickline: Set TTP, Set DSSSV 2. Fullbore: MIT -T, CMIT-TxIA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.oeR(o-)hilcorn.com P: (907) 659-5102 M: (307)399-3816 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS q lP,r / 2n. 0 FIsm 1, Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ ''..88ss Pull Tubing ❑ Operarlg9 , sh ( _ iiSuspentl ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Water Wash 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number: 192-135 3. Address: P.O. Box 196612 Anchorage, AK 9 951 9-661 2 Stratigraphic ❑ Service El 6API Number 50-029-22318-00-00 7 Property Designation (Lease Number): ADL 034628 B. Well Name and Number: PBU AGI -03 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 11540 feet Plugs measured None feet true vertical 8536 feet Junk measured Unknown feet Effective Depth: measured 11496 feet Packer measuredfeet 10678 true vertical 8503 feet Packer true vertical 7885 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20" 36-112 36-112 1490 470 Surface 4025 13-3/6" 35-4060 35-3483 5020 2260 Intermediate 10887 9-5/8" 34-10921 34-8068 6870 4760 Production Liner 784 7" 10754 - 11538 7942-8535 8160 7020 Perforation Depth: Measured depth: 11080 - 11473 feet True vertical depth: 8187-8485 feet Tubing (size, grade, measured and true vertical depth) 7" 26# x 5-1/2" 17#, NT -80 / L-80 33-10759 33-7946 Packers and SSSV (type, measured and 5-1/2" Baker SB -3A Packer 10678 7885 true vertical depth) 7" Camco WDRP-2 SSSV 2234 2189 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: 216750 300 3487 Subsequent to operation: 283429 250 3405 14.Attachments: (required per 20 MC 25.070.25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations p Exploratory ❑ Development ❑ Service M Stratigraphic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ I GSTOR ❑ WINJ ❑ WAG ❑ GINJ m 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: 319536 Authorized Name: Brown, Don L. Contact Name: Brown, Don L. Authorized Title: Petroleum Engineer Contact Email: browd2@BP.com Authorized Signature: l I N . (j-(,Vyj Date. _ /Q- ao Contact Phone: +1 9075644675 Form 10404 Revised 04/2017 6Y,II)IIOZ-p r.4'"t4� IBM6(/ SAN 13 2020 Submit Original Only of Well [�? IT/I/O = 2612/288/45 Temp - SI. LRS Unit 46 (TUBING WASH/PICKLE) Pumped 15 bbls of 60/40, followed by 205 bbls of 90* dsl/xyl down tbg, followed by 323 bbls of FW w/ 0.02% F-103 surfactant. Let dsl/xyl soak across perfs for 3 hours. Pump 200 bbls of FW w/0.02% F-103 surfactant at 1 bpm. Pumped 25 bbls of FW at 3 bpm. Freeze protect surface lines and well with 10 bbls 60/40. Notify 12/19/2019 DSO to POI. SSV, WV, SV (Closed) IA and OA (OTG). FWHP= 784/286/114 FL = 3390 nsi 13-3/8' CSG, 6811, K-55, ID = 12.415' I-1 12Z SAFETY WEU A V' I-0.3 NO CT EMNENTED. ALL TBG IIS IPC WITH NSCC LINER THREAD. 13-3/8" CSG, 68#, NT=80, D =12.415' 4060' . Minimum ID = 4.455" @ 10747' 5-1/2" OTIS XN NIPPLE NSCC, 1-1 10675' bpf, D = 6276' TOP OF 7" LNR H 10754' FeTD —t 11496' f 7' LNR, 29#, NT -00S, .0371 bpf, D = 6.184' 11rJ'.36' V VAIVI V 6AL-0 955V NIP, ID = 5.937' '1 10676' 1-17^ X 5-1/2' XO. D = 4.B75^ 10678' ANCHOR 10679' 9-5/8" X 5-12" BAKER SB -3A RCR 10726' 5-12' PARKER SWS NP, D = 4.562" 10747' 5-12" OTIS XN NIP, D = 4.455' 10769' S-t2^wLEG 10766' FIND TT LOGG®0520/93 DATE 5-1/2' TBG, 17#, L-80 -IPC, NSCC, — 10759' I REV BY .0232 bpf, D = 4.892' 01102193 ORIGINAL COMPLETION 9S/8• CSG, 47#, NT -8 D = 8.881• 10921' WBS CLEANUP PERTALLIES PRORATION SUMMARY StS-LG REVISION 11/19/19 DD/JMD REF LOG: SM GR OCL ON 0520/93 0522101 RWKAK CORRECTIONS ANGLEAT TOP PERF: 42@1108U Note- Refer to Production DB for historical perf data SIZE SPF MERVAL Opn/Sgz DATE '�3/8' 6 11080 - 11100 O 521/93 318" 6 11200 - 11220 O 521/93 ',3/8" 6 11314 - 11334 O 521/93 -3/8" 6 11370-11380 O 521/93 13/8" 6 11403 - 11413 O 521/93 -318" 6 11453 - 11473 O 521193 FeTD —t 11496' f 7' LNR, 29#, NT -00S, .0371 bpf, D = 6.184' 11rJ'.36' V VAIVI V 6AL-0 955V NIP, ID = 5.937' '1 10676' 1-17^ X 5-1/2' XO. D = 4.B75^ 10678' ANCHOR 10679' 9-5/8" X 5-12" BAKER SB -3A RCR 10726' 5-12' PARKER SWS NP, D = 4.562" 10747' 5-12" OTIS XN NIP, D = 4.455' 10769' S-t2^wLEG 10766' FIND TT LOGG®0520/93 DATE REV BY COMMENTS DATE REV BY COMMENTS 01102193 ORIGINAL COMPLETION 07/19/16 JMD WBS CLEANUP PERTALLIES 0126101 StS-LG REVISION 11/19/19 DD/JMD ADDED BF ELEV 0522101 RWKAK CORRECTIONS 03/13403 AS/TP ADD PC/THREAD FOR TBG 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE 09/09/15 TJH/JMD FISH:LOSTEARDH FISH i EAR FROM 2-112" QUICK CONNECT (0.5" X 0.75" X 0.1875") (05123115) PRUDHOE BAY UNIT WELL: AGI -03 PERMIT No: 1921350 API ND: 50-029-2231 B-00 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Don Brown Petroleum Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU AGI -03 Permit to Drill Number: 192-135 Sundry Number: 319-536 Dear Mr. Brown: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.a1asko.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, Jere rice Chair DATED this day of November, 2019. ABDO ±�-7j NOV 2 7 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 NOV 21 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ o )lrYo'6rrp Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Water Wash 0 ' 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number 192-135 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service R1 6. API Number: 50-029-22318-00-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU AGI -03 9. Property Designation (Lease Number): 10. Field/Pools: ADL 034628 464. 67yV30 PRUDHOE BAY. PRUDHOE OIL 11. /l-ZZ.ry PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ff): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11540 8536 11496 8503 None Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 76 20" 36-112 36-112 1490 470 Surface 4025 13-3/8" 35-4060 35-3483 5020 2260 Intermediate 10887 9-5/8" 34-10921 34-8068 6870 4760 Production Liner 784 7" 10754 - 11538 7942-8535 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grace: Tubing MD (ft): 11080- 11473 8187-8485 7" 26# x 5-1/2" 17# NT -80 / L-80 33-10759 Packers and SSSV Type: 5-1/2" Baker SB -3A Packer Packers and SSSV MD (ft) and TVD (ft): 10678/7885 7" Cameo WDRP-2 SSSV 2234/2189 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program Cl BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 , 14. Estimated Date for Commencing Operations: 12/6/2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Brown, Don L. be deviated from without prior written approval. Contact Email: browd20BP.COm Authorized Name: Brown, Don L. Contact Phone: +1 9075644675 Authorized Title: Petroleum Engineer Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 'BDMS e---" N0V 2 7 2019 Post Initial Injection MIT Req'tl? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 11/ Subsequent Form Required: k -40y APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: W Form 10-403 Revised 04/2017 0 R -I G I N A LQztq Approved application is valid for 12 months from the date of approval. u mlt Form and Attachments in Duplicate 10-403 Sundry Application for Well PBU AGI -03 PTD #192-13S Expected Start Date: December 6, 2019 Current condition of well: Gas Injection Well, Operable, Online: Gas Injection Rate: 234039 Mscf/Da Injection Pressure: 3518 psi Reservoir Pressure (Estimate): 3427 psi Program Objective(s): AGI -03 has had several successful water washes historically, the most recent being on 5/13/13. These water washes have been successful and injectivity in this well has decreased since the 2016. If this water wash goes to plan, injectivity should improve as the process is designed to dissolve salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used successfully in the past on the NGI/WGI/AGI gas injectors to improve injectivity. This well is also an emergency gas source well.. Proposed Program: 1. Pump diesel/xylene water wash as per attached pumping template. BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU AGI -03 PTD #192-135 Pump Schedule: well AGW3 Work Desc Gas Injector Water Wash AFE 0 Date 11F20/19 Engineer Don Brown Phone 9077564-4675 112S ValueT 28A 112S Date r flr.A Increase well injectivity by performing a water wash. Use 2 full uprights of fresh water mixed with 0.02% F-103 surfactant. Use 200 bbis of diesel/xylene. Pump Schedule Stage Po Into Vol bbis Rate(b m Max Pres i 1ter TBG 15 1-3 3000 2 TBG 200 Max 3000 3 TBG 600 See Below 3000 4 er TBG 10 1-3 3060 5 5 7 1.) 15 bb160/40 McOH/vrater spear 2.) 200 bbis 50/50 diesel/xylene heated to 90 degrees F or as hot as LRS can heat it. 3.) Pump 600 bbis of fresh water with 0.02% F-103 surfactant per following: a.) Pump 323 bbis of fresh water with 0.02% F-103 surfactant at 1-3 bpm, shut -down pumps and let diesel/xylene soak across perfs for 4 hours - this should allow _ 100 bbis of D/x to be pumped into perfs and a remaining 100 bbis to soak. b.) Resume pumping at 0.5 bpm for next 200 bbis of fresh water with 0.02% F-103 surfactant. c.) Once 523 bbis of fresh water with 0.02% F-103 surfactant has been pumped resume pumping at 1-3 bpm for remainder of overflush (-77 bbls). 4.) 10 bbis of 60/40 McOH/vrater freeze protect Directions When filling out the pumping template, please note the following: MIT #2 Test Type Target Pressure Max Applied Pressure Test Fluid Integrity Lprvts Confirmed ❑ MIT #3 Test Type Target Pressure Max Applied Pressure Test Fluid kite-Inteordy Lams Confirmed ❑ 'MIT" is selected as a stage, the corresponding MIT section must be filled out. The boxes are defined as follows. Test Type: Type of test to be performed (MIT -T, MIT -IA, MIT.OA, etc) Target Pressure: This is the requested Mit test pressure (ie MIT -T to 2500 psi) Max Applied Pressure: This is the max pressure that can be applied in order to achieve a passing MIT of the target test pressure, typically 10% greater than target pressure. BP practice 100218 (10-45) requires that the test pressure must remain above or equal to the target pressure during the entire test evaluation period. This pressure must not exceed the lowest rated working pressure (taking into account corrosion. erosion, etc) of any well barrier element in the well barrier envelope. Test Fluid: The fluid to be used for the test. Integrity limits Confirmed: By checking this box. you have confirmed that the "Max Applied Pressure" requested is within the limas of the wells 'Well Barrier Envelope". BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU AGI -03 PTD #192-135 Wellbore Schematic: TREE. w••w. WELLHEAD= 01ACTR 3-318' 811080-11100 O BAKER /� ct SAFETY NOTES: WELL REQUIRES A SSSV. LINER 'OK9.ELEV- OKS, ELEV 4646' AGI -03 Va I NOT CEMENTED. ALL TOG 6IPCWRIT NSCC� B0.ELEV= 18.14' O 7TigFgD, KOP= W. A,& 1564- 53• Q 860Y 6 11370.11380 71 IDatuP MO: 11885' I if 6 11403 - 11413 1. Dayan TYO= _ 88!!0'3.4 3-38" Minimum ID = 4.455" @ 10747' 5.112" OTIS XN NIPPLE 7• 10232 bP1, D • 4.892' I 9516' CSO, 47N, Nr80.5, D. 8.�/' 1092T . FHd'-0fN110N S1.6wNRY REFLOG. SAB GRCCL OPI052093 ANGLEATTOP FE+F: 42 11067 a. fmfer b PaducOun 08 for Nstori Dorf aem T• LHR. 2W. NT4g8..0371;j D.6.te4• 10708' t3NOTT LOGOF00520193 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 x 0.75• PRUDHOE BAY UNT WELL: AGW3 PERM? No: 1921350 APIM: 50-029-22318-M w••w. � 3-318' 811080-11100 O 52/!83 3-38' 6 11200.11220 O 521193 3-38• 6 11314-1133! O 521!83 3-38• 6 11370.11380 O 521193 3-38• 6 11403 - 11413 O 1 52 VBG 1 3-38" 6 11453 - 11473 O 821!93 T• LHR. 2W. NT4g8..0371;j D.6.te4• 10708' t3NOTT LOGOF00520193 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 x 0.75• PRUDHOE BAY UNT WELL: AGW3 PERM? No: 1921350 APIM: 50-029-22318-M • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,August 09,2017 P.I.Supervisor e?' �(I°( 7 SUBJECT: Mechanical Integrity Tests / 6 BP EXPLORATION(ALASKA)INC. AGI-03 FROM: Guy Cook PRUDHOE BAY UNIT AGI-03 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry S 72-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT AGI-03 API Well Number 50-029-22318-00-00 Inspector Name: Guy Cook Permit Number: 192-135-0 Inspection Date: 8/5/2017 Insp Num: mitGDC170805183634 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well AGI-03 - Type Inj G 'TVD 7885 • Tubing 3380 3341 • 3287 - 3269 - PTD 1921350 Type Test SPT Test psi _ 1971 , IA 282 2492 - 2494 - 2490 - BBL Pumped: 6.1 • BBL Returned: 4.9 • OA 50 84 90 94 Interval 4YRTST P/F P ✓ Notes: MIT-IA. A fluid level shot was taken prior to testing to show the fluid at 90'. Little Red Services heated the diesel to 100 degrees Fahrenheit ✓ before pumping to help with issue of thermal expansion during testing. • SCANNED TF 2 . 2r Wednesday,August 09,2017 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /"'/5 Number of Well History File File PAGES TO DELETE Complete RESCAN [] [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] OVERSIZED [] Diskettes, No, Other, No/Type Logs of various kinds Other COMMENTS: Scanned by: Bevedy Diann than Lowell TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /si UNSCANNED, OVERSIZED MATERIALS AVAILABLE: l~i~ ~~~ FILE # ~~,` ~~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 ~ Anchorage, Alaska 99501 Voice (907) 279-1433 y Fax (907) 276-7542 • • Wallace, Chris D (DOA) From: Wallace, Chris D(DOA) Sent: Wednesday, September 25, 2013 1:45 PM To: 'AK, D&C Well Integrity Coordinator' Subject: RE: Injector AGI-03(PTD#1921350) Inconclusive MIT-IA on 08/08/13 Jack, Troubling that there is a miscommunication of this magnitude at this level. Please provide a TIO (plot plus raw data excel)and any other relevant data that can support an integrity determination for this well and we will review it when revisiting the inconclusive MIT. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer r r' tt " A' Alaska Oil and Gas Conservation Commission ,.�AOi1� I � 333 West 7th Avenue �r�+ Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace @alaska.gov From: AK, D&C Well Integrity Coordinator [mailto:AKDCWellIntegrityCoordinator @bp.com] Sent: Tuesday, September 24, 2013 6:17 PM To: Wallace, Chris D (DOA) Subject: Injector AGI-03(PTD #1921350) Inconclusive MIT-IA on 08/08/13 Chris, I just came across this email from Phoebe correcting our MITIA form for Injector AGI-03 from 08/08/13. I highlighted the well I am concerned about in her email, and deleted the unrelated attachments. There were two test performed, both MIT-IAs,the first test was determined to be inconclusive by our Wellsite Leader and the State Inspector, however,the second test was reported as a pass from our Wellsite Leader and according to Phoebe it was determined to be Inconclusive by the State Inspector. We have been operating the well assuming we had a passing test. Has there been a ruling on the inconclusive test? Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator GWGlobal Wefts Or aniza is Office: 907.659.5102 WIC Email:AKDCWelllntegrityCoordinator @bp.com From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooks @alaska.gov] Sent: Monday, September 09, 2013 12:14 PM To: AK, D&C Well Integrity Coordinator 1 • Cc: Regg,James B (DOA) Subject: RE: August 2013 AOGCC MIT Forms Jack/Laurie, Attached are revised reports as follows: • AGI-03—Revised report to match the inspector's; both test results were determined to be inconclusive • PBU 01-04A—Test date was changed to 08/30/13 per the inspector's report • ACT MPB-27—Test date was changed to 8/17/13 per the inspector's report(and the file naming convention) • PBU LPC-02—Packer TVD was changed to reflect 5314' • ACT END 5-02 SD-10—Revised report to match the inspector's;the type of injection was changed to"N"and the test psi was changed to 2600 Please update your copies or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone:907-793-1242 Fax:907-276-7542 From: AK, D&C Well Integrity Coordinator(mailto:AKDCWelllntegrityCoordinator @)bb.com] Sent: Sunday, September 01, 2013 2:53 PM To: Regg, James B(DOA); Wallace, Chris D (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay Cc: AK, D&C Well Integrity Coordinator Subject: August 2013 AOGCC MIT Forms All, Please find the attached MIT forms for August 2013. Enclosed in.zip file 01-04A(PTD#2011520) 03-37(PTD#2091390) 04-20(PTD#1831190) 13-35(PTD#1940410) AGI-01A(PTD#2091640) AGI-02(PTD#1921200) AGI-03(PTD#1921350) AGI-04(PTD#1921460) AGI-06(PTD#1930090) AGI-08(PTD#1930330) AGI-09(PTD#1930350) END1-43/P-26(PTD#1881050) ENDS-02/SD-10(PTD#1811180) LPC-02(PTD#1930250) MPB-27 (PTD#2042210) MPH-06(PTD#1951150) 2 STATE OF ALASKA - • ! L. ;, ;• ::, k+ 1 AOKA OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS 0C - -; ,:( 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U • Other 1/1 Water Wash Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc • Development Exploratory ❑ 192 -135 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ . Service 51 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22318 -00 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0034628 PBU AGI -03 • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL. 11. Present Well Condition Summary: Total Depth measured 11540 feet ' Plugs measured None feet true vertical 8536.23 feet Junk measured None feet Effective Depth measured 11496 feet Packer measured 10678 feet true vertical 8502.71 feet true vertical 7884.4 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 76 20" 91.5# H -40 36 - 112 36 - 112 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 10887 9 -5/8" 47# NT8OS 34 - 10921 34 - 8067.87 6870 4760 Liner 784 7" 29# NT8OS 10754 - 11538 7942.05 - 8534.71 8160 7020 Perforation depth Measured depth 11080 - 11100 feet 11200 - 11220 feet 11314 - 11334 feet 11370 - 11380 feet 11403 - 11413 feet 11453 - 11473 feet True Vertical depth 8186.83 - 8201.9 feet 8277.41 - 8292.58 feet 8364.12 - 8379.38 feet 8406.78 - 8414.37 feet 8431.84 - 8439.44 feet 8469.96 - 8485.19 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 5 -1/2" Baker SB -3A Packer 10678 7884.4 Packer 7" Camco WDRP -2 SSSV 2234 2188.59 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED JUL 0 ij 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: 'Copies of Logs and Surveys Run Exploratorj❑ Development ❑ • Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas U WDSPIU GSTOR ❑ WINJ ❑ WAG ❑ . GINJ 0 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: 313 -209 Contact Nita Summerhays Email Nita.Summerhays a(�.BP.com Printed Name Nita Summerha s A Title Petrotechnical Data Technician iii , ignatu ., �� / I ■ Phone 564 4035 Date 6/11/2013 r 1�i�� RBDMS JUN 12 201 1,i/0W-77 ,i00z /J Form 10-404 Revised 10/2012 Submit Original Bnily • • Daily Report of Well Operations ADL0034628 Road to loc Wait for DSL no DSL available move to next job (inside skin of top 5/12/2013 wellhouse door falliing into wellhouse operator notifieed of danger) T /1 /0= 2500/870/151. Temp= INJ Tubing Displacement Tubing wash /pickle. Pumped 10 bbl meth spear down tbg, followed by 208 bbls 50/50 blend of diesel /xylene. Pumped 710 bbls freshwater with .02% F -103 surfactant down tbg to flush. Freeze protect with 10 bbls meth. FWHP = 0/957/407. SwV, WV= closed. 5/13/2013 SSV, MV =Open. IA/OA= OTG. FLUIDS PUMPED BBLS 208 50/50 DIESEL /XYLENE 8 DIESEL 20 METH 710 .02% F -103 SURFACTANT INHIBITED FRESHWATER 946 TOTAL Casing / Tubing Attachment ADL0034628 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" 91.5# H -40 36 - 112 36 - 112 1490 470 LINER 784 7" 29# NT8OS 10754 - 11538 7942.05 - 8534.71 8160 7020 PRODUCTION 10887 9 -5/8" 47# NT80S 34 - 10921 34 - 8067.87 6870 4760 SURFACE 87 13 -3/8" 68# K -55 35 - 122 35 - 122 3450 1950 SURFACE 3938 13 -3/8" 68# NT -80 122 - 4060 122 - 3482.94 5020 2260 TUBING 10642 7" 26# NT -80 33 - 10675 33 - 7882.13 7240 5410 TUBING 84 5 -1/2" 17# L -80 10675 - 10759 7882.13 - 7945.83 7740 6280 • III TREE = • S NOTES: WELL REQUIRES A SSSV. LINER WETATA= CMJ ACTUUATOR R BAKER AGI-03 NOT CEMENTED. ALL TBG IS IPC WITH NSCC THREAD. KB. ELEV = 49' BF. ELEV = KOP = 1554' Max Angle = 53 @ 9602' Datum MD = 11965' Datum TVD= 8800'SS 13 -3/8" CSG, 68 #, K -55, ID = 12.415" —I 122' 1- 2234' H 7" CAMCO BAL -O SSSV NIP, ID = 5.937" 13 -3/8" CSG, 68 #, NT -80, ID = 12.415" H 4060' IA Minimum ID = 4.455" @ 10747' 5 -1/2" OTIS XN NIPPLE 7" TBG, 26 #, NT -80 -S -IPC, NSCC, .0383 bpf, ID = 6.276" I 10675' 10675' — 17" X 5-1/2" XO I TOP OF 5-1/2" TBG 10675' 10678' -I ANCHOR I I 10679' H9-5/8" X 5 -1/2" BAKER SB -3A PKR I 10726' H 5 -1/2" PARKER SWS NIP, ID = 4.562" I 1 0747' — I5 -1/2" OTIS XN NIP, ID = 4.455" I I TOP OF 7" LNR H 10754' I . ■ 15 -1/2" TBG, 17 #, L -80 -IPC, NSCC, .0232 bpf, ID = 4.892" I-1 10759' I / 10759' -J 5-1/2" WLEG I I 10766' H ELMD TT LOGGED 05/20/93 I 9 -5/8" CSG, 47 #, NT -80 -S, ID = 8.681" — I 10921' I PERFORATION SUMMARY REF LOG: SWS GR CCL ON 05/20/93 ANGLE AT TOP PERF: 42 @ 11080' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 11080 - 11100 O 5/21/93 3-3/8" 6 11200 - 11220 0 5/21 /93 3-3/8" 6 11314 - 11334 0 5/21/93 3-3/8" 6 11370 - 11380 O 5/21/93 3-3/8" 6 11403 - 11413 0 5/21/93 3-3/8" 6 11453 - 11473 0 5/21/93 I PBTD I� 11496' I 7" LNR, 29#, NT -80-S, .0371 bpf, ID = 6.184" —I 11538' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/02/93 ORIGINAL COMPLETION WELL: AGI-03 01/26/01 SIS -LG REVISION PERMIT No: '1921350 05/22/01 RN/KAK CORRECTIONS AR No: 50- 029 - 22318 -00 03/13/03 AS/TP ADD IPC /THREAD FOR TBG SEC 36, T12N, R14E, 245.23' FEL & 3766.26' FNL 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE • w s THE STATE Alaska Gil and Gas OF TFj �� LAJKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 SCANNED MAY 0 3 2013 Javier Farinez Petroleum Engineer -t 3 BP Exploration (Alaska), Inc. II 6612 Box 1 P.O. 9 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AG1 -03 Sundry Number: 313 -209 Dear Mr. Farinez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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 - day of May, 2013. Encl. , • RECEIVED " ' • STATE OF ALASKA APR 3 0 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations0 Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. • Water Wash ig 2. Operator Name: l/' 4. Current Well Class: 5. Permit to Drill Number. y BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 192 -135-0 3. Address: 6. API Number. Stratigraphic ❑ Service Q P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 22318 -00 -00 ' 7. If perforating: 8. Well Name and Number. ✓ What Regulation or Conservation Order governs well spacing in this pool? 341 D PBU AGI -03 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): ?I'33 10. Field /Pool(s): f ADL0034628 • .Z of 6'10 PRUDHOE BAY, PRUDHOE OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft):' Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): '11540 '8536 11496 8503 None None Casing Length Size MD ND Burst Collapse Structural Conductor 76 20" 91.5# H -40 36 - 112 36 -112 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 10887 9 -5/8" 47# NT8OS 34 - 10921 34 - 8068 6870 4760 Liner 784 7" 29# NT8OS 10754 - 11538 7942.05 - 8535 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 5 -1/2" Baker SB -3A Packer Packers and SSSV MD (ft) and TVD (ft): • 10678, 7884.4 7" Camco WDRP -2 SSSV • 2234', 2188.59' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: / Detailed Operations Program 0 • BOP Sketch ❑ Exploratory ❑ Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: / 5/7/13 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: 4./ 3o/, 3 WINJ ❑ GINJ WAG ❑ Abandoned ❑ Commission Representative: j// e t I-7 `a. if r , c v 1 5 el GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and corraLt to the best of my knowledge. Contact Javier Farinez Email Javier.Farinez)BP.corrt Printed Name J ' arin- Title PE Signature /�' Phone Date 564 -5043 4/30/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 51 3 f 2/CP1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No i Subsequent Form Required: 1° —1f liBDMS MAY - 2 2Q13 APPROVED BY ` / Approved by: COMMISSIONER THE COMMISSION Date: Form -403 Revised 1/4010i ArOf tip cO_tittgaAfa r 12 months �r �� he date of approval. S in Duplicate .190 Version/ .1 04/28/2010 Fulibore Pumping Design Template Well Name AGI -03 Job Scope Select Job Scope H2S (ppm /date) WBL Cat IOR . 2500 Max Pumping Pressure (psi) Well Type GI AFE APBinjec Main Fluid Type Date 4/29/2013 IOR 30 700 Main Fluid Volume (bbls) Engineer Javier Farinez Phone 564 -5043 Methanol (60/40) Freeze Protect Type Job Objective 10 Freeze Protect Volume (bbls) If Applicable Recent Tbg Fluid Level (ft) Improve injectivity by dissolving salts and possibly asphaltenes in the • If Applicable Recent IA Fluid Level (ft) tubing and formation. Diesel / Xylene washes have been used If Applicable Recent OA Fluid Level (ft) successfully in the past on the NGI/WGI /AGI gas injectors to improve If Applicable Expected Tbg Fill Up Volume (bbls) injectivity. If Applicable Expected IA Fill Up Volume (bbls) If Applicable Expected OA Fill Up Volume (bbls) 418 Wellbore Volume to Perfs (bbls) Fulibore Pumping Schedule 3300 Anticipated Bottom Hole Pressure (psi) Pump Volume Rate Max Select Tubing /Casing within Pressure Limits? Stage Fluid Type Into (bbls) (bpm) Pressure Size Burst/Collapse 80% Burst/Collapse Tubing Burst (psi) 7 8860.00 7088 I Pre -Flush I Methanol (60/40) I Tbg 101 1 1 1 25001 Tubing Collapse (psi) size See helpful tips tab Casing Burst (psi) size See helpful tips tab 1 Solvent 1 1 Select Fluid Type 11 Tbg 200 I 11 15001 Casing Collapse (psi) size See helpful tips tab 1 Load 11 Select Fluid Type 1 Tbg 7001 I 1 1 1200 Select Input Depth • Integrity Issues? No unknown 1 Freeze Protect 1 I Methanol (60/40) 1 Tbg 1 10 1 1 1 12001 No Input Depth 1 Select Stage 1 1 Select Fluid Type 11 Select 1 1 1 1 1 1 1 I No 1 Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition 1 Select 1 Production Packer within Pressure Limits? Detailed Pumping Procedure Rated Packer dp . ,. Max Anticipated dp at Packer 1 10 bbls 60/40 meoh spear 2 200 bbls 50/50 diesel /xylene I Not Necessary I Hold Pressure on Other Strings? 3 700 bbls of fresh water with 0.02% F -103 surfactant Tubing (psi) 4 10 bbls 60/40 meoh IA (psi) 5 RDMO. Return well to gas injection OA (psi) 6 • • Fullbore Pumping Program for Field Name - 3 Well Na e AGI-03 Job Scope Select Job Scope Well Type GI AFE APBinjec Date 4/29/2013 IOR 30 Engineer Javier Farinez Phone 564 -5043 H2S • bjective Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel /Xylene washes have been used successfully in the past on the NGI/WGI /AGI gas injectors to improve injectivity. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate (bpm) Max Pressure 1 Pre -Flush Methanol (60/40) I Tbg 10 I 2500 2 Solvent I Select Fluid Type Tbg 200 1500 3 I Load I Select Fluid Type Tbg 700 1 1200 4 Freeze Protect I Methanol (60/40) Tbg 10 1 1200 5 Select Stage I Select Fluid Type Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear 2 200 bbls 50/50 diesel /xylene 3 700 bbls of fresh water with 0.02% F -103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Additional Details If Applicable Recent Tbg Fluid Level (ft) Integrity Issues? No unknown If Applicable Recent IA Fluid Level (ft) No Input Depth If Applicable Recent OA Fluid Level (ft) • • Freeze Protection - see PE manual for additional information Freeze Protect to 2500' TVD in GPB. Use 60/40 Meth Water for Injectors Use 5 bbl 60/40 Meth Water spear followed by dead crude for Producers Pipe Data (L -80) j _ dimensions mechanical inner capacity outer capacity size Iblft od id drift id _ collapse burst bbls /ftft/bbls bbis /ft ft/bbis 2.375 4.60 2.38 2.00 1.90 11780 : - . C. _ 2.--. .. 00548 182.5 2.875 6.50 2.88 2.44 2.35 11160.00 10570.00 0.00579 172.8 0.00803 124.5 3.188 6 40 3.19 2.81 2.68 1 1 1 1 1 00 11 11 1 00 0.00769 130.1 0.00987 101.3 3.500 9.30 3.50 _ 2.99 2.87 10530.00 10160.00 0.00870 115.0 0.01190 84.0 4 500 12 60 4 50 3.96 3.83 7500.00 8430.00 0.01522 65.7 0.01967 50.8 5.000 18.00 5.00 4.28 4.15 10490.00 9910.00 0.01776 56.3 0.02429 41.2 5.500 17.00 5.50 4.89 4.77 6280 00 7740 00 0.02325 43.0 0.02939 34.0 7.000 26.00 7.00 6.28 6.15 5410.00 7240.00 0.03826 26.1 0.04760 21.0 7 000 29.00 7.00 6.18 6.06 7020.00 8160.00 0.03715 26.9 0 04760 21.0 7.625 29.70 7.63 6.88 6.75 4790.00 6890.00 0.04592 21.8 0.05648 17.7 9.625 47 00 9 63 8.68 8.53 4760 00 6870.00 0.07321 13.7 0.08999 11.1 13.375 72.00 13.38 12.35 12.19 2670.00 _ 5380.00 _ 0.14809 6.8 0.17378 5.8 custom 6.000 4.000 0.01561 64.1 0.03497 28.6 Bursts OD GRADE WT Burst 3 1/2" 80 9.3# 10160 41/2" 80 12.6# 7500 5 1/2" 80 15.5# 7000 80 17# 7740 7" 80 26# 7240 80 29# 8160 95 29# 9690 110 29# 11220 7 5/8" 80 29.7# 6890 80 33.7# 7900 95 29.7# 8180 9 5/8" 55 36# 3520 55 40# 3950 80 40# 5750 80 43.5# 6330 80 47# 6870 80 53.5# 7930 95 47# 8150 10 3/4" 55 45.5# 3580 80 45.5# 5190 80 55.5# 6450 11 3/4" 95 60# 6920 13 3/8" 55 54.5# 2730 55 61# 3090 55 68# 3450 80 68# 5020 80 72# 5380 95 72# 6390 16" 80 84# 4330 18 5/8" 55 96.5# 2510 55 109.3# 2910 20" 40 94# 1530 55 133# 3060 Brine Design Notes Revised: 5/1/00 NaCI KCI CaCI NaBr Design Notes: 8.5 29 8.4 31 8.5 30 8.5 30 8.6 27 8.5 30 9.0 22 9.0 25 Design for -50 degrees from surface to 100', 10 degrees through permafrost (approx. 2500'). 8.7 26 8.7 27 9.5 10 9.5 20 Be careful using McOH /H2H for freeze cap - McOH may mix with brine and dilute 8.8 24 8.9 23 10.0 -9 10.0 14 Don't use Ca based fluids that may come in contact with the formation. 8.9 22 9.1 19 10.5 -36 10.5 6 Be careful using CaCI in IA - may dump on formation 9.0 19 9.3 15 10.7 -51 11.0 -2 Corrosion Inhibitor: mix 25 gal of NEEC EC1124 per 100 bbls brine 9.1 17 9.5 15 10.8 -57 11.5 -11 Note: Inhibitor has a 1 day half -life 9.2 14 9.6 33 10.9 -35 11.7 -16 Be careful allowing very cold diesel to contact KCI - could form a slush 9.3 11 11.0 -19 11.8 -19 • 9.4 9 11.5 36 11.9 -10 9.5 6 12.0 6 9.6 3 12.5 50 9.7 -1 12.7 63 9.8 -5 9.9 5 10.0 25 Crystallization Temperatures for Clear Brines 4 KCI / CaCI NaCI / 20 / o j Naar /. .. • ■ -20 ., .. -♦ - NaCI -40 _ .. -- - -- -- - -- -IP-. CaCI ` --s -KCI -60 -s NaBr- 8.5 9.5 Density, PPO .p.5 155 4.5 Perforation Attachment ADL0034628 Well Date Perf Code MD Top MD Base TVD Top TVD Base AGI -03 5/21/93 PER 11080 11100 8187 8202 AGI -03 5/21/93 PER 11200 11220 8277 8293 AGI -03 5/21/93 PER 11314 11334 8364 8379 AGI -03 5/21/93 PER 11370 11380 8407 8414 AGI -03 5/21/93 PER 11403 11413 8432 8439 AGI -03 5/21/93 PER 11453 11473 8470 8485 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • ! Casing Summary ADL0034628 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 76 20" 91.5# H -40 36 112 36 112 1490 470 H -40 LINER 784 7" 29# NT8OS ' 10754 11538 7942 8535 8160 7020 NT8OS PRODUCTION 10887 9 -5/8" 47# NT8OS 34 10921 34 8068 6870 4760 NT8OS SURFACE 3938 13 -3/8" 68# NT -80 122 4060 122 3483 5020 2260 NT -80 SURFACE 87 13 -3/8" 68# K -55 35 122 35 122 3450 1950 K -55 TUBING 84 5 -1/2" 17# L -80 10675 10759 7882 7946 7740 6280 L -80 TUBING 10642 7" 26# NT -80 33 10675 33 7882 7240 5410 NT -80 • Packers and SSV's Attachment ADL0034628 Well Facility Type MD Top Description TVD Top AGI -03 SSSV 2234 7" Camco WDRP -2 SSSV 2189 AGI -03 PACKER 10678 5 -1/2" Baker SB -3A Packer 7884 TREE= • • S NOTES: WELL REQUIRES A SSSV. LINER * _WELLHEAD= CNV N CEMENTED. ALL TBG IS IPC WITH NSCC ACTUATOR= BAKER AG i_o 3 THREAD. KB. ELEV = 49 BF. ELEV = KOP = 1554' Max Angle = 53 @ 9602' Datum MD = 11965' Datum TVD= 8800'SS 13 -3/8" CSG, 68#, K -55, ID = 12.415" I 122' I 2234' I -17" CAMCO BAL -O SSSV NIP, ID = 5.937" 113 -3/8" CSG, 68 #, NT -80, ID = 12.415" I 4060' I-- Minimum ID = 4.455" @ 10747' 5 -1/2" OTIS XN NIPPLE 7" TBG, 26 #, NT -80 -S -IPC, NSCC, .0383 bpf, ID = 6.276" H 10675' / 10675' - 7" X 5-1/2" XO I TOP OF 5-1/2" TBG I 10675' 10678' - I ANCHOR I I 10679' H 95/8"x5-1/2" BAKER SB -3A PKR I II I I 10726' 1-15-1/2" PARKER SWS NIP, ID = 4.562" I I I '115 5-1/2" OTIS XN NIP, ID = 4.455" I I TOP OF 7" LNR H 10754' I . ■ 15 -1/2" TBG, 17 #, L -80 -IPC, NSCC, .0232 bpf, ID = 4.892" I-) 10759' I l 10759' IH 5-1/2" WLEG I 10766' H ELMD TT LOGGED 05/20/93 I 9 -5/8" CSG, 47 #, NT -80 -S, ID = 8.681" -I 10921' I PERFORATION SUMMARY REF LOG: SWS GR CCL ON 05/20/93 ANGLE AT TOP PERF: 42 @ 11080' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 11080 - 11100 0 5/21/93 3-3/8" 6 11200 - 11220 0 5/21/93 3-3/8" 6 11314 - 11334 0 5/21/93 3 -3/8" 6 11370 - 11380 0 5/21/93 3-3/8" 6 11403 - 11413 0 5/21/93 3-3/8" 6 11453 - 11473 0 5/21/93 I PBTD 1 11496' I I 7" LNR, 29#, NT -80-S, .0371 bpf, ID = 6.184" —I 11538' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/02/93 ORIGINAL COMPLETION WELL: AGI-03 01/26/01 SIS -LG REVISION PERMIT No: 1921350 05/22/01 RN/KAK CORRECTIONS API No: 50- 029 - 22318 -00 03/13/03 AS/TP ADD IPC /THREAD FOR TBG SEC 36, T12N, R14E, 245.23' FEL & 3766.26' FNL 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE • • Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Tuesday, April 30, 2013 2:43 PM To: 'Farinez, Javier' Subject: RE: AGI -03 Water Wash Sundry Javier, You have approval to proceed with the procedure as outlined. Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson a,alaska.gov From: Farinez, Javier mailto:Javier.Farinez b .com [ @ P ] Sent: Tuesday, April 30, 2013 9:20 AM To: Ferguson, Victoria L (DOA) Subject: AGI -03 Water Wash Sundry Victoria, Find attached the 10 -403 form for the AGI -03 (permit to drill number: 192 -135). We are not able to get injectivity in the well AGI -03. The plan forward is: 1. Mobilize Fulbore and try to establish injectivity with fluids 2. If injectivity is established. Proceed with a Water Wash 3. If no injectivity, mobilize SL unit to drift and tag and check SSSV We are planning to mobilize the equipment this morning and pump tonight. I was wondering if we could get a pre - approval so we could do this job under compliance Thanks Javier Farinez Lead P.E. GPB Gravity Drainage East Resource- Base Management 1 trscumiwtul STATE OF ALASKA ALIA OIL AND GAS CONSERVATION COMMI•N SEP 0 6 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon [J Repair Well 11 Plug Perforations U Perforate U Other U Water Wash Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Wel{J 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 192 -135 -0 3. Address: P.O. Box 196612 Stratigraphir❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 -, 50- 029 - 22318 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0034628 PBU " AGI -03 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 4 To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11540 feet Plugs measured None feet true vertical 8536.23 feet Junk measured None feet Effective Depth measured 11496 feet Packer measured 10678 feet true vertical 8502.71 feet true vertical 7884.4 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 76 20" 91.5# H-40 36 - 112 36 - 112 1490 470 Surface 3938 13 -3/8" 68# NT -80 122 - 4060 122 - 3482.94 5020 2260 Intermediate None None None None None None Production 10887 9 -5/8" 47# NT8OS 34 - 10921 34 - 8067.87 6870 4760 Liner 784 7" 29# NT8OS 10754 - 11538 7942.05 - 8534.71 8160 7020 Perforation depth Measured depth 11080 -11100 feet 11200 - 11220 feet 11314 - 11334 feet 11370 - 11380 feet 11403 - 11413 feet 11453 - 11473 feet True Vertical depth 8186.83 - 8201.9 feet 8277.41 - 8292.58 feet 8364.12 - 8379.38 feet 8406.78 - 8414.37 feet 8431.84 - 8439.44 feet 8469.96 - 8485.19 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) 5 -1/2" Baker SB -3A Pack 10678 7884.4 Packer 7" Cameo WDRP -2 SSSV 2234 2188.59 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED LIAR 0 4 2013 )3 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 62788 0 0 2311 Subsequent to operation: 0 185057 0 0 3307 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service Q Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ ) p4 Gas El - WDSPI{J GSTOR ❑ WINJ ❑ WAG ❑ 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: 312 -142 Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature "2/4 Ca Phone 564 -4424 Date 9/6/2012 RBDMS SEP 10 20124 VI F i iii /t. aI1,v 1 Form 10-404 Revised 10/2010 Submit Original Only Casing / Tubing Attachment ADL0034628 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" 91.5# H-40 36 - 112 36 - 112 1490 470 LINER 784 7" 29# NT8OS 10754 - 11538 7942.05 - 8534.71 8160 7020 PRODUCTION 10887 9 -5/8" 47# NT8OS 34 - 10921 34 - 8067.87 6870 4760 SURFACE 3938 13 -3/8" 68# NT -80 122 - 4060 122 - 3482.94 5020 2260 TUBING 10642 7" 26# NT -80 33 - 10675 33 - 7882.13 7240 5410 TUBING 84 5 -1/2" 17# L -80 10675 - 10759 7882.13 - 7945.83 7740 6280 • • 1 I Daily Report of Well Operations ADL0034628 ACTIVITYDATE } TT - con roue. rom I - I9 -12 * ** Tubing Wash ( Solvent Treatment) Speared into Tbg w bbls neat methanol followed by 100 bbls 50/50 diesel /xylene, 726 bbls fresh water w/ 0.02% F -103 surfactant & 10 bbls neat methanol to freeze protect. FWHP's= vac /520/100 SV, WV= SI SSV, 7 /10/2012 MV= 0 IA & OA= OTG. • • . TREE = e WELLHEAD= CM/ NENTED ALL REQUIRES A SSSV. IPC WITH NSCC LINER ACTUATOR= BAKER AGI-03 THREAD. KB. ELEV = 49' BF. ELEV = - KOP = 1554' Max Angle = 53 @ 9602' Datum MD = 11965' Datum TV D= 8800'SS 13 -3/8" CSG, 68#, K -55, ID = 12.415" H I 122' 1- 2234' H7" CAMCO BAL-O SSSV NIP, ID = 5.937" I 13 -3/8" CSG, 68 #, NT -80, ID = 12.415" H 4060' IA Minimum ID = 4.455" @ 10747' 5 -1/2" OTIS XN NIPPLE 7" TBG, 26 #, NT -80 -S -IPC, NSCC, .0383 bpf, ID = 6.276" H 10675' / 10675' -I 7" X 5-1/2" XO I TOP OF 5-1/2" TBG I 10675' 10678' ANCHOR .>< 10679' - -I9 -5/8" X 5 -1/2" BAKER SB -3A PKR I ' ' I 10726' H5_1/2" PARKER SWS NIP, ID = 4.562" I I I 1074 H 5-1/2" OTIS XN NIP, ID = 4.455" I TOP OF 7" LNR H 10754' I . ■ 15 -1/2" TBG, 17 #, L -80 -IPC, NSCC, .0232 bpf, ID = 4.892" H 10759' I / 10759' 5 -1/2" WLEG H I I 10766' I-f ELMD TT LOGGED 05/20/93 I 9-5/8" CSG, 47 #, NT -80 -S, ID = 8.681" H 10921' I I ■ PERFORATION SUMMARY REF LOG: SWS GR CCL ON 05/20/93 ANGLE AT TOP PERF: 42 @ 11080' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 11080 - 11100 0 5/21/93 3-3/8" 6 11200 -11220 0 5/21/93 3-3/8" 6 11314 - 11334 0 5/21/93 3-3/8" 6 11370 - 11380 0 5/21/93 3-3/8" 6 11403 - 11413 0 5/21/93 3-3/8" 6 11453 - 11473 0 5/21/93 I PBTD H 11496' I 7" LNR, 29#, NT -80-S, .0371 bpf, ID = 6.184" H 11538' I I l DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/02/93 ORIGINAL COMPLETION WELL: AGI-03 01/26/01 SIS -LG REVISION PERMIT No: '1921350 05/22/01 RN/KAK CORRECTIONS API No: 50- 029 - 22318 -00 03/13/03 AS/TP ADD'PC/THREAD FOR TBG SEC 36, T12N, R14E, 245.23' FEL & 3766.26' FNL 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 5t.ANNED AUG 0 7 2012 Anchorage, Alaska 99501 3 Subject: Corrosion Inhibitor Treatments of GPB AGI Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB AGI that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) AGI Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date AGI -01 1921240 50029223070000 0.6 NA 0.6 NA 3.4 7/25/2011 AGI-02 1921200 50029223110000 0.6 NA 0.6 NA 3.4 7/25/2011 _7AGI03 1921350 50029223180000 3.3 NA 3.3 NA 22.1 1/10/2012 AGI -04 1921460 50029223230000 1.4 NA 1.4 NA 17.0 7/23/2011 AGI -05 1930020 50029223270000 1.9 NA 1.9 NA 13.6 7/24/2011 AGI-06 1930090 50029223330000 1.8 NA 1.8 NA 11.9 1/10/2012 AGI -07 2060520 50029223430100 2.0 NA 2.0 NA 17.0 7/24/2011 AGI -08 1930330 50029223480000 1.8 NA 1.8 NA 15.3 7/24/2011 AGI-09 1930350 50029223500000 Sprit conductor NA NA NA NA NA AGI -10 2061350 50029223530100 Dust cover NA NA NA NA NA t`1Zr3So Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] Ze1 4 11.--7t, z __ Sent: Thursday, April 26, 2012 7:55 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Chivvis, Robert; G GPB FS1 DS; AK, OPS FS1 Operators; Daniel, Ryan Cc: Olson, Andrew; Walker, Greg (D &C); Clingingsmith, Mike J Subject: OPERABLE: Injector AGI -03 (PTD #1921350) MIT -IA Passed, SSSV C/O Attachments: AGI -03 TIO Plot.doc; MIT PBU AGI -03 04- 14- 12.xls All, Injector AGI -03 (PTD #1921350) passed an MIT -IA to 4000 psi on 04/14/2012. At that time the SSSV was also changed out. The IA pressure was bled down and has since remained stable as seen in the attached TIO Plot. The well is now reclassified as Operable and may remain on injection. An updated TIO plot and MIT -IA form are attached. «AGI -03 TIO Plot.doc» «MIT PBU AGI -03 04- 14- 12.xls» Thank you, Mehreen Vazir (' /t.'rttcitC. Gerald ift?fp /71") Well Integrity Coordinator BP Alaska Drilling & Wells :. MAY 2 3 201 Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Friday, March 23, 2012 8:00 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Chiwis, Robert; G GPB FS1 DS; AK, OPS FS1 Operators; Daniel, Ryan Cc: Wills, Shane M; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Injector AGI -03 (PTD #1921350) IA Repressurization Post Bleed All, Injector AGI -03 (PTD #1921350) IA pressure was bled from 1200 psi to 500 psi on 02/21/2012. Over the next 4 weeks the IAP has slowly repressurized as seen in the attached TIO plot. On 03/21/2012 the IA pressure was again bled from 1200 psi to 520 psi. Over the next two days the IA has repressurized 650 psi. The well is reclassified Under Evaluation and will remain on injection while further diagnostics are performed. The plan forward is: 1. Wellhead: PPPOT -T 2. Downhole Diagnostics: Bleed IAP to 500 psi 3. Well Integrity Coordinator: Monitor TIO post bleed and evaluate for SSSV change out and MIT -IA 1 • • A wellbore schematic, TIO Plot and Injection Plot are attached for reference: « File: AGI -03. pdf » « File: AGI -03 TIO 03- 23- 2012.doc » Thank you, Mehreen Vazir ( /tt.j'lill'phy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 2 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq @alaska.gov; doa .aogcc.orudhoe.bavCmalaska.gov; phoebe.brooksealaska.gov; tom.maunder(caalaska.00v OPERATOR: BP Exploration (Alaska), Inc. 'e-fl ‘07 ? (t FIELD / UNIT / PAD: Prudhoe Bay /PBU /AGI -Pad 1 DATE: 04/14/12 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well AGI -03 Type Inj. N ' TVD ' 7,885' Tubing 2144 2704 - 2688 2688 2688 " Interval 0 P.T.D. 1921350 ' Type test P Test psi 1971.25 Casing 282 4016 - 4000 3986 3986 ' P/F P ' Notes: Under Evaluation for IA Repressurization OA 100 120 120 120 120 IA took 402 bbls to pressure up Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle 1= Industrial Wastewater R = Intemal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU AG1.03 04 - 14 - 12 • • PBU AGI -03 PTD # 1921350 4/26/2012 TIO Pressures Plot Wet A6103 4.000 1 3.030 -19- Tim f - IA z OA 00A 000A On 1.000 "''++."'`.,� 1 fir,'\ VP �,,, � r� L. ~-� • 01/28/12 02/64/12 07/11n2 02116/12 0226/12 03103/12 ' 03/11042 03/17 /12 03M/12 03/3102 01/07/12 04/14/12 04/21/12 Injection Plot WalA10•03 3,500i 200000 3 3,300 �•. �- -��•,'� -�--v' 790.000 3,200 3,100 190,000 i 3 ' 000 170,000 2.900 2003 160,000 2.700 2,300 150p00 2.509 2.400 ( 7/0.030 2300 100.030 2,200 2,100 120,000 2,000 - WHIP 1.900 I t 710.000 3 SW 3 000 ( RV 1.700 V 00 + 100 z - MI GI 1530 / 90.000 -OBw p0 7.100 84030 7.330- 1 1200 • 70,000 1,100 1,000 60.000 900. 50.000 800 700. 40,000 600 - . 00,000 400 20,000 230 10,000 100 \ 01/28/12 02N4112 02/11/12 02 /18/12 02/25/12 03/03/12 03/10/12 02/17 /12 03/24 /12 0/21/12 04/07/12 04/14/12 0421/12 , • • d F =-s SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Bob Chivvis 35- Petroleum Engineer a �.' BP Exploration (Alaska), Inc. , P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU AGI -03 Sundry Number: 312 -142 Dear Mr. Chivvis: titAtatiED APR k _1 LtilL Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, "/ / ":71€.14)_______ Cathy ,' . Foerster Chair DATED this (V day of April, 2012. j Encl. /2 5thD ECEIVED • STATE OF ALASKA ALi OIL AND GAS CONSERVATION COMMI N APR 052012 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: Water Wash 0 • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 192 -1350 • 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 • 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22318 -00 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ❑ No 0 • PBU AGI -03 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 034628 • PRUDHOE BAY Field / PRUDHOE BAY Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11540 8536 • 11496 8503 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 91.5# H-40 30 106 30 106 1490 470 Surface 4031' 13 -3/8" 68# NT -80 29 4060 29 3483 5020 2270 Production 10893' 9 -5/8" 47# NT -80S 28 10921 28 8068 6870 4760 Liner 784' 7" 29# NT -80S 10754 11538 7942 8535 8160 7020 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7" 26# NT -80 -S -IPC 27 10675 - - 5-1/2" 17# L -80 -IPC 10675 10759 Packers and SSSV Tvoe: 7" CAMCO BAL -O SSSV Packers and SSSV MD and ND (ft): 2234 2189 5 -1/2' BAKER SB -3A PKR 10679 7885 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/19/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ o • WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bob Chiwis Printed Name Bob Chivvis Title PE Signature �%' `/' Phone Date 564 -5412 4/5/2012 Prepared by Nita Summerhays 564 -4035 COMMISSION USE ONLY 'j, Conditions of approval: Notify Commission so that a representative may witness Sundry Number: J 1 2-' I q L Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: 1 b " Ll APPROVED BY Approved by: - COMMISSIONER THE COMMISSION Date: 4.-- !Q /Z. • .t 5 it �u •-I -6 %2- ! • Form 10-403 Revised 1/2010 oRIGINAL % 4 Submit in Duplicate `� AGI-03 192 -135 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base AGI -03 5/21/93 PER 11,080. 11,100. 8,186.83 8,201.9 AGI-03 5/21/93 PER 11,200. 11,220. 8,277.41 8,292.58 AGI-03 5/21/93 PER 11,314. 11,334. 8,364.12 8,379.38 AGI -03 5/21/93 PER 11,370. 11,380. 8,406.78 8,414.37 AGI -03 5/21/93 PER 11,403. 11,413. 8,431.84 8,439.44 AGI -03 5/21/93 PER 11,453. 11,473. 8,469.96 8,485.19 AG1-03 12/28/08 BPS 10,747. 11,080. 7,936.76 8,186.83 AGI -03 1/13/09 BPP 10,747. 11,080. 7,936.76 8,186.83 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 MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 Version/ .1 04/28/2010 Fullbore Pumping Design Template Well Nam AGI -03 . Job Scope Select Job Scope H2S (ppm /date) WBL Cat IOR _ Cost 20000 2500 Max Pumping Pressure (psi) Well Type GI AFE APBinjec Main Fluid Type Date 4/4/2012 IOR 100 700 Main Fluid Volume (bbls) Engineer Bob Chivvis Phone 564 -5412 Methanol (60/40) Freeze Protect Type 10 Freeze Protect Volume (bbls) Job Objective If Applicable Recent Tbg Fluid Level (ft) Improve injectivity by dissolving salts and possibly asphaltenes in the If Applicable Recent IA Fluid Level (ft) tubing and formation. Diesel /Xylene washes have been used If Applicable Recent OA Fluid Level (ft) successfully in the past on the NGI/WGI /AGI gas injectors to improve • If Applicable Expected Tbg Fill Up Volume (bbls) injectivity. If Applicable Expected IA Fill Up Volume (bbls) If Applicable Expected OA Fill Up Volume (bbls) 418 Wellbore Volume to Perfs (bbls) Fullbore Pumping Schedule 3300 Anticipated Bottom Hole Pressure (psi) Pump Volume Rate Max 1 Select I Tubing /Casing within Pressure Limits? Stage Fluid Type Into (bbls) (bpm) Pressure Size Burst /Collapse 80% Burst /Collapse Tubing Burst (psi) 7 8860.00 . 7088 • Pre -Flush 1 I Methanol (60/40) 11 Tbg 1 10 511 25001 Tubing Collapse (psi) size See helpful tips tab Casing Burst (psi) size See helpful tips tab 1 Solvent 1 1 Select Fluid Type 1 Tbg 1 100 5 2500 Casing Collapse (psi) size See helpful tips tab Load Select Fluid Type 11 Tbg 1 7001 1 5 1 25001 Select Input Depth Integrity Issues? No unknown 1 Freeze Protect 1 1 Methanol (60/40) 11 Tbg 1 101 1 51 1 25001 No Input Depth • 1 Select Stage 11 Select Fluid Type 11 Select 1 1 1 1 1 1 No Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition Select I Production Packer within Pressure Limits? Detailed Pumping Procedure Rated Packer dp Max Anticipated dp at Packer 1 10 bbls 60/40 meoh spear i 2 100 bbls 50/50 diesel /xylene v 1 Not Necessary 1 Hold Pressure on Other Strings? 3 700 bbls of fresh water with 0.02% F -103 surfactant Y Tubing (psi) 4 10 bbls 60/40 meoh ✓ IA (psi) 5 RDMO. Return well to gas injection . OA (psi) 6 ` TREE P • S p OT ES : WELL REQUIRES A SSSV. LINER WELLHEAD= CM/ • AG I Q 3 N O ELATED ALL TBG IS IPC WITH NSCC ACTUATOR= BAKER KB. ELEV = 49' THREAD. BF. ELEV = - KOP = 1554' Max Angle = 53 @ 9602' Datum MD = 11965' Datum TVD= 8800'SS 13 -3/8" CSG, 68 #, K -55, ID = 12.415" I_f 122' I— { 2234' H7" CAMCO BAL -O SSSV NIP, ID = 5.937" I 113 -3/8" CSG, 68 #, NT -80, ID = 12.415" J--{ 4060' I-_ ' Minimum ID = 4.455" @ 10747' 5 -1/2" OTIS XN NIPPLE I--\ 7" TBG, 26 #, NT - 80 - S - IPC, NSCC, .0383 bpf, ID = 6.276" I--I 10675' / 10675' — 17" X 5 -1/2" XO I TOP OF 5-1/2" TBG I— 10675' 10678' 1 _fANCHOR I . .X, 10679' — I9 -5/8" X 5 -1/2" BAKER SB -3A PKR I 1 I I 10726' I 15 -1/2" PARKER SWS NIP, ID = 4.562" I 1 1 10747' - I5 -1/2" OTIS XN NIP, ID = 4.455" I I (TOP OF 7" LNR H 10754' I ■ 2 f 5-1/2" TBG, 17 #, L 80 IPC, NSCC, .0232 bpf, ID =4. 8 92" I—I 10759 / \ I 10759' I 5 WLEG ( 10766' H ELMD TT LOGGED 05/20/93 I 9 -5/8" CSG, 47 #, NT -80 -S, ID = 8.681" H 10921' I , ■ PERFORATION SUMMARY REF LOG: SWS OR CCL ON 05/20/93 ANGLE AT TOP PERF: 42 @ 11080' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3-3/8" 6 11080 - 11100 0 5/21/93 3 -3/8" 6 11200 - 11220 0 5/21/93 3-3/8" 6 11314 - 11334 0 5/21/93 3 -3/8" 6 11370 - 11380 0 5/21/93 3-3/8" 6 11403 - 11413 0 5/21/93 3 -3/8" 6 11453 - 11473 0 5/21/93 PBTD I--I 11496' I J l 7" LNR, 29 #, NT -80 -S, .0371 bpf, ID = 6.184" I 11538' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/02/93 ORIGINAL COMPLETION WELL: AGI-03 01/26/01 SIS -LG REVISION PERMIT No: • 1921350 05/22/01 RN /KAK CORRECTIONS API No: 50- 029 - 22318 -00 03/13/03 AS/TP ADD IPC/THREAD FOR TBG SEC 36, T12N, R14E, 245.23' FEL & 3766.26' FNL 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE Regg, James B (DOA) frr cgzi350 From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] 'Ref/ qz 7 Sent: Friday, March 23, 2012 8:00 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Chivvis, Robert; G GPB FS1 DS; AK, OPS FS1 Operators; Daniel, Ryan Cc: Wills, Shane M; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Injector AGI -03 (PTD #1921350) IA Repressurization Post Bleed Attachments: AGI- 03.pdf; AGI -03 TIO 03- 23- 2012.doc All, Injector AGI -03 (PTD #1921350) IA pressure was bled from 1200 psi to 500 psi on 02/21/2012. Over the next 4 weeks the IAP has slowly repressurized as seen in the attached TIO plot. On 03/21/2012 the IA pressure was again bled from 1200 psi to 520 psi. Over the next two days the IA has repressurized 650 psi. The well is reclassified Under Evaluation and will remain on injection while further diagnostics are performed. The plan forward is: 1. Wellhead: PPPOT -T 2. Downhole Diagnostics: Bleed IAP to 500 psi 3. Well Integrity Coordinator: Monitor TIO post bleed and evaluate for SSSV change out and MIT -IA A wellbore schematic, TIO Plot and Injection Plot are attached for reference: «AGI- 03.pdf» «AGI -03 TIO 03- 23- 2012.doc» Thank you, ANNED MAR 2 9 2012 Mehreen Vazir (Alternate: Gei all ;i- larrl>Jt� Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com 1 • • PBU AGI -03 PTD #1921350 3/23/2012 T1O Pressures Plot Wd:A61 -03 1 000 3,000 + 163 O 2000 00 000 + 0 � On 1.W0 1 ` `1 \ / ' Y om.. 12/24/11 12/31/11 01/07/12 01/14/12 01/21/12 01/28/12 02/04/12 02/11/12 02/18/12 02/2/12 03/03/12 03/10/12 03/17/12 Injection Plot YhkA01O3 3,500 - - 210000 3,400'\ i10111.■■ _ . 2913/060 3.300 - �� ' 3,200 - , - 151,000 3.100 - :180000 lOW - 170.000 2/30D 2,700 1 - 180300 2W0 2.501/ -1 _3.000 • 2,400 �,r...,.� - 1400(0 2.300 � + \ - 130,000 2100 f ` - 12300 m -WHIP 1.91 ' \ - 110000 § - L W 1.400 1.300 - 81.010 122 um 1.000 - 80,000 500 / I •■■• OA OM 700 - 40.000 500. - 31300 I WO -2.000 300: -10000 100- 1224/11 12/01 /11 01/07/12 C6/14 /12 01/21 /12 01/2812 02/04/12 82/11 /12 02/1812 02/a/12 03/03/12 03/10 /1 2 43/17/12 TREE _ • SAF"ETOTES: WELL REQUIRES A SSSV. LINER WELLHEAD= CM! ACTUATOR= BAKER G 1 _0 3 NOT CEMENTED. ALL TBG IS IPC WITH NSCC KB. ELEV = 49' BF.ELEV= KOP = 1554' Max Angle = 53 @ 9602' Datum MD = 11965' Datum 7VD= 8800'SS 13 -3/8" CSG, 68 #, K -55, ID = 12.415" 1--1 122' (- 2234' (-(7" CAMCO BAL -O SSSV NIP, ID = 5.937" 1 ( 13 -3/8" CSG. 68 #, NT -80, ID = 12.415" H 4060' Minimum ID = 4,455 " @ 10747' 5-1/2" OTIS XN NIPPLE 7" TBG, 26 #, NT -80 -S -IPC, NSCC, .0383 bpf, ID = 6.276" ( t 10675' / 10675' --17" X 5 -1/2" XO 1 TOP OF 5 -1/2" TBG 1 10675' 10678' 1- -1ANCHOR I 1 10679' 1-19 -5/8" X 5 -1/2" BAKER SB -3A PKR ( I 1 I 10726' 1 -1/2" PARKER SWS NIP, ID = 4.562" 1 I 10747' - -15 - 1/2" OTIS XN NIP, ID = 4.455" 1 +TOP OF 7" LNR H 10754' 1 ( 5 -1/2" TBG, 17 #, L- 80 -IFC, NSCC, .0232 bpf, ID = 4.892" 1-1 10759' 1 / \ 10759' 1- 5 -1/2" WLEG ( ( 10766' H ELMD TT LOGGED 05/20/93 1 ,kkAiP= 6 €7op5; 9 -5/8" CSG, 47 #, NT -80 -S, ID = 8.681" (-1 10921' ( PERFORATION SUMMARY REF LOG: SWS GR CCL ON 05/20/93 ANGLE AT TOP PERF: 42 @ 11080' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3-3/8" 6 11080 - 11100 0 5/21/93 3 -3/8" 6 11200 - 11220 0 5/21/93 3-3/8" 6 11314 - 11334 0 5/21/93 3-3/8" 6 11370 - 11380 0 5/21/93 3 -3/8" 6 11403 - 11413 0 5/21/93 3-3/8" 6 11453 - 11473 0 5/21/93 (PBTD I-f 11496' 1 7" LNR, 29#, NT -80 -S, .0371 bpf, ID = 6.184" 1-1 11538' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOEBAY UNIT 01/02/93 ORIGINAL COMPLETION WELL: AGI-03 01/26/01 SIS -LG REVISION PERMIT No: F 1921350 05/22/01 RN/KAK CORRECTIONS API No: 50 -029- 22318 -00 03/13/03 AS /TP ADD IPC /THREAD FOR TBG SEC 36, T12N, R14E, 245.23' FEL & 3766.26' FNL 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE ~ MEMORANDUM Ta~ Jim Regg P1. Supervisor ~ ~l/ ~~~d l ~ ~ ( FROM: Jeff Jones Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 08, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC AGI-03 PRUDHOE BAY UNIT AGI-03 Src: Inspectot NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY LJNIT AGI-03 API Well Number: 50-029-22318-00-00 Inspector Name: JeffJones Insp Num: mitJJ090906173648 Permit Number: 192-135-0 ~ Inspection Date: g~21/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ^GI-o pe Inj. ~ I TVD ~ass r Ip an z2oo ' zi~o ziio ~ P.T.DI 1921350 ~TyPCTCSt ~ SPT ~ Test psi -- 197125 QA 200 390 380 375 Interval 4YRTST p~F P ~ Tubing 3450 3460 3460 3440 Notes' 3.2 BBLS diesel pumped. +~y '!a ( ~; ~ : `C~ ~ f~ .. t.~/1.3,~~ Tuesday, September 08, 2009 Page 1 of 1 ~ ~ STATE OF ALASKA A~ASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. ~1 ~\~ J 1 FIELD I UNIT / PAD: Prudhoe Bay / PBU / AGI ~ j ~ J DATE: 08/20/09 ~ 0~~ ~~ / OPERATOR REP: Torin Roschinger ~ AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well AGI-02 T e In'. G TVD 7,862' Tubin 3370 3360 3360 3360 Interval 4 P.T.D. 1921200 T pe test P Test psi 1965.5 Casing 970 2210 2190 2190 P/F P Notes: MIT-IA for 4 year regulatory compliance OA 600 710 710 710 Well AGI-03 Ty e In'. G TVD 7,885' Tubin 3450 3460 3460 3440 Interval 4 P.T.D. 1921350 T e test P Test psi 1971.25 Casin 475 /2200 2170 ~2180 P/F P Notes: OA 200 390 380 375 Well AGI-04 T e In'. G ND 7,920' Tubing 3410 3400 3400 3400 Interval 4 P.T.D. 1921460 T e test P Test si 1980 Casing 590 2210 2240 2280 P/F F Notes: OA 300 415 430 450 Well AGI-06 Ty e In . G TVD 7,883' Tubin 3360 3360 3360 3360 interval 4 P.T.D. 1930090 T e test P Test si 1970.75 Casing 360 2200 2170 2170 P/F P Notes: OA 390 550 550 550 Well Ty e Inj. TVD Tubin Interval P.T.D. T etest Test si Casin P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas i = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Intemal Radioactive Tracer Survey A = Temperature Momaly Survey D = Differential Temperature Test ~_ ~i't,;~'~,. '~~l`,~. < ,.. ~ ` ~r ~,. d~ ~~! w r~ ~ny~<' ~. ~ ~l~l~ INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other(describein notes) MIT Report Form BFL 9/1/05 MIT PBU AGI 02, 03, 04, 06 08-22-09.x1s MEMORANDUi~ State of'Alaska Alaska Oil and Gas Conservation Commission TO: Julie HeUsser ~~O\ DATE: May 27, 2001 Commissioner · . SUBJECT: Mechanical Integrity Tests THRu: T°m Maunder ,~..¢~.~'~ BPX P.I. SuPervisOr AGI Pad (~ [~,--O\ AGI-01, 02, 03, 04, 05 FROM: Jeff JoneS PBU Petroleum InSpector PBF · NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min, · 30 Min, · Welll AGI-01 J Typelnj,I G I T,V,D. J 7910 I TubingJ 3500 I 3500 I 3500 I 3500 I lntervalJ 4 P,T.D,I '192-124 ITYpetestl P j Testpsil 1978 I CasingI 450 I 2100 I 2090 I 2080 I P/F I P Notes: WellI AGI-02 I Typelnj. I G I T.V,D, J 7858.1 TubingJ 3500 I 3500 I 3500 I 3500 J lntervalI 4 P,T,D.I 192-120 ITypetestl P I Testpsil 1965 I CasingI 325 I 21°°1 210o1 21°°1 P/F I P Notes: WellI AGI-03 I mypelnj, I G i T,V.D' i 7870 ITubing J 3500 I 3500 I 3500 J3500 /In{ervall' 4 P,T,D.I 192-135 ITyPetestl P '. I Testpsil 1968 I CasingI 600 I 2120 I 2~0 I 21~o I' P/F I -P-P Notes: we, l~ AGI,04 ~ I ~.~.~. I~ J mubingJ3500 13500 13500 13500 I,nterva, J 4 P.T.D.I 192~146 I'rypetestl P I Testpsil lg75 I CasingI 360 I 2180 I 2200 I 2200 I P/F I -P Notes: we,,J AG','05 mype,nj.J G I T.V.D. P.T.D.I 193-002 Type testI P' I Testpsil 1936 I CasingI 600 I 21001 21001 21°° I 'P/F I P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G -- GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) TeSt's Details Sunday, May 27, 2001: I traveled to BPX'S AGI Pad to witness 4 year MIT's on gas injection wells AGI-01, 02, 03, 04, and 05. The pre-test pressures were observed to be stable and the standard annulus pressure test was then performed with all five wells passing the MIT's. The test data above indicates these wells are suitable for continued injection. Summa~: I'witnessed five successful MIT's on BPX's AGI Pad in the Prudhoe Bay Field· M.I.T.'s performed: _5 Number of Failures: _0 Total Time during tests: 3 hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT PBU AGI-01,02,03,04,05 5-27-01 JJ 6/9/01 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE DECEMBER 01, 2000 E P L W M ATE IA L U N D ER T H IS M ARK ER AOGCC Individual Well - Geological Materials Inventory Page: 1 Date: 04/04/95 PERMIT DATA T DATA_PLUS RUN DATE_RECVD -- 92-135 5822 92-135 407 92-135 DAILY WELL OP ~I~"OH-DPR, 8347-11540 ~/CoMP DATE:05/20/93 12/18/92-04/13/93 10/19/1993 08/26/1993 08/26/1993 92-135 SURVEY ~R SS DIRECTIONAL 08/26/1993 92-135 SURVEY 92-135 SURVEY ~ MWD / q~MWD DIRECTIONAL 08/26/1993 09/13/1993 92-135 DPR/GR '~ MWD RUNS 4-9, 2&5"MD 06/28/1993 92-135 DPR/GR t/L MWD RUNS 4-9,2&5"TVD . 92-135 PERF ~5" RUN 1 1 92-135 SBT/GR/CCL ~ CH 1 06/28/1993 07/30/1993 07/30/1993 03/19/1993 Are dry ditch samples required? yes -____~And received? .~no Was ~the well cored? yes ~Analysis & description.~6~ved? Are well tests required? ~.es ~Received? yes~~ Well is in compliance Initial COMMENTS yes no ARCO ~l._~k,: Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-11-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS Q~-I~ AGI-2~_~t[12/7-14/93 DPR/GR e.~gl-lbZ~5' Runs4-7 Job~11~ BHI fla'-4~ AGI'3~2~12/24'31/9~'DpR/GR t5~{~f"ll*q(Y 1~m~4-8 Job~l163 BHI Please sign and return ~he attached copy as receipt of data. RECEIVED BY .~ Have amce ~ay.' - ' ~ ,OQ. ~'~///~,. Sonya Wallace APPROVED .~?~._ iTO- 1529 Trans# 9311 ~-~ .... CENTRAL FILES iCH) # PHILLIPS CHEVRON D&M # BOB OCANAS (OH/GCT) # EXXON MARATHON MOBIL PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO * The correct logging date for this tape is 12/24-31/92. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-10-93 REFERENCE: ARCO DIRECTIONAL DATA ~- ~ 3-18A 4-24-93 Electronic Multi-Shot Survey Job~~ Sperry q% 4-/ 3-20A 4-14,93 Electronic Multi-~hot Survey Job~~ Sperry ~-~o~ 5-3A 5-2e,93 MWD Directional Survey Aha ~~ 5-14A 6-36~ MWD ~ Survey Aha ~%-~ 5-15A ~26-93 MWD Directional Survey Aha ~-5~ 6-22A 4-30-93 MWD Directional Survey Aha c/~-~O 18-29A 4-26-93 MWD Directional Survey Aha ~ ~q.~-~ I~AGI-3 4-14-93 MWD Directional Survey Job~ 1163 BHI ~- I% AGI-4 4-14-93 MWD Directional Survey Job~1168 BHI q~-27 AGI-7 4-28-93 MWD Directional $urvey Job~ 1185 Teleco /AGI-9 3-17-93 MWD Directional Survey Job# 1195-450 BHI ~ ~ *~,AGI-9 54~93 MWD Directional Survey Job~11~ BHI Please sign and return the attached copy as receipt of data. /' o ' Have A Nice Day! \ Sonya Wallace APPROVED_.A¥,,v ~' ~,~ ATO- 1529 Trane# 93102 ' ' "~.. CENTRAL FILES CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON MOBIL # PB WELL ~ R&D #BI~X # ST. OF AK. (2 COPIES) # LUCILLE JOHNSTON INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 92-135 D?R/GR 92-135 DPR/GR 92-135 GR/CCL 92-135 PERF 92-135 SBT/GR/CCL 92-135 407 92-135 92-135 92-135 Are well tests required? Was well cored? Yes No... DAILY WELL OP SURVEY SURVEY Yes No MWD RUNS 4-9, 2&5"MD MWD RUNS 4-9,2&5"TVD 5" RUN 1 5" RUN CH R1 5" COMP DATE:05/20/93 12/18/92-04/13/93 MWD SS DIRECTIONAL If yes, was the-core analysis & description received? Yes No Are dry ditch samples required? Yes No 08/30/1993 PAGE: 1 WELL IS ON COMPLIANCE. INITIAL COMMENTS: '~ STATE OF ALASKA ALASKA!ioIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE D( An~x ~.~ In.i~ctor 2. Name of Operator 0j~/G//~4L 7. Permit Number ARCO Alaska, Inc. 92-135 3. Address t 8. APl Number P. Oo Box 196612, Anchorage, Alaska 99519-6612 s0- 029-22318 4. Location of well at surface 9. Unit or Lease Name 1819' NSL, 2432' WEL, SEC. 36, T12N, R14E ~r '~" Prudhoe Bay Unit At Top Producing Interval ~ i-'VLr~'~--~i 10.AGi.3Well Number At Total Depth ~ ~!111' Field and P°°l 1517' NSL, 4629' EWL, SEC. 31,. T12N, R15E i Prudhoe Bay Field/Prudhoe Bay Pool 5. Elevation in feet (indicate KB, DF, etc.) i6. Lease Designation and Serial No. KBE = 48.8' I ADL 34628 12. Date SpUdded12/17/92 13. Date T.D. Reached4/g/93 14' Date C°mp" Cusp' er Aband' IlS' Water Depth' if °ffsh°re 116' N°' °f C°mploti°nss/20/93 N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permaf. rost / 11540' MD/8536' TVD 11496' MD/8503' TVD YES [] N3 [] 2234' feet MD I 1900' (Approx.) 22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECORD SETrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.51t H-40 30' 106' 76' 11 yds Arcticset 13-3/8" 68# NTSO 37' 4060' 16" 2604 cuft PF "E'/464 cu fl Class "G" 9-5/8" 47# NTSOS 35' 10921' 12-1/4" 440 cuft Class "G' 7" 29# NTSOS 10743' 11538' 8-1/2" Uncemented 24. Perforations open to Production (MD+TVD of Top and Boltom and 25. TUBING REC_,ORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter 3-3/8" 6 spf 7" x 5-1/2" 10759' 10679' MD TVD 11080'-11100' 8138'-8153' NT-80/L-80 11200'- 11220' 8228'-8243' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11314'-11334' 8315'-8330' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 11370'-11380' 8358'-8365' 11403'-11413' 8383'-8390' 11463'-11473' 8419'-8436' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 5/31/93 I/njecting Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL ;)IL 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. RECEIVED AU G 2 6 1993 Alaska 0ii & Gas Cons. C0mmissi0~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. i i=~ i~ 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase, Top Sadlerochit 10952' 8042' Zone 3 11030' 8100' Zone2 11178' 8212' Zone I 11383' 8367' Base Sadlerochit 11483' 8444' 31. LIST OF A'I'rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge '~gned ~.~t TitleDrillingEngineerSuoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". R E C ~IV E D Form 10-407 AUG 2 6 3993 Alaska Oil & Gas Cons. Gommissior~ Anchorage Prudhoe Bay Drilling ?'" ilsY Drilling Report. w~;,: AGI-3 Depth(MD/l'VD): 715 / 714 'J Prey (~'D): 106 JProgress': 609 I I , Contractor: AUDI2 Phone: 4605 J Daily Costs: $106,815.00 J Est Cum Costs' $106,815.00 ILast Csg: 20"@ 115' INext Csg: i33/8" IS'hoe "N/,~' Operation at 0600: ,, D R ! L LIN G , I(size/depth) (,,.'ize) Rig Accept (hr/date): 12/17/92 @ 0900 Rig Release( hr/date): , Mud Data Bit )ara Dril!ina Data Rot 70 M~'dTypesPUD MBT 20.0 Bit No. I Depth 715 Wt. ,, Weight 8.6 pH 10.2 Size 16" P.U. 70 S.O. 70 ~ Wt. Wt. Viscosity 2:10 Pm 0.5 Make SMITH Avg. Max se: ., Drn~ Drag PV/YP 16 / 50 Pf 0.3 Type AIJSL Trq- Trq Btm Off G~'ls 20 / 32 Mf 0.9 iSerial No. KV0618 PL'no Data ..... Pump No. 1 2 APl W.L. Chlorides Depth Out , 10.2 1300 ppm MD/TVD / / / Liner Size 5.5" 5.5" HTHP Oil 0 :Footage .. 100 esi % ft. ft. ft. SPM 1 15 115 HTHP OWR 0 / 97.5 ART/AST 500 / / / GPM 406 406 Solids 2.5 ES RPM 45 9O % Table/Mtr / rprr / rpm / rprr · WeB ' ' Pressure 1500 sand .5 .% LGS 2.3 Mia/Max, 1° / 20 F¢ / K~ / F¢ . Hole Vol. Pit Vol. .., Slow Pump Data 63.0 bbl 800.0 Jets/TFA 16 18 18 Slow P.S. Bit Costs :Filter 3 iCalcium 60 ppm $19983.00 Cake $3,032.00 $6032.00 Grade ,, BHA Description: BIT #1, XO, 1'F2000, XO, NM STAB, NMLC, NM STAB, MWD, NM sT ,3 NMDC, STAB, JARS, XO, 30 HW. , ,,, BHA No: 1 , ,,, Injection Data ,, Source: Volume: Type Fluid' i Injection IRate: IPressure: ..... W~II; ~lpml, psi Daily I Cumulative Volume: bb] Volume: Freeze Protect Fluid: Volume: gal ,,, Fuel & Water Data F~el 3462 gal--ource:[S BP 10013.00 1100 VERN Used' Recv'd: gal Used: BBL Source: (Juttin.qs Data ' I Weather Data · Speed: 5 -10 oF Daily: 16CU YD oF~Umulative:16CU YDc.JSt°rage DS5 Temp: -2 oFJwind r.,hlOhi,I F~cts'~: ~I ~ite; , , Personnel & Safetv/BOP Data Accident?(Y/N): N IName: IEmplayer: Jr-,ptFi,ed?(Y/N): PB Drlg: 11 Contractor: 24 JServico: 11 J Other: 8 J Total: 44 Last BOPE Test: 12/17/92 Last BOP Drill: Last H2S Drill: Last Fire Drill: Last SafetY/ Mtg: 1 2/1 7/92 Last Spill Drill: Spill (Y/N)? Volume (Gals.): Type Spill: Report Filed? Time Ooeratian Prob Code Hrs. O~)~rations From 0600 to 0600 , , 0600-0900 OTHR 3.00 SKIDDED RIG FROM AGI-2TOAGI-3. 0900-1745 'OTHR 3.00 ACCEPTED RIG @ 0900 HRS. N/U 20" DIVERTER & MIXED SPUD MUD. 1745-2115 TRIP 3.50 P/U BHA #1 & ORIENTED MTR / MWD. 2'115-0600 DRILL 8.75 TAGGED@ 106'. DRILLED FROM 106'TO715'. HAD SUBSTANTIAL AMT OF . ,,,, , GRAVEL. K/O @ ~615'. (STARTED SLIDING AT THAT POINT.) ,,, ,, , ,, .... , ,,,, Prudh0e ,Bay Drilling ?x ilsY Drilling Re.port AFE. No: 4J0194 Rpt. No: / I 2/1 9/92 2 Well: AGI-3 Depth(UD/TVD): 2129 / 2097 1Prey(MD): 715 !Pr°gress: 1414 Contractor: Audi2 Phone" 4605 IDaily c~sts: $56,492.00 IEst Cum C°sts' $163,307.00 IOperation at 0600: SHORT TRIP N/A ILast Csg: 20" @ 115' I Next Csg: 133/8" IShoe , ,, I(size/depth) I(size) ITest: Rig Accept (hr/date): 12/17/92 @ 0900 ! Rig Release( hr/date): I Mud )ata Bit ;)ata Drilling Data Rot Mud TypesPUD MBT 17.5 Bit No. I Depth 2129 Wt. 95 Weight 9.0 pH 8 7 SiZe 16" P'.U. 100 S.O. 90 F~ ' Wi, Wt. ViscoSity 170+ Pm Make SMITH Avg. 5 Max sec Draa Draa _ -- Trq Trq PV/YP 9 / 35 Pf 1.0 Type A1JSL Btm Off Gels 18 / 26 Mf 0.4 Serial No. KV0618 punoData Pump No. 1 2 Depth Out APl W.L. 16.0 Chlorides 700 ppm MD/l-VD / / / Liner Size 5.5" i~.5" 5.. HTHP el! 0 Footage 2023 100 psi % ft. ft ft. SPM 115 115 HTHP DWR 0 / 94 ART/AST 5.3 / 15.5 5oo psi / / GPM 406 406 ES RPM 6O 9O Solids 6.0 % Table/Mtr / rprr / rprr / rprr Pressure 2400 i LGS WeB 10 4O Sand .25 % 5.4 Min/M~x, / Slow Pump Data !Pit Vol. iHole Vol.428.0 bbl 675.0 Jets/TFA 16 18 18 Slow P.S. Filter 3 Calcium 40 Bit Costs $19983.00 iOake ppm Daily Mud $ Total Mud $ Dull $3,498.00 $9530.00 Grade ii I II III BHA Description: BIT #1, XO, l'F2000, XO, NM STAB, NMLC, NM STAB, MWD, NM STAB, 3 NMDC, STAB, JARS, XO, 30 HW. BHANo: 11BHALength: 1120.14 IDateLastlnspected: I Hours On Jars: 90.5 Iniection Data Source' Volume: Type Fluid: Injection IRate: IPressure: W~II;! ~pmI psi Daily I Cumulative Volume: bbl Volume: Freeze Protect Fluid: Volume: gal Fuel & Water Data Fuel 6351 IFuel ! ue' 0.00 JDrl'Water 1675 IDrl' water VERN USed: gal[Source: BP Recv'd' gal Used' BBL Source: Cuttin,qs Data We~tther Data Daily: 850YD c~3umulative: 866 YD JStorage DS 5 Temp:IWind Speed: mpJOhill Factor: CFI Site:, °F I· °F Per=e-nnel ~ Safetv/BOP Data Accident? (Y/N>: N IName: I~mp'byer: IRpt Filed' (Y/N,: PB Drlg:. I i Contractor: 24 lService: 11 !Other: 8 IT°tal: 44 Last BOPE Test: 12/17/92 Last BOP Drill: Last H2S Drill: Last Fire Drill: Last Safety Mtg: 12/17/92 Last Spill Drill: Spill (Y/N)? Volume (Gals.): l'ype Spill: Report Filed? Time Ooeration Prob Code Hrs. Ooerations From 0600 to 0600 0600-0400 DRILL 22.00 DRILLED FROM 7'15' TO 2129' MD. SLIDING, DICKING OFF. HAD LARGE AMT OF GRAVEL. COAL STREAKS ETC CAUSING ROUGH DRILLING. 0400-0445 CiRC 0.75 ClRC BTM UP. 0445'0600 TRIP 1.25 SHORT TRIP TO WIPE THROUGH CLAY ETC. · Prudhoe Bay Drillincl ': ' Daily Drilling Re rt AF~'-N°: 4J0194 2 j 12/19/92 A(..51-3 Survey Data Surv. No. I 2 3 4 5 6 7 8 9 1 0 11 Depth (MD) 279 579 759 939 112~ 130 ~ 14c~5 161 2 18 70 2(: 59 ,, , Angle 3 .2 1.3 3.7 6.0 8.8 9.2 12.1 15.3 24.4 Direction 1 6 231 103 97 88 91 94 92 96 86 T.V.D. i279 579 759 939 1119 1306 1490 11674 1857 2034 Vert. Sec. !0 0 2 10 25 49 78 :113 157 221 North/South'7 1.13 .48 -.64 -1.02 -.86 -1.92 -3.52 -6.76 -6.87 , , , East/West 2 0 1.75 9.51 24.77 48.97 78.2 112.72 157.09 221.01 Dog Leg .11 .16 .8 1.34 1.33 1.5 ~.32 1.56 1.77 5.09 'Mud Lo,q Data Depth Mud Wt. Formation BG gas Conn gas Trip gas PPg U U Max BGG Dc Exponent Shale density !Est. pore press ROP/Shale ROP/Sand L fph Time Ooeration Prob Code Hrs. Operations From 0600 to 06(: 0 .. . , Prudhoe Bay Drilling, ~,~ iii,, ~ D~.ilsY Drillinq ReP0,rt Well: AGI-3 Depth (MD/TVD): 3671/ 3229 ]Prev (MD): 2129 ]Progress 1542 I I Contractor: Audi 2 Phone: 4605 i D~.i'Jy Costs: $76,640.00 lest Cum Costs: $239,947.00 I (~peratior~ at 0600: D R I L L I N G N/A ]Last Csg: 20"@~5' ]NextCsg' ~33/e:' }Sh°e l{size/depth) . .. I(size) ITest: Rig Acce~3t (h'r/d~te): 12/17/92 @ 0900 ] Rig Release( hr/date): I '" Mud )ara Bit 3ara .... D'rillino Data Rot k;lud TypesPUD MBT 22.5 Bit No. 1 1RR Depth 3671 95 Wt. Weight 9.4 pH 8.9 Size 16" 16.000 P.U. 100 s'.o. 90 PPg Wt, wt. Viscosity 115 Pm 0,1 Make SMITH SMITH Avg. Max sec Dra~ Draa PV/YP 12 / 32 Pf 0 I Type AIJSL AIJSL Trq- 225 Trq- 175 · Btm Off Gels 22 / 29 Mf 0.6 Serial No. KV0618 KV0618 Pt mo Data Pump No. 1 2 Depth Out 3114 2937 APl w.L. 16.0 Chlorides 750 ppm MD/TVD / / / Liner Size 5.5" ].5" 5., H'THP Oil 0 Footage 3008 557 ,, 100 Ds] % fL ft ft. SPM 115 115 HTHP OWR 0 / 92.5 ART/AST 6.8 / 20.0 5.3 / 0.5 500 esi I / GPM 406 406 Sol]dis 7.5 ES RPM 60 90 60 90 -, % Table/Mtr / rprr / rprr / rprr ' Pressure 3200 '~ LGS WeB Sand .25 % 6.4 10 40 30 40 MiniMax. / K~ / K~ / K~ Pit Vol. Slow Pump Data Hole Vol.839.0 bbl 600.0 Jets/TFA 16 18 18 16 18 18 ' Filter Calcium Bit Costs Slow P.S. 3 60 $19983.00 Cake ppm $3,333.00 $12862.00 Grade.. E I NO BHA Description: BIT #1, XO, 1'F2000, XQ, NM STAB, NMLC, NM STAB, MWD, NM STAB, 3 NMDC, STAB, JARS, XO, 30 HW. , iniection Data Source: Volume: Type Fluid: Injection IRate: IPressure' . Welh ~]pmI psi i Daily i Cumulative I Volume: bbl Volume: Freeze Protect Fluid: Volume: gal Fuel fi Water Data Used: gat[Source: BP 10029.00 1 725 VERN Recv'd: gal Used: BBL S3urce: Cuttings Data , Weather Data F]C IWind Speed: , ] Chili'Factor: -26 umulative:1262 YD ]Storage DS 5 Temp: -22 oF o Daily: 396YD c Gq~ite: 3 mpnl Accident? (Y/N): N IName: Personnel & S~tfetv/BOP D'ata . IEmpl°yer: I Rpt F;'.-~d? (Y/N): I J:;'B Drlg: 1 ! Contractor: 24 IService: 13 ]Other: 8 IT°rah '' 46 Last BOPE Test: 12/17/92 iLast BOP Drill: Last H2S Drill: Last Fire Drill: Last Safety Mtg' 12/17/92 Last Spill Drill: Spill (Y/N)? Volume (Gals.): Type Spill: Report Filed? Time Oa~ratic~n I Pmb Cod~ Hrs. Operations From 0600 to 0600 0500-0630 TRIP 0.50 FINISHED SHORT TRIP. NO FILL. NO PROBLEMS. 0630-1700 DRILL 10.50 DRILLED & KICKED OFF 2129-3114' MD. BROKE MOTOR DRIVESHAFTi 1700-1800 CIRC CIRC & CLEANED HOLE. i800-1945 TRIP 1.75 POH. MOTOR HAD BROKEN DRIVESHAFT. STICKY BTM 12 STD. · · 1945_2245 TRIP 3.00 CLEANED STABS, CHANGED MOTOR, ORIENTED & TIH. 2245-0600 DRIL 7.25 DRILLED FROM 3114' TO 2671' MD. ,, Prudhoe Bay Drillinq ., ~, iAFE. No: 4J0194 II~pt. No: 3 ii, Date: I ! Surv. No. J 11 ! 12 ! 13 ITM Depth(MD)! 2247I 2429! 26171 28, Ve'rt Sec [3'07 1406 1519' 1639 North/Sou't'~'5.25 J-6.6, J-8.20 !-7.62 East/West J306.981405.661519.03 J638.§ DogLeg /3.23 13.02 11.60 11.40 12/20/92 IWell Name: ISupv' Daily Drilling Report Init: GLC [ Page 2 Survey Data /90'3 ~0'6 ~4'2 / 1768 ' P27 110951 /-6'35 ~7'62 !-14'67/ 71767'65~26'7111095 / Mud L.o,q Data Depth Max BGG T~B~ JMud Wt. . 4Dc Exponent O~eration Prob Code ppglF°rmati°n IShale density Hrs. gas ulCOnn gas OperJt~tn~PF°rroemPr0~s0s0 to 06010ReP/Shale fphfRr i p gas OP/Sand u Prudhoe Bay Ddlling - ilsY Drillina Report ' '""'""' '"""' --'~"' ........ =! ] ! 'lS'"upv. Init:- AFE. No: 4J0194 Rpt. No: ~! ]il;,; Date: I 2/21/9 2 Days Sinc,.. _. J/Est: 4 ~./-.,¢ Well: AGI-3 Depth(MD/TVa): 4070 / 3488 IPrev(MD): 3671 IPr°gress: 399 I Contractor: Audi2 Phone: 4605 IDaily C°sts: $233,534.00 J Est Cum Costs: $473,481.00 I ILast Csg: 20"@ 115' INext Csg: 133/8" IShoe N/A Operation at 0600: N/D FOR TOP JOB I(size/depth)i(size) ITe~t: Rig Accept (hr/date): 12/17/92 @ 0900 I Rig Release( hr/date): I Mud ')ata Bit ~)ata Drilling Data Rot Mud TypeqPUD,., MBT 27.5 Bit No. 1RR Depth 4070 Wt. Weight 9.3 pH 9.0 tSize 16.000 P.U. 120 S,O, 85 ROCJ Wt, Wt. Viscosity 1 15 Pm 0.1 Vlake SMITH Avg. Max s~ Drag Drao_ PV/YP 10 / 30 Pf 0 I Type A1JSL Trq Trq ' Btm off PL rno Data Gels 20 / 32 Mf 0.6 Serial No. KV0618 Pump No. 1 2 Depth Out 4070 / 3488 APl W.L. 16.0 Chlorides 800 ppm MD/l-VD / / Liner Size 5.5" 5.5" HTHP Oil 0 Footage 956 100 esi % ft ft ft. SPM 115 115 HTHP OWR 0 / 91.5 ART/AST 6.3 / 1.3 50o esi / / GPM 406 406 ES RPM Solids 8.5 % !Table/Mtr / rprr 60 / 90 rpm / rpm LGS WeB Pressure 32 0 0 Sand .25 % 5.9 Min/Max. / F¢ 30 / 40 F¢ / F¢ Slow Pump Data Hole Pit Vol. 400.0 iJets/TFA 161818 V°1'976.0 bb~ Slow P.S. Filter Calcium Bit Costs Cake 3 80 ppm o,a, ud. $3,988.00 $16850.00 Grade " E I NO BHA Description: BIT #1, XO, 1'F2000, XO, NM STAB, NMLC, NM STAB, MWD, NM STAB, 3 NMDC, STAB, JARS, XO, 30 HW. BHANo: 2 IBHALength: 1120.14 IDate Last inspected: [ Hours On Jars: 99.75 Iniection Data Source: Volume: Type Fluid' Injection IRate: IPressure: Well; ~lpmI psi Daily I Cumulative Volume: bbl Volume: Freeze Protect Fluid: Volume: gal Fuel 5543 !Fuel IFue' ~u¢l & Water Data I I iUsed: gal[Source: BP 0.00 Drl. Water 875 Drl. Water IRecvd: gal Used: BBL Source: VERN. outtin.qs Data Weather Data I:[C ~St°rage DS5 Temp: _24 IWind Speed: 20 4Chill Factor: -78 Daily: 328 c umulative:1590 YD c~dite; , personnel & Safetv/BOP Data iAccident?(Y/N): N !Name: !EmpI~3yOr: !RptFilOd?(Y/N): PB Drlg: I ! Contractor:' 24 ISorvico' 13 IOther: 8 ITM 46 Last BOPE Test: 12/17/92 Last BOP Drill: Last H2S Drill: Last Fire Drill: Last Safety Mtg: 12/17/92 Last Spill Drill: Spill (Y/N)? Volume (Gals.): type Spill: Report Filed? , , Time Operation Prob Code Hrs. Ooerations From 0600to 0600 0600-0930 DRIL 3.50 DRILLED FROM 3671' TO 4070'MD. 0930-1045 CIRC 1.25 CIRC HOLE CLEAN. 1045-1345 TRIP 3.00 SHORT TRIPPED TO 1120'. HOLE IN RELATIVELY GOOD SHAPE. 1345-1445 ClRC 1.00 CIRC. 1445-1745 TRIP 3.00 DROPPED SS. POH SLM. BHA BALLED UP. 1745-2315 CASG 5.50 R/U WOTCO. RAN 105 JTS 13-3/8" CSG AS' PER PROG. GOOD DISPLACEMENT. 2315-0200 ClRC 2.75 R/U CMT HEAD. ClRC 2 CSG VOL. 0200-0545 CASG 3.75 CEMENTED CSG. LOST RETURNS FOR 15 MIN , THEN REGAINED'SAME. DID NOT GET CMT TO SURFACE. 0545-0600 CASG 0.25 N/D DIVERTER & PREP FOR TOP JOB. Prudhoe Bay Drillin< ~ "~" Daily Drilling RePOrt " ' '"GLC I'"' "' ,, Survey Data Surv. No. 18 1 9 Depth (MD) 3649 4000 Angle 49.5 49.8 Direction !91.3 91.3 ,, T.V.D. 3216 3443 Vert. Sec. 1'262 1530 North/South-22'73 -28.80 East/West 162 1529 r)og Leg 1.08 .09 , , Mud Lo,q Data D~l~th Mud Wt. Formation i BG gas Conn gas Trip gas PPg U U u ,, Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/Sand Time Ooeration Prob Code Hrs, Operations From 0600tO 0600 . , , ~ , , , Prudhoe Bay Drilling '"'% ! Drilling Report · ., I 2/2 2/9 2 .,d/Est: pv. Init: Well' AGI-3 ' Depth (MD/TVD): 4656 / 3875 IPrey (MD): 4070 !Pr°gress: 586 I Contractor: Audi2 Phone- 4605 [ Daily Costs: $159,118.00 IEst cum c°sts: $632,599.00 ILast Csg: 13-3/8" @4060' INext Csg: 9-5/8" lShoe 12.6 Operation at 0600: D R i L L I N G I(size/depth)i (size) ITest: Rig Accept (hr/date): 12/17/92 @ 0900 I Rig Release( hr/date): Mud )ata Bit ;)ara Drilling Data Rot Mud TypeLSND MBT 12.5 Bit No. 2 Depth 46.56 Wt. 110 Weight 8.9 IPH 1 2.0 Size 12.25" P.U. 150 S.C. 95 ppg Wt, Wt. Viscosity 37 Pm 2.5 Make SMITH Avg. 40 Max sec Drag Drao PV/YP 5 / 11 Pf 1.0 Type MFDSH+CEL Trq Trq- Btm Off Gels 8 / 13 Mf 1.3 Serial No. NC4040 Pt:mo Data Pump No. 1 2 Depth Out APl W.L. Chlorides 1400 ppm MDfTVD / / / Liner Size 5.5" 5.5" , HTHP Oil 0 Footage 586 100 esi % ft. ft ft. SPM 115 115 HTHP ©WR 0 / 95 ART/AST 3.3 / / / 500 esi GPM 406 406 ES RPM 60 90 SoliSs 5.0 % Table/Mtr / rprr / rpm / rprr Pressure 3300 LGS WOB 3O 35 Sand TR % 3.5 Min/Max. / Slow Pump Data Hole Pit Vol. 500.0 12 14 14 33 V°1'596.0 bbl Jets/TFA Slow P.S. Filter 3 Calcium Bit Costs $8927.00 Cake ppm $2,324.00 $19174.00 Grade BHA Description: BIT ~2, 9-5/8" 1' DYNADRILL, XO, NM STAB, NMLC, MS AB MWD, NMSTAB, 3 NMDC, STAB, JARS, XO, 30 HW. BHAN°: 3 IBHALengtn: 1118.29' IDate Last Inspected' IH°urs On Jars: 103 Iniection Data Source: AGI-3 Volume: 1754 Type Fluid: MUD Injection AGI-2 IRate: 3 IPressure: Well:! [IpmI psi " 30 DIESEL Daily 1784 i Cumulative 1784 Volume: bbl~ Volume: Freeze Protect Fluid: DIESEL Volume: 30 BBL gal Fu~I & Water Data Fuel 6880 Fuel BP IFuel 10012.00 IDr'. water 2650 IDrl' water Used: gal Source' ! Recv'd: galI Used: BBL~ Source: VERN ~uttin,qs Data Weather Data Daily: 78YD cFtCUmulative:1590 YDc4St°rage Personnel & ~afetv/BOP Data Accident?(Y/N): N IName: ]Employer: IRptFiled?(Y/N): PB Drlg: 11 Contractor: 24 IService' 9 IOther: 8 ITM 42 Last BOPE Test: 12/21/92 Last BOP Drill: Last H2S Drill: Last Fire Drill: Last Safety Mtg: 12/17/92 Last Spill Drill: Spill (Y/N)? Volume (Gals.): type Spill: Report Filed? Time Ooeration !Prob Code Hrs. Or)orations From 0600 to 0600 0600-0700 CASG 1.00 L/D CASG TOOLS & LANDING JT. CLEARED FLOOR. 0700-0900 CASG 2.00 N/D 20" RISER & PREPPED FOR TOP JOB. 0900-1030 CASG 1.50 PUMPED 108 SX CLASS"C" 15.6PPG = 18 BBLTOPJOB. 1030-1330 CASG 3.00 N/U FMC SPLIT SPEED HEAD. 1330-1545 'BOPE 2.25 N/U 13-5/8" BOP'S. 1545-1715 BOPE 1.50 TESTED BOPS. WITNESS WAIVED BY MR. HERRING (AOGCC). 1715-1945 TRIP 2.50 INSTALLED WEAR RING, & P/U BHA #3. ORIENTED MWD & MOTOR. 1945-2015 RIGS 0.50 RIG SERVICE. 2015-2145 TRIP 1.50 TIH. TAGGED @ 3980'. 2145-2215 CIRC 0.50 CIRC. 2215-2300 CASG 0.75 TESTED CASG 3000 PSI. GOOD TEST. 2300-2345 CASG 0.75 DRILLED FLOAT COLLAR & CEMENT TO 4053" 2345-2400 CASG 0.25 TESTED CASG 10 MINUTES. GOOD TEST. Prudhoe Bay Drillin~ i~:, ,, "-"~. Ds, ily Drilling Report 'A~:E. No: 4J01 pt. No: 5, iii .Jato: 12/22/92 Well Name: ALii-3 Supv. Init: Page 2 Survey Data Surv. No. 20 21 Depth(MD) 4211 4460 Angle 48.1 48.9 Direction 91.3 91.0 T.V.D. 3581 i3746 Vert. Sec. 11689 i1876 North/South -32 -36 , East/West 1689 1876 Dog Leg 81 .33 Mud Loci, Data Depth Mud Wt. Formation BG gas Conn gas Trip gas ~ u ~ u Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/SandCASG L fph fph Time Ooetation Prob Code Hrs. Operations From 0600 to 06(,0 2400-0030 CASG .5 DRILLED CEMENT, FLOAT SHOE, RATHOLE & 10' NEW FORM TO 4080'. 0030-0130 CIRC 1 CIRC. 0130-0145 EVAL .25 LOT. 8.9 PPG MUD WT + 675 PSI @ 3482' TVD =12.6 PPG EMW. 0145-0600 DRIL 4.25 DRILLED FROM 4080' TO 4656' MD. Prudhoe Bay Drilling AFB. No: 4J0194 ]Rpt. No: : !" IDate:- , We,: AGI-3 Depth (MD/TVD): I 2/23/92 IDays Sinc~ ,.,p..,/Est: 6 Daily Drilling Report IS'upv. Init: . .. I SRWalls 6500 / 5107 IPrev(MD): 4656 IPr°gress: 1844 Contractor: Audi 2 Phone: 4605 Operation at 0600: D r i I I i n g Rig Accept (hr/date): 12/17/92 @ 0900 '" Mud :~'ata J Daily Costs: $67,926.00 JEst Cum Costs: $700,525.00 ILast Csg: 13.3/8-@ 4060, 1 Next Csg: 9-5/8" IShoe 12.6 /size/depth) (size) ITest: IRig Release( hr/date): Bit )ata Mud Typet_SND Weight 9.2 Viscosity 43 MBT 17.5 HTHP 100 psi HTHP 500 So;iSs 6.0 .% Sand 0.125 % H°le V°1'834-0 bt 10.6 Pm Bit No. Size LGS 6.4 Pit Vol. 65.0.0 Make PV/YP 10 / 7 Pf 0.2 Type Gels 7 / 28 !Mf 0.6 Serial No. Chlorides Depth Out APl W.L. 8.8 1000 ppm MD/I-VD Oil 0 % Footage OWR ART/AST / ES RPM Table/Mtr WeB Min/Max, Filter 1 Cake Daily Mud $ $5,1 O3.OO Calcium tr ppm Total Mud $ $24275.00 Jets/TFA Bit Costs Dull Grade 12.25" SMITH MFDSH+CEL NC4040 / / / 2440 ft. ft ft. 10.0 2.0 / / / 90 150 / rprr / rpm / rprr 30 / 55 KC / Kc / Kc 12 14 14 23 $8927.00 Drillino Data Depth -I Rot 6030 IWt 125 P'U 8 '' 10 I'' 100 Wt, Iwt. Avg. 55 Drao Trq- 400 Btm , Pt Pump No. Liner Size SPM GPM Pressure IMax 80 I Dra_a Trq 3 00 Off mo Data 115 I 115 1406 380O BHA Description: BIT #2, 9-5/8" I°BH F2000, XO, NM STAB, NMLC, NMSTAB, MWD, NMSTAB, 3 NMDC, STAB, JARS, XO, Slow pump Data I, 30! 45 Slow P.P. ~ BHA No: 3 IBHA Length: 1118.29' IDate Last Inspected: 12/4/92 I H°urs On Jars: 105.75 Source' Volume: Type Fluid: Iniection Data Injection Well: Daily Volume: AGI-2 Freeze Protect Fluid: IRate: }Pressure: ~pml ICumulative bbl Volume: Volume: gal psi , Fuel 6509 I Fuel Used: gal[Source: B P L;uttinqs Data Daily: F~CUmulative: /St°rage c CFl~ite: iAEs'ident? (Y/N)' N IName: PB Drlg: 1 I Contractor: Last BOPE Test: 12/21/92 Last Spill Drill: 24 ILast BOP Drill: Spill (Y/N)? N Fuel & Water IFuel 10021.00 IDrl. Water Recv'd: gal Used: -24 oFIWind Speed: Personnel & Safety/BOP Data JEmpl~3yer: 12 IService' JOther: 5 lyaSt Fire Drill: pe Spill: 1 550 I Drl. Water BBL[ Source: Weather Data 21 mphll Chill Factor: ILast H2S Drill: Volume (Gals.): Rpt Filed? (Y/N): VERN -78 Tctal: 42 Last Safety Mtg: 12/22/92 Report Filed? 0600-0745 drill 0 745-0915 prob efc 0915-1000 drill 1000-1215 prob efc 1215-2100 drill Operations From 0600 to 0600 Drilling to 4907. Check sudace system for loss of pressure. Drilling 4907-4938. POOH looking for washout-found it in slip area 23 stds down. RIH. · Drilling 4938-6030. PumPed around hi-vis sweep before shod trip. 2100-2115 circ Circ. OF¸ 2115-0100 trip 0100-0200 drill 0200-0300 prob th 0300-0600 drill 15-std shod trip. Swabbed entire time-filled through dp. Tight getting to bottom. Drilling 6030-6118. Pumped SAPP & nut plug pills. Gumbo attack @ sudace. Drilling. Out of clays, into sands now. Planning a 20-std shod trip after another 1000' of hole or so have been made. Prudhoe Bay Drillin( ', ,"-'" ,, Daily Drillina Report 'Ai:E. No: 4J0194 6, iii' ,~tte: Well Name: Supv. Init: S-RWalls Page 2 ! 12/23/92 AL~,-3 Survey Data Surv. No. 22 23 24 25 26 27 28 Depth (MD) 4711 4962 5211 546( 571~ 596 ) 621 1 At, gte 47.2 47.8 48.8 48.2 48.1 48.3 48.7 Direction 90.6 91.00 91.7 92.4 92.4 89.6 89.2 T.V.D. 3914 4084 4249 4414 4581 4748 4914 ,, Vert. Sec. 2062 2247 2433 2620 2806 2992 3180 North/Soutf S 39 S 41 S 46 S 52 S 60 S 63 S 61 East/West E 2062 E 2247 E 2433 E 2619 E 2805 E 2992 E 3180 Dog Leg 0.69 0.27 0.45 0.32 0.04 0.84 0.20 Mud Lo.q Data Depth Mud Wt. Formation BG gas Oonn gas trip gas ppg u' L U Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/Sand 'Time Operation Prob Code Hrs. Operations From 0600 to 0600 , , : Prudh Drilling "-", . ilsY Drilling Report i'~FE. No: 4~J0194 Rpt. No: ~i i,~ Date: I 2/24/92 Days SinCe. , .J/Est: 7 S"up~. Init: SRWalls Well: AGI-3 Depth (MD/TVD): 8080 / 6120 IPrev (MD): 6500 [Progress: 1580 I I Contractor: Audi 2 Phone: 4605 J Daily Costs: $69,181.00 lEst Cum Costs' $769,706.00 ILast Csg: 13-3/8"@4o60' INext CSg: 9-5/8" IShoe 12.6 '~peration at 0600: D r i I I i n g I(size/depth), (size) . ITest: "l~ig Accept (hr/date):' 12/17/92 @ 0900 Rig Release( hr/date): ,, , Mud ')ata Bit :)ata Drilling Data Rot MudTypeLSLD MBT 22.5 Bit No. 2 Depth 7678 Wt. 140 Weight 9.3 pH 9.0 Size 12.25" P.U. 240 S.C. 1 PI~ Wt. Wt. ~/iscosity 43 pm 0.3 Make SMITH Avg. 100 Max 200 sec Drao Drao PV/YP 10 / 9 Pf 0 I Type MFDSH+CEL Trq- 400 Trq- 400 ' Btm Off Gels 5 / 22 Mf 0.4 Serial No. NC4040 Pt~'no Data Pump No. 1 2 ,,,,, APl W.L. Chlorides Depth Out 7.6 1500 , ppm MD/TVD / / / Liner Size 5.5" 5.5" '[:-ITH P" Oil 0 Footage 4020 ,100 esi % ft. tt . ft. SPM 115 115 HTHP OWR ART/AST 20.0 3.0 500 esi / / / / GPM 406 406 ES RPM 9O 150 Solias 7.0 '"% Table/Mtr / rprr / rprn / rprr .... Pressure 3900 LGS WeB 'Sand tr % 7.2 30 55 Min/Max. / F¢ / ~ / F¢ Sl(~w Pump,,, Data Pit Vol. Hole Vol1093.0 bbl 630.0 Jets/TFA 12 14.14 Slow P.S. 30 45 Filter Calcium Bi't Costs Cake 1 40 ppm $8927.00 $4,731.00 $29005.00 Grade !!1 II !1 : BHA Description: BIT #2, 9-5/8" 1°DH F2000, XO, NM STAB, NMLC,'NMSTAB, MWD, NMSTAB, 3 NMDC, STAB, JARS, XO, BHAN°: 3 IBHALength: 1118.29' IDate Last Inspected: 12/4/92 I H°urs On Oars: 116.5 Iniection Data Source: AGI-3 Volume: 140 Type Fluid: Mud Injection AGI-2 IRate: 3 IPressure: 800 Well:J ~pmI ,psi Daily 144 Cumulative 19 24 Volume: bbl Volume: Freeze Protect Fluid' Diesel Volume: 420 gal i=uel & Wate~ Data i=uel 7770 Fuel BP !Fuel I Drl. Water 875 I Drl. Water USed: gal Source' IRecv'd' ,,,, galI, Usedi' ' BBL~ Source: VERN ;uttin,qs Data Weather Data Daily: oFIC~mulative: 04Storage~;ite: Temp: _33 cFIwind Speed: 11 mphIChill Factor: .68 oF Personnel & Si~fetv/BOP Data ,, i ' last BOPE Test: 12/21/92 Last BOP Drill: Last H2S Drill: LaSt Fire Drill: Last Safety Mtg: 12/22/92 Last Spill Drill: Spill (Y/N)? N Volume (Galsl): lype Spill: ' Report Filed? Tim~. Operation Prob Code Hrs. Op~ratioqs From 0600 tQ 0600 , 0600-1715 drill 11.25 Drilling to 7533. 1715-1730 circ 0.25 Circulate. 1730-2115 trip 3.75 16-std short trip. Swabbed every stand while POOH. Filled hole through dp; overpull were not escessive, but hole wouldn't fill. Had to push pipe back in hole 1st two std's; then bali broke off of BHA & pipe went back to bottom freely with no drag. 2115-0600 drill 8.75 Drilling. ,, Prudhoe Bay Ddllin .. ,, Daily Drillinq Report 'A~-~I~T"' --" ..... ~pt. No: ;i iii'Sate: WellName: ' Supv, Initi SRWalIs Page2 4J01 7 ! 12/24/92 ~1-3 Survey Data Surv. No, 29 30 31 32 33 34 35 Depth (MD) 6462 6711 6960 7201 746: 771 :) 79(~ 1 Angle 48,8 48,9 49,5 49,9 49.1 49,0 49,0 Direction 88,9 89,6 90,6 91,7 93,5 91,0 90,3 T.V,D, 5080 5244 5407 5562 5733 5896 6059 Vert, Sec, 3369 3556 3744 3928 4127 4315 4503 North/Soutl' S 58 iS 56 S 56 S 60 S 69 S 76 S 78 East/West E 3368 :E 2556 E 3744 E 3928 E 4127 E 4315 E 4502 Dog Leg 0.1 0.21 0.41 0.39 0.61 0.76 0.21 Mud Lo.q Data Depth Mud Wt. Formation BG gas Conn gas l'rip gas ppg u L U Max BGG Dc Exponent Shale density Est, pore press ROP/Shale ROP/Sand U fph fph Time Ooeration Prob Code Hrs. Operations From 0600 to 0600 , · , , Prudho¢ Bay Drilling AFE. No: 4J0194 Well: 'oonifbcior: IRpt' N°: o IDate: Depth (MD/TVD): AGI-3 Audi 2 Phone: 4605 Operation at 0600: D r i I I i n g Rig Accept (hr/date): 12/17/92 @ 0900 "' Mad Mud TypeLSLD Weight 9.4 Viscosity 42 se~ PV/YP 9 / 9 Gels 5 6 / APl W.L. 6.0 HTHP 100 HTHP 500 esi SoliSs 7.5 % ... Sand tr % Hole V°I1- 172.0 bbl )ata ' MBT 22.5 pH 9.0 ~m Pf 0.1 Mf 0.6 Chlorides 1700 ppr~ Oil 0 % Bit No. Size Make Type Serial No. Depth Out MD/TVD Footage I 2 / 2 5 / 9 2 I Days Since o~..~d/Est: I 8587 / 6466 IPrev (MD): I IDaily Costs: $94,873.00 ILast Csg: 13-3/8"@4060' Next Csg: (si,ze/depth) l(size) I Rig Release( hr/date): Bit )a'~ , 2 3 12.25" 12.250 SMITH HTC Filter 1 6;ake Daily Mud $ $8,598.OO MFDSH+CEL NC4040 ATJC P11H T00PX 8408 / 6350 / / 1 79 4338 OWR ART/AST 22.0 2.5 5.0 / / / / ES 90 / RPM Table[Mtr WeB Min/Max. 150 rprr LGS 7.5 Pit Vol. 670.0 80 150 / rpm Jets/TFA Calcium 60 ppmlBit Costs I Total Mud $ ~ Dull $37604.00 IGrade / rprr 30 / 55 K~ 35 / 50 K~ / I~ 12 14 14 22 15 15 12 $8927.00 I $11790.00I I I I I I I I' Daily Drilling Report /Supv. Init: '... 8 .! SRWalls 8080 !Pr°gross: 507 JEst Cum Costs: $864,579.00 9-5/8' IShoe ., ITest: 12.6 Drillina Depth 8408 P.U. 240 Wt_ Avg. 90 Draa Trq- 600 Btm P~ Pump No. Liner Size SPM GPM Pressure Data Rot Wt. 150 S.O.' 115 Wt. Max 150 Draa Trq 500 Off mo Data 5.5"I 5.5" ; 100I 100 '353I 353 3500 Slow Pump Data II BHA Description: Bit, I°BH F2000, NM Stab, NMLC, NM Stab, MWD, NM Stab, 3xNMDC, stab, jars, xo, 15 HWDP Source: Volume: Type Fluid: Injection Data Injection Well: Daily Volume: AGI-2 Freeze Protect Fluid: IRate: IPressure: . cjpml I Cumulative bbl Volume: Volume: gal 124.25 psi 1924 Fuel I Fuel Used: gal[source: BP OuttinqS Data Daily: oF~umulative: Accident? (Y/N): ' N IName: PB Drlg: 1 ! Contractor: Fuel & Water Data IFuel 10000.00 [ Drl. Water Recv'd: gal Used: Last BOPE Test: 12/21/92 Last BOP Drill: 12/25/92 Last Spill Drill: Spill (Y/N)? N 0600-1200 drill Wind Speed: ~Storage emp: -38 oF C~Site: Personnel &.Safety/BOP Data IEmployer: 24 IService: 118 IOther: 5 I Last H2S Drill: ILast Fire Drill: Volume (Gals.): F~,pe Spill: O.oerations From 0600 tO 0600 I Drl. Water BBL Source: Weather Data VERN 6 mP4 Chill Factor: -54 Rpt Filed? (Y/N): Total: 148 Last Safety Mtg' 12/22/92 Report Filed? *F Drilling to 8408. Bit quit drilling. Had launched hi-vis sweep when bit slowed down. 1200-1215 circ Finish circ hi-vis sweep around. POOH w. bit #2; L/D 15 jt's HWDP to reduce pump pressure. Changed out MWD's (picked up DPR t001), loaded, tested, RIH w. HWDP. Bit was 3/8" OOG. Slip & cut drilling line & service rig. RIH to 8279 & p/u dp to replace L/D HWDP. Reaming to bottom. Drilling; steady ReP @ report time steady @ 40'/hr. 1215-1830 trip 1830-1930 rigs . 1930-2200 trip 2200-2300 drill 2300-0600 drill Prudho¢ Bay Ddllin~ ~ ?"~ Daily Drillinq Report ,, Survey Data Surv. No. 36 37 Depth (MD) 8212 8456 , Angle 49.7 49.7 Direction 89.9 92.4 ,, T.V.D. 6223 6381 Vert. Sec. 4693 4879 , North/Soutl' S 79 S 83 East/West iE 4693 E 4879 iDog Leg 0.3 0.78 Mud Lo.q Data Depth Mud Wt. Formation BG gas Conn gas l'rip;"gas PPg U L U Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/Sand Time IO~erati°n Prob Code Hrs. Operations From 0600 to 0600 , ,, ,, ,,, ,,,. , · ,,, ,,,,,,. · .. . · .... ,, ,,, , ,,. Prudhoe Bay Drilling :, ! Drillinq Re.oort , 'Ai:E. No: 4~J0194 Rpt. No: ' !,,., I 2/26/92 _,d/Est: S~upv. '-' Well: AGI-3 Depth (MD/TVD): 9170 / 6834 JPrev (MD): 8587 JPr°gress: 583 I I Contractor: Audi 2 Phone: 4605 J Daily Costs: $74,794.00 JEst Cum Costs: $967,906.00 I I JLast Csg: 13-3/8"@4060' JNext Csg' 9-5/8" JShoe 12.6 Operation at 0600: D r il Ii n g I(size/depth) i (size) . ITest: Rig Accept (hr/date): 12/17/92 @ 0900 Rig Release( hr/date): Mud )ata Bit )ata Drillina Data Rot Mud TypeLSLD MBT 22.5 Bit No. 3 Depth 9074 Wt. 160 Weight 9.5 pH 9.5 Size 12.250 P.D. 250 S.O. 120 PP~ Wt, Wt. Viscosity 42 Pm 0.3 Make HTC Avg. 90 Max 130 sec Dm_o Dina_ PV/YP 11 / 12 Pf 0.2 Type ATJCP11H Trq 460 Trq 400 Btm off Gels 5 / 10 Mf 0.6 SeriaINo. T00PX Pum~D~t~ Pump No. 1 2 APl W.L. Chlorides Depth Out 6.0 1450 ppm MDf]-VD / / / Liner Size 5.5" 5.5" HTHP 19.6 Oil 0 Footage 762 !00 .psi % ft. ft ft. SPM 108 108 HTHP OWR ART/AST 26.5 5oo psi / / / / GPM 381 381 ES RPM Solids 8.5 % Table/Mtr / rpn 80 / 150 rpm / rprr LGS WeB Pressure 3800 Sand tr % ~ 8.7 Min/Max. / Ktt 35 / 50 K~ / K~ Pi~' Vol. Slow Pump Data Hole Vol1262.0 bbl 650.0 Jets/TFA 22151512 Slow P.S. 30 45 Filter 1/2 Calcium 40 ppm Bit Costs $11790.00 Cake $7,304.00 $44908.00 Grade BHA Description: Bit, 1 °DH F2000, NM Stab, NMLC, NM Stab, MWD, NM Stab, 3xNMDC, stab, jars, xo, 15 HWDP BHA No: 3 IBHA Length: 676.72 IDate Last Inspected' 12/4/92 IH°urs °n Jars: 144.75 Iniection Data Source: AGI-3 Volume: 106 Type Fluid: Mud Injection AGI-2 IRate: 2 IPressure' 800 W~II;I ~ipmI psi j Daily 106 I Cumulative 2030 [Volume: bblI Volume: Freeze Protect Fluid: Diesel Volume: 840 gal Fu~I ~ Water Data Fuel 4690 IFuel !Fuel ' IDrl' water IDrl' water Used: gal[Source: BP 10001.00 875 VERN lRecv'd: gal Used: BBL Source: Guttings Data Weather Data Daily: Cl~umulative: c~St°rage~it~; romp: _35 OFIwind Speed: I mpl~Chill Factor: .35 oF Personnel & Safety/BOP Data Accident?(Y/N): N IName: IEmp,oye~: JRptFiled?(Y/N): PB Drlg: I I Contractor: 24 IService: 18 !other: 5 Total: 48 Last DOPE Test: 12/21/92 Last BOP Drill: 12/25/92 Last H2S Drill: Last Fire Drill: Last Safety Mtg: 12/22/92 Last Spill Drill: Spill (Y/N)? N Volume (Gals.): Type Spill: Report Filed? Time Oaeration Prob Code Hrs. Ooerations From 0600 to 0600 0600-0600 drill 24.00 Drilling. (0.5 hr repair #2 mud pump). Teleco resistivity tool died; GR still working. Planning a trip today to remedy slow ReP; will replace MWD while OOH. Believe bit could be pinched. , , · , Prudhoe Bay Ddllin~ ~ \ , '~'", Daily Drillir g Report 'A~:E. No: 4J01 pt. No: § i .~'ate: Well Name: Supv. Init~ SRWalls Page 2 I 12/26/92 · ALII-3 Survey Data Surv. No. 38 39 Depth (MD) 8710 9020 Angle 50.3 51.2 Direction 91.3 93.1 T.V.D. 6544 6740 Vert. Sec. 5074 5314 North/South S 89 S 98 . East/West E 5073 E 5313 Dog Leg 0.41 0.54 Mud Lo,q Data Depth Mud Wt. Formation BG gas Conn gas l'rip gas PPg U L U Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/Sand U fPh ~ . ' Time [Ooeration Prob Code Hrs. Operations From 0600to 0600 · .. , ... , Prudh0e Bay Drilling / D? ilsY Drilling Reoort. Well: AGI-3 iOepth(MD/TVD): 9525 / 7052 IPrev(MD): 9170 IPr°gross: 355 I Contractor: Audi2 Phone: 4605 I Daily Costs: $75,657.00 lEst Cum Costs: $1,043,563.00 I ILast Csg: 13-,3/8" @ 4o60' ! Next Csg: 9-5'8" ISh°e 12.6 ppg Operation at 0600: D ri lli n g l(size/depth), (size) ITest: Rig Accept (hr/date): 12/17/92 @ 0900 I Rig Release( hr/date): I , Mud ')ate Bit r)ata Drillina Data Rot Mud TypeLSLD MBT 20.0 Bit No. RR4 3 Depth 9438 1 60 Wt. Weight 9.5 pH 9.2 Size 12 25" 12.250 P.U. 260 S.O. 120 ppcj · ,i Wt, Wt. Viscosity 43 Pm 0.3 Make Smith HTC Avg. 100 Max 140 sec Drn~ Drn~ PV/YP 10 / 12 Pf 0 I iType S856KP ATJCP11H Trq- 600 Trq- 500 ' Btm Off PL m~3 Data Gels 5 / 9 Mf 0.5 iSerial No. JQ2486 T00PX ,J Pump No. 1 2 DepthOut 9194 / 6800 APl W.L. 6.0 Chlodcles I 100 ppm MD/TVD / / Liner Size 5.5" 5.5" ~HTHP 19.2 Oil 0 Footage 331 794 100 .psi % lt. ft ft.SPM 102 102 HTHP DWR ART/AST 27.5 500 psi / / / / GPM 360 360 ES RPM 100 150 80 150 Solids · 8.5 .% Table/Mtr / rprr / rpm / rprr Pressure 3600 LGS WeB 8 15 35 50 Sand tr % 8.5 Min/Max. / Slow Pump Data Pit Vol. 725 0 15 15 15151414 122151512 Hole Vol1314.0 bbl · Jets/'rFA Slow P.S. 30 45 FiJter 1/2 Calcium 40 ppm Bit Costs $11790.00 ,Cake $7,107.00 $52015.00 Grade E I NO :BHA Description: Bit,lOBH F2000, xo, NM Stab, NMLC, NMStab, NMLC, MWD, NMStab, 3xNMDC, stab, jars, xo, 15 HWDP BHA No: 4 IBHA Length: 676.31 IDate Last 'nspected: 12/4/92 IH°urs On Jars: 157.75 Iniection Data Source: AGl-3vb Volume: 163 Type Fluid: Mud Injection AGI-2 IRate: 2.0 IPressure: 850 Well;I ~lpmI psi Daily 163 Cumulative 2193 Volume: bbl Volume: Freeze Protect Fluid' Diesel Volume: 630 gal Fuel & Water D~ta Used: g~!jSource: Recv'd' gal Used: BBL Source: VERN CUttings Data Weather Data Daily: CFlCUmulative:CFl~ita;.-IStC'rage Temp: _90FITM Speed: 16 mphIChill Factor: .48 oF Personnel & Safety/BOP Data Accident? (Y/N): y IName: Vance Dale iEmpl°yer: Audi IRpt Filed? (Y/N): Y PB Drlg: 11 Contractor: 24 IService: 18 Last BOPE Test: 12/21/92 ILast BOP Drill' 12/25/92 Last H2S Drill: Last Fire Drill: 12/26/92 Last Safety Mtg' 12/22/92 Last Spill Drill: Spill (Y/N)? N Volume (Gals.): 'i'ype Spill: Report Filed? Time Ooeration Prob Code Hrs. Operations From 0600to 0§00 0600-0730 drill 1.50 Drilling; ReP for last 3 hrs <20 fph. MWD resistivity tool had failed also. 0730-1600 trip 8.50 POOH, change bit & MWD, RIH. (0.5 hr rig service). Bit was completely undamaged. 1600-0600 drill 14.00 Drilling w. PDC - initial ReP 40 fph. Continues to build angle, however, and these bits cannot be steered with full stabilization, regardless of salesmen's claims. Last few hrs tried to slide and cannot. If assembly does not begin to drop slightly, will have to POOH & switch to roller bit so it can be steered. Hole began taking seepage losses. , , @ 0300; have lost 50 bbl's since then. Prudh0e Bay Drillin( ~ ... ~ D~,ily Drilling Report iAFE. Noi 4J0194 ]5,pt. No: l't, ii' ~"~te: 12/27/92 Well Name: ,,~,-3 Supv. lint: SRWalls Page2 I Survey Data Surv. No. 40 Depth (MD) 9296 Angle 52 ,,,,, Direction 92.00 T.V.D. 6911 Vert. Sec. 5530 North/South S 108 East/West E 5529 ,,, Dog Leg 0". 43 Mud Lo.q Data Depth Mud Wt. Formation iBG gas Conn gas ]'rip gas PPg U U U Max BGG Dc Exponent Shale density lEst. pore press ROP/Shale ROP/Sand t. f¢l fph Time Operation Prob Code Hrs_ Operations From 0600 to 06C 3 .. , , , ~ , Prudhoe Bay Drilling AFE. No: 4J0194 Well: JDate' Depth (MD/TVD): AGI-3 Contractor: Audi 2 Phone: 4605 Operation at 0600: D r i i I i n g Rig Accept (hr/date): 12/17/92 @ 0900 Mud l Mud TypeLSLD Weight 9.4 Viscosity 43 se( PV/YP 9 / 13 APl W.L. 6.0 )ara MBT 20.0 pH 9.0 Pm 0.3 Pf 0.1 Bit No. Size Make Type Chlorides 850 ppm I 2/28/92 IDays Sin(,. -,~..,/Est: ! 9787 / 7209 IPrev(MD): IDaily Costs: $71,490.00 ILast Csg: 13-3/8" @ 4060' Next Csg: (size/depth) l(size) I Rig Release( hr/date): Bit ;)ata RR4 12.25" Smith 12.250 Smith S856KP MFDSHCEL Gels 5 / 10 Mf 0.6 :Serial No. JQ2486 NC6340 / 7.5 % HTHP 100 psi HTHP 5o0 psi Solids 9649 / Oil Depth Out MDfTVD Footage 140 17.6 0 % 535 ft. ft. OWR ART/AST 13.0 2.0 5.0 / / / / ES / RPM Table/Mtr WeB Min/Max. JetsFFFA LGS Sand tr % 7.6 Pit VoI. 700.0 Hole ye,l/350.0 bb~ Calcium 40 ppm Filter Cake 1/2 Daily Mud $ $10,780.00 Total Mud $ $62795.00 100 150 / 80 150 / rpm Bit Costs Dull Grade rprr rpm 8 / 15 KC 15 / 35 F¢ / KC 15 15 15 15 14 14 22 15 15 12 $8927.00 Da, ily Drilling Report /Supv. Init: __ .. 11 ! SRWaLIs 9525 IPr°gross: 262 IEst Cum Costs: $1,115,053.00 9-5/8" IShoe 12.6 PPg - ~'lTp,_,t' Orillir~n Depth 9680- P.U. 260 Wt. Avg. 95 Drao Trq 460 Btm Pi Pump No. Liner Size SPM GPM Pressure Data Rot 165 Wt. S.O. 120 Wt. Max 140 Drag Trq 520 Off mo Data '1 I 2 I 9°! 90 318I 31.8. 3600 Slow Pump Data BHA Description: Bit,lOBH F2000, xo, NM Stab, NMLC, NMStab, NMLC, MWD, NMStab, 3xNMDC, stab, jars, xo, 15 HWDP BHA No: 6 !BHA Length: 676.06 IDate Last Inspected: 12/4/92 IH°urs On Jars: Source' AGI-3 Volume: 386 Type Fluid: Injection Data Mud Injection Well; Daily Volume: AGI-2 386 Freeze Protect Fluid' Volume: 1722 IRate:2.0 IPressure: ~lpml ICumulative Volume: Diesel Fuel 8952 I Fuel Used: gal[Source' BP Cuttinqs Data Daily: CF~Cumulative: CI Accident? (Y/N): N IName: PB Drlg: 1 ! Contractor: Fuel & Water Data JFuel 1004..00 Recv'd' . I Drl. Water gal Used: 24 gal Storage -8 oFIWind Speed: Personnel & Safety/BOP Data IEmpl~yer: IService: 18 Iother: 5 1 66 725 psi 2579 Last BOPE Test: 12/21/92 ILast BOP Drill: 12/27/92 Last Spill Drill: ISpill (Y/N)? N 1150 I Drl. Water BBLI Source: VERN Weather Data Chill Factor: -31 9 mp °F Rpt Filed? (Y/N): Total: 48 Last Safety Mtg: 12/27/92 Report Filed? Last H2S Drill: ;Volume (Gals.): l ast Fire Drill: 12/26/92 ype Spill: 0600-1330 drill 1330-1400 circ Drilling. Could not slide bit; could not stop build & make any kind of REP.. Projected to miss targetunless corrected. Circ. POOH, change bit & drop stab on bottom of motor for 11-1/4" sleeve. Download & re-test MWD & RIH (take checkshots & fill pipe while RIH). (trip includes 1/2 hr rig sew). Wash & ream to bottom. Drilling. 1400-2200 trip 2200-2215 dFill 2215-0600 drill Daily Drilling RePOrt Prudhoe Bay Dfillin i '~ i!i '; '~ , ' -AF~.'-No~' - -4~01;4 ..... f~pt. No: 1'~1'''' .~ate: 12/28/92 WellName: A~,,-3 Supv. Ini,~ Page2 Survey Data Surv. No. 41 Depth (MD) 9576 ~5'3.0 Angle Direction 91.7 T.V.D. 7082 Vert. Sec. 5752 North/Sout[ S 115 East/West E 5751 Dog Leg 0.3 7 Mud Log Data Depth Mud Wt. Formation BG gas Conn gas ]'rip gas PPg U U U Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/Sand Time Ooeration Prob Code Hrs. OPerations From 0600 to 0660 Weekly trucking requirements: Monday: Water, bed, guzzler (2). Tuesday: water, fuel, 2 guzzlers, bed. Wednesday: Water, 2 guzzlers, 6 vac trucks. Thursday: Water, fuel, 4 guzzlers, 2 vac trucks, bed truck. Friday: Water, fuel, 4 guzzlers, bed truck. Saturday: Water, 3 guzzlers, 2 vac trucks. Sunday: Water, fuel, 3 guzzlers, bed truck. Monday: Water, 3 guzzlers, bed truck. · . , , .. . , Prudh0e Bay Drilling ~, "'"'",, · D~,ilsY Drillina Re~rt ·-- I 2/29/9 2 '-. 1 2 S~.'H~/.~ Well: AGI-3 Depth(UDrrVD):10303/ 7585 IPrev(UD): 9787 IPr°gress: 516 I ! Contractor: Audi2 Phone' 4605 IDaily C°sts: $74,865.00 IEst Cum C°sts: $1,189,918.00 & ILast Csg: 13-,.'.'.'.'.'.'.'.'.~8" @ 4060' ! Next Csg: 9-5/8" IShoe 12.6 ppg Operation at 0600: P O O H I(size/depth)~ (size) ITest: "R'i'g Accept (hr/date): 12/17/92 @ 0900 I Rig Release( hr/date): I Mud ')ata Bit 3ata Drilling Data MU · Rot , d TypeLSLD MBT 22.5 Bit No. 5 Depth10198 Wt. 170 Weight 9.4 pH 9.1 Size 12.250 P.U. 270 S.C. 125 PPg Wt. . Wt. Viscosity 41 Pm 0.3 Make Smith Avg. 100 Max 150 sec Drao Drao !PV/YP 10 / 19 Pf 0.1 Type MFDSHCEL Trq- 500 Trq- 500 Btm Off P[rmo Data iGels_ 6 / 11 IMf 0.7 Serial No. NC6340 Pump No. 1 2 Chlorides Depth Out 10303 / 7585 APl W.L. 6.0 600 ppm MD,ri'vD / / Liner Size 5.5" 5.5" :HTHP 17.6 Oil 0 Footage 654 100 psi % ft. ft ft. SPM 100 100 HTHP DWR ART/AST 27.0 500 osi / / / / GPM 353 353 ES RPM Soil(is 7.5 % Table/Mtr / rpm 80 / 150 rpm / rprr -. LGS WOB Pressure 3700 Sand tr % 7.6 MiniMax. / ~ 15 / 35 I~ / K~ Slow Pump Data Hole Pit'Vol. 675.0 22151512 Vo, 41 7.0 bbl Jets/TFA Slow P.S. Fi'tter 1/2 Calcium 40 ppm Bit Costs $8927.00 Cake Daily Mud $ Total Mud $ Dull BH^ Description: BiI,lOBH F2000, xo, NM Stab, NMI_G, NMStab, NMt_C, MWD, NMStab, 3xNMDC, stab, iars, xo, 15 HWDP BHANo: 6 BHA Length: 676.06 IDate Last Inspected: 12/4/92 I Hours On Jars: 188 I I Injection Data Source: Volume: Type Fluid: I Injection AGI-2 IRate: IPressure' Well;! ~1 psi Daily I Cumulative 25 79 Volume: bbl[ Volume: Freeze Protect Fluid: i Volume: gal Fuel & Water Data Fuel 6844 IFuel BP IFuel IUd.water 1150 IUd.water Used: gal[Source: ~ Recv'd: gal~ Used: BBLj Source: VERN (Juttings Data Weather Data Daily: CFr;Umulative: c~Storage Temp:7 oFIWind Speed:5 mphJChill Factor: 0 oF _ [iite; .. . Personnel & Safety/BOP Data Accident?(Y/N): N IName: IEmpl°yer:. IRptFiled?(Y/N): PB Drlg: 1J Contractor: 24 [Service' 14 J Other: 5 Total: 44 Last BOPE Test: 12/21/92 Last BOP Drill: 12/27/92 Last H2S Drill: Last Fire Drill: 12/26/92 Last Safety Mtg: 12/27/92 Last Spill Drill' Spill (Y/N)? N Volume (Gals.): Type Spill: Report Filed? Time ODeratic)n .proh Code Hrs. Ooerations From 0600 to 0600 0600-0415 drill 22.25 Drilling. Angle dro'pped @ 1.5-2 °/100'; now projected to fall short of target if allowed to continue. 0415-0600 trip 1.75 POQH to lock up BHA; will test BOP's while CCH. .. , . '~",, Is"p'' Daily Drillinq Report Dfillinq Iweu Name: Init: Prudhoe BaY4J0194 I~Pt. No: Date: AFE. No: " 12/29/92 r,...,,-3 SRWalls i Page2 ! ! I Surv. No. J 41 ! 42 J 43 I 44 ~ 45 JPr°jiurveyDaia I J J ! ! ! Depth(MD, I 9576197661 99451 10,3f 1023~3 10313 I ! I I ! I I '~me Mud Lo,q Data Max BGG IShale density Oper!t~i:PF°rroemPr0e6s0s0 to 06J0ReP/shale I o sa"d ~ Mud Wt. J Dc F:xponent Operation Prob Code . Hr.~_ Prudhoe Bay Drilling Df Drilling Report ,. ¢ Date: I 2~30~9 2 Days Sinc,. , .J/Est: 13 Well: AGI-3 Depth(MD/TVD): 10799 / 7964 IPrev(MD): 10303 IPr°gross' 496 I Contractor: Audi2 Phone' 4605 I Daily Costs: $65,096.00 lEst Cum Costs: $1,255,014.00 I ILast Csg: 13-,3/8" @ 4060' I Next Csg: 9-5/8" IShoe 12.6 ppg Operation at 0600: REPAIRING SHOCK HOSE l(size/depth),(size) ITe.~t: Rig A~ept (hr/date): 12/17/92 @ 0900 Rig Release( hr/date): Mud ~ata Bit ')ate Drillinc~ Data Rot Mud TypeL. SLD MBT 22.5 Bit No. 6RR4 5 Depth10799 ~ Wt. 180 Weight 9.6 pH 9.8 Size 12.25" 12.250 P.U. 310 S.C. 130 PP~ Wt, Wt. Viscosity 42 Pm 0.4 Make Smith Smith Avg. 130 Max sec Drag Drac~ PV/YP 12 / 16 Pf 0.3 Type S856KP MFDSHCEL Trq 650 Trq 500 Btm Off Puree Data Gels 5 / 12 Mf 1.1 Serial No. JQ2486 NC6340 PumpNo. 1 2 Chlorides Depth Out 10303 / 7585 APl W.L 6.0 900 ppm MD/TVD / / Liner Size 5.5" 5.5" HTHP Oil 0 Footage 49 6 654 100 ~)si % ft. ft. ft. SPM 105 105 HTHP DWR 0 / 92 ART/AST 8.0 / 27.0 / / 500 p~i GPM 370 370 ;Solids 8.0 ES RPM 80 150 % Ti~,ble/Mtr / rprrl / rprr / rprr WeB Pressure 3700 Sand TR % LGS 4 Min/Max. / F¢ 15 / 35 F¢ / F¢ Slow Pump Data Pit Vol. 700.0 15 15 15151414 22151512 Hole Vol1499.0 bbl Jets/TFA Slow P.S. 30 45 Filter I ;Calcium 40 ppm Bit Costs $8927.00 Daily Mud $ Total Mud $ Dull 2 2 Slow P.P. $3,875.00 $75'798.00 Grade E I NO BHA Description: Bit, 9-5/8" I°BH F2000, xo, NMLC, NMStab, MWD, NMStab, 3xNMDC, stab, jars, xo, 15 HWDP BHA No: 7 IBHA Length: 672.75 IDate Last Inspected: 12/4/92 IH°urs On Jars: 199 Iniection Data Source: AGI-3 Volume: 309 Type Fluid: MUD i lnjection AGI-2 IRate: 2 iPressure' 800 !Well;I cjprnI psi 10 DIESEL iDaily I Cumulative 2898 i Volume: bblI Volume: Freeze Protect Fluid: DIESEL Volume: 420 gal Fuel & Water Data Fuel 6079 Fuel BP IFuel 10000.00 IDrl. water 1150 IDrl' water VERN Used: gal Source: ]Recv'd: gall Used: BBL~ Source: ;uttin.qs Daia Weather Data ,,,, ,, Daily: 280BBL cl:~umulative: c4St°rage BALL MILL Temp: lWind Speed: mr)4Chill Factor: ~ite: el: °F Personnel & Safety/BOP Data Accident?(Y/N): N IName: IEmplbyer: iRptFiled?(Y/N): PB Drlg: 1J Contractor: 24 [Service: 14 IOther: 5 Total: 44 Last BOPE Test: 12/29/92 Last BOP Drill: 12/27/92 Last H2S Drill: Last Fire Drill: 12/26/92 Last Safety Mtg: 12/27/92 Last SPill Drill: Spill (Y/N)? N Volume (Gals.): Type Spill: Report Filed? Time Ooeration Prob Code Hrs. Ooerations From 0600 t~3 0600 0600-0815 trip 2.25 POOH f. BHA change. Very tight connections while POOH. 0815-0945 TRIP 1.50 CHANGED BHA & WORKED MWD. 0945-1130 BOPE 1.75 TESTED BOP'S. GOOD TEST. 1130-1500 TRIP 3.50 TIH TO 10,228. ( .5 HR RIG SERVICE.) 1500-1530 OTHR 0.50 REAMED 10,228-10303. 1530-0200 DRILL 10.50 DRILED FROM 10,303-10,799' MD. STOPPED AT THE K-2 MARKER UNTIL GEOLOGIST IN TOWN COULD DECIDE CASING POINT. ReP 100 FPH AT THIS TIME. 0200-0230 CIRC 0.50 ClRC AND WAIT ON GEOLOGIST. 0230-0600 RIGS EFC 3.50 REPLACED MUD PUMP SHOCK HOSE. IDepth (MD/TVD): Well: AGI-3 JPhone: Contractor: Audi 2 4605 Operation at 0600: RUNNING 9-5/8" CSG Rig Accept (hr/date): 12/17/92 @ 0900 Mud I)ata Mud TypeLSLD Weight 9.6 Viscosity 41 sec PV/YP 12 / 18 Gels 6 13 / APl W.L. 6.0 HTHP 100 p~i HTHP 500 psi Solids 8.0 % Sand TR % 12/31/92 IDays Sine, J/Est: 10935 / 8065 I Prev(MD): IDaily Costs: $60,465.00 ILastCsg: 13-3/8"@4o6o' Next Csg: (size/depth) I{size) I Rig Release( hr/date): Bit )ata Hole Vo11519.0 bbl Filter cak~ 1 Daily Mud $ $2,413.00 MBT 25.0 Bit No. 6RR4 )H Size 9.7 12.25" Pm 0.4 Make Smith Chlorides 800 ppm Pf 0.2 Type S856KP Mf 1.1 Serial No. JQ2486 / Oil DWR 0 / 92 ¸ES LGS 4 Pit Vol. 650.0 Calcium 40 ppm Total Mud $ $78391.00 Depth Out MD,q-VD Footage ART/AST RPM Table/Mtr WeB Min/Max. Jets/TFA Bit Costs 10935/ 8065 632 ft. 10.8 / 90 90 / rprr / rprr /rprr 0 / 10 KC / KC / KC 15 15 15 15 14 14 Dull Grade Daily Drilling RePOrt;. 14 . I Supv. Init: I 10799 IPr°gress: 136 lest Cum Costs: $1,315,479.00 9-5/8" IShoe 12.6 ppg ITest: Drilling Depth10935 Av~. 130 Drao -- Trq 750 Btm Pump No. Liner Size SPM GPM Pressure Data Rot Wt. 180 S.'O. 13O Wt. :Max Drao Trq 5 0 0 Off no Data 105I 105 370I 37O, 3700 Slow Pump Data BHA Description: Bit, 9-5/8" 1°DH F2000, xo, NMLC, NMStab, MWD, NMStab, 3xNMDC, stab, jars, xo, 15 HWDP BHANo: 7 BHA Length: 672.75 IDate Last Inspected: 12/4/92 I Hours On Jars: Source: AGI-3 Volume: 181 10 IType Fluid' Iniection Data MUD Injection DIESEL Daily Volume: AGI-2 191 Freeze Protect Fluid: I Rate' 2 IPressure: ~pml ICumulative Volume: DIESEL Volume: 420 gal 800 3089 psi Fuel 5392 I Fuei Us ed: gal[Sou rce: Guttinqs Data Daily: 240BBL c F~um ulative: Accident? (Y/N): N IName: PB Drlg: 1 I Contractor: Last DOPE Test: 12/29/92 Last Spill Drill' 0600-0715 RIGS Fuel & Water Data BP !Fuel 10000.00 lDr'.Water 1000 IDrl' water IRecv'd: gal Used: BBL Source: Storage BALL MILL . emp: Wind Speed: Personnel & ~.fety/BOP Data Employer: 24 !service: 15 IOther: 5 Total: ILast H2S Drill: mast Fire Drill: 12/26/92 JLast BOP Drill: 12/27/921Volume (Gals.): I Spill (Y/N)? N ype Spill: Ooerations From 0600 to 0600 EFC FINISHED REPLACING SHOCK HOSE. VERN mP4 Chili Factor: oF Rpt Filed? (Y/N): 45 Last Safety Mtg: 12/27/92 Report Filed? 0715-0930 DRIL DRILLED FROM 10799' - 10935'. CIRC HOLE CLEAN. SHORT TRIPPED TO 9500'. HIT BRIDGE WHILE TIH @ 10581. WASHED THRU BRIDGE @ 10581'- 10,673'. TRIPPED TO 10935'. CIRC LO-H! VIS SWEEP. DROPPED SURVEY. POH TO 10,884. TIGHT 10884-10789'. HAD TO PUMP OUT. WASHED & REAMED 10789'- 10,935'. CIRC LO-HI VIS SWEEP. P©H. PUMPED OUT 10,874 - 10,820'. STILL TIGHT W/O PUMP ON BOTTOM. CHANGED RAMS TO 9-5/8". FIN TOH & L/D BHA. PULLED WEAR RING, R/U WOTCO, & RAN CSG. 0930-1100 CIRC 1100-1230 TRIP 1230-1300 TRIP / 1300-1315 TRIP TH 1315-1600 CIRC 1600-1630 TRIP 1630-1 715 TRIP TH 1715-1945 CIRC 1945-2400 TRIP 2400-0030 DOPE 0030-0230 TRIP 0230-0600 CASG Prudhoe Bay Ddllinl ~~., -"-', Daily Drillinq Report Survey Data Surv. No. 46 47 48 PROJ Depth(MD) 10419 10604 1086.~ 1093!~ , Angle 40.2 40.6 41.2 41.36 Direction 95.2 94.5 94.5 94.5 T.V.D. 7674 7815 8012 8065 Vert. Sec. 6349 6469 6639 i6685 North/South -153 -163 -176 1-180 East/West 6347 6467 6637 6683 Dog Leg .11 .33 .23 .23 Mud Lo,q Data Depth Mud Wt. Formation BG gas Corm gas i'rip gas PPg U L U Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/Sand L ~h ~ Time Or)eratic~n Prob Code. Hrs. Operations From 0600 to 06C0 GEOLOGIST PICKS: K-2 @ 7883 'TVD; SADELROCHIT 8081'TVD. DESIRED CSG PT: 8071'TVD. STOPPED DRILLING @ 8065'TVD. . CSG WILL BE SET @ 8054'TVD. , , , , Prudho¢ Bay Drilling JlsY Drilling Re.oort. AFL. No: 4J0194 Rpt. No: ' !.i¢ 1/1/93 15 ¢:.[_E. Well: AGI-3 Depth (MD/TVD): 10935 / 8065 IPrey (MD): 10935 IPr°gress: 0 I Contractor: Audi2 Phone: 4605 I Daily Costs: $475,096.00 IEst Cum Costs: $1,790,575.00 I ILast Csg: 9-5/8' @ 10921 i Next Csg: 9-5/8" IShoe 12.6 ppg Operation at 0600: DISPLACING TO SEA H20 Jlsize/depth)~(size) ITest: trig Accept (hr/date): 12/17/92 @ 0900 I Rig Release( hr/date): Mud ')ata Bit ~ata Drillin_9 Data Rot Mud TypeLSLD MBT 22.5 Bit No. 666 Depth1 0921 Wt. Weight 9.5 pH 9.4 Size 8.5 P.U. 600+ S.C. 200 I~ Wt. Wt. Viscosity 40 Pm Make STC Avg. Max sec Draa Drna Trq- Trq - ~PV/YP 11 / 14 pf Type F15L Btm Off , , !Gels 3 10 Mf Serial No. KS2234 Pum[~ Data / Pump No. 1 2 APl W.L. Chlorides Depth Out 8.0 ppm MD,ri'VD / / / Liner Size 5.5" 5.5" HTHP Oil Footage 1100 esi % ft. ft. ft. SPM 115 HTHP DWR ART/AST !500 psi / / / / GPM 406 SoliSs ES RPM % Table/Mtr / rprr / rprnJ / rprr Sand LGS-. WeB Pressure 700 % Min/Max. / K~ / Fei / F¢ Slow Pump Data Hole Pit Vol. V°I'719.0 bbl Jets/TFA O P E N Slow P.S. Filter 1 Calcium Bit Costs Cake ppm~ $776.00 $79167.00 Grade BHA Description: BIT, BIT SUB, 6 DC, XO, 15 HWDP BHA No: 8 IBHA Length: 644.57 IDate Last Inspected: !H°urs On Jars: Iniection Data Source' AGI-3 Volume: 691 Type Fluid: MUD Injection AGI-2 IRate: 2.5 IPressure: 400 Well;I cjpmI psi 10 DIESEL Daily 701 I Cumulative 3790 VolUme: bbl! Volume: Freeze Protect Fluid: DIESEL Volume: 420 gal Fuel & Water Data Fuel 9504 · IFuel IFuei 10008.00 IDrl. Water 360 IDri'Wator VERN iUsed: galLSource: BP Recv'd: gal Used: BBL Source: Cuttings Data Weather Data Daily: 114 BBLcF!Cumulative: /St°rage BALL MILL Temp: lWind Speed: mp4 Chill Factor: CFi Site: . oF °F per=onnel & Safety/BOP Data iAccident?(Y/N): N IName: [Employer: IRptFiIed?(Y/N): ,PB D;Ig: 1 ! Contractor: 24 Iservice' 13 I°thor: 1 ITOtah 39 Last BOPE Test: 12/29/92 Last BOP Drill: 12/27/92Last H2S Drill: Last Fire Drill: 12/26/92 Last Safety Mtg: 12/27/92 Last Spill Drill: Spill (Y/N)? N VolUme (Gals.): Type Spill: Report Filed? Time Ooeration Prob Code Hrs. Ooerations From 0600to 0600 0900-0700 CASG 1.00 RAN 9-5/8" CSG i'O 4000'. 0700-0730 CASG ClRC 0,50 ClRC 1 CSG VOL. 0730-1200 CASG 4.50 RAN CSG TO 10672'. TOOK WEIGHT. 1200-1400 CASG TH 2 00 WASHED CSG TO BTM @ 10921'. 1400-1715 CASG ClRC 3.25 CIRC1700BBL, OR2CSGVOL. NOLOSSES. 1715-1945 CASG CMT 2.50 PUMPED 20 BBL 8.3 PPG ARCO PREFLUSH & TESTED LINES 2500 PSI; 50 BBL 11 PPG ARCO SPACER; DROPPED BTM PLUG; 383 SX = 78.44 BBL 15.8 PPG CMT; DROPPED TOP PLUG; 5 BBL H20; 788.59 BBL MUD = 9376 STROKES OR .0841 BBL/STK. BUMPED PLUG 2000 PSI. FLOATS HELD. FLUID LOSS ON CMT = 33 CC/30 MIN. COULD NOT RECIPROCATE. 1945-2100 CASG 1.25 R/D CSG EQUIPT& LANDING JT. 2100-2200 CASG 1.00 RAN PACKOFF & TESTED SAME TO 5000 PSI. 2200-2245 BOPS 0.75 CHANGED RAMS TO 5". RAN WEAR RING. 2245--430 TRIP 6.75 L/D REST OF BHA. P/U BHA #8. TIH. INJECTED 100 BBL MUD, 100 BBL Prudhoe Bay Ddllin( ' !, '~-"~ · Daily Drilling Report. 4J0194 pt. No: 'i,~i',ir ,-3ate: Well Name: Supv. Initi I 1/1/93 , ~u~-3 Page 2 Survey Data Surv. No. Depth (MD) Angle Direction T.V.D. , Vert. Sec. North/Soutl' East/West Dog Leg , , Mud Lo,q Data Depth Mud Wt. Formation BG gas Conn gas rrip gas ppg Ul U U Max BGG Dc Exponent Shale density Est. pore press ROP/Shale ROP/Sand L fph 'fph Time Ooeration Prob Code Hrs. Operations From 0600 to 06do DIESEL DOWN 13-3/8 X 9-5/8" ANNULUS. CUT & SLIPPED DRILL LINE · TAGGED ON FLOAT COLLAR. 0430-0500 CASG .5 TESTED CSG 4000 PSI 30 MIN. GOOD TEST. 0500-0600 CIRC 1 TOOK ON SEA WATER. STARTED DISPLACING WELL TO SEAWATER. , ! Prudh0¢ Bay Drilling .--% ! Drilling Report ~ Date: Days Sine J/Est: Supv. Init: AFE.'Noi 4J0194 Rpt. No: ~ =i,. ~ 1/2/93 16 . Wail: AGI-3 Depth (MD/I'VD): 10935 / 8065 IPrey (MD): 10935 !Pr°grass: 0 contractor: Audi 2 Phone: 4605 I Daily Costs: $36,047.00 lEst Cum Costs: $1,826,622.00 [Last Csg: 9-5/8"@ 1~21 [Next Csg: 7' [Shoe Operation at 0600: RELEASED RIG TO AGI-4 i(size/depth) Ifsize) ITest: Rig Accep't'(hr/date): ..... ;12/17/92 @ 0900 I Rig Release(hr/date)' 1/2/93 @ 0300 HRS I Mud ;)ata' Bit" )ata Drilling'Data Mud Type,.,EAb MBT Bit No. Depth !Rot !Weight ipH Size P.U. S.C. PP~ Wt. Wt. Viscosity iPm Make Avg. Max sec Dm_- Dran PV/YP pf Type Trq Trq - / . Btm Off Gels Mf Serial No. Pt mo Data / Pump No. 1 2 APl W.L. Chlorides Depth Out ppm MD/TVD / / / Liner Size 5.5" 5.5" HTHP Oil Footage 100 ~si % ft. It ft.SPM HTHP OWR ART/AST . 50o ~)si / / / / GPM Solids ES RPM % Table/Mtr / rprr / rpm / rpm ' Pressure Sand LGS WeB % Min/Max, / F¢ / Kct / Kit! Hole Vol. Pit Vol. .Slow Pump Data bbl Jets/TFA Slow P.S. Filter Calcium Bit Costs Cake ppm Daily Mud $ Total Mud $ Dull Grade III I Il Is,°w"... BHA Description: _ Injection Data Source: A~I-3 Volume: 1133 Type Fluid: MUD Injection AGI-2 IRate: 3 ' IPressure: 500 Well:[ ~pmI psi 201 SEA H20 Daily 1619 Cumulative 5409 Volume: bbl Volume: 225 WATER Freeze Protect Fluid: DIESEL 60 DIESEL Volume: 2520 gal Fuel & Water Data , Used: gal~Source: BP 0.00 500 VERN lRecv'd: gal Used: BBL Source: --~,uttings Data Weather Data Daily: 103BBL c . ~it~; °F °F Personnel & Safetv/BOP Data Accident?(Y/N): N JName: IEmployer: IRptFiled?(Y/N): PB Drlg: 1 [ Contractor: 24 [Service' 13 IOther: 1 Total: 39 Last ,.BOPE Test: 12/29/92 Last BOP Drill: 12/27/92 Last H2S Drill: Last Fire Dril'l: 12/26/92 Last Safety Mtg: 12/27/92 Last Spill Drill: Spill (Y/N)? N Volume (Gals,): Type Spill: Report Filed? Time Operation Prob Code Hrs. O~erations From 0600 to 0600 06,00-1030 'ClRC 4.50 PUMPED 90 BBL SAFECLEAN PILL & 50 BBL POLY PILL, AND SEAWATER UNTIL CLEAN. INJECTED MUD & SEAWATER. 1030-2130 TRIP 11.00 TOHL/DDP. SERV RIG .5 HR. DISP 2000' W/ DIESEL. 2130,2400 BOPE 2.50 N/D BOP STACK & RAN TBG HGR. , 2400-0300 OTHR '3.00 N/U DRYHOLE TREE. TESTED FLANGE 5000 PSI. RELEASED RIG @ 0300 HRS rA]aska 0il & Gas O0ns. .tMI I~1 lUl , BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: AGI #3 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/07/93 10:00 SPUD: RELEASE: OPERATION: DRLG RIG: AUDI 2 WO/C RIG: AUDI 2 12/18/92 ( 1) TD: 715'( 0) 12/19/92 (2) TD: 2129' (1414) DRLG. MW: 8.6 VIS:210 SKID RIG TO AGI 3. RIG ACCEPTED @ 09:00 HRS, 12/17/92. RIH W/ BHA #1. SPUD WELL @ 21:15 HRS, 12/17/92. DRLG F/ 106'-715'. SHORT TRIP. MW: 9.0 VIS:170 DRLG F/ 715'-2129'. CBU. SHORT TRIP. 12/20/92 (3) TD: 3671' (1542) 12/21/92 (4) TD: 4070' ( 399) 12/22/92 (5) TD: 4656' ( 586) 12/23/92 (6) TD: 6500' (1844) 12/24/92 ( 7) TD: 8080' (1580) DRLG. MW: 9.4 VIS:ll5 SHORT TRIP. DRLG F/ 2129'-3114'. POOH FOR MTR FAILURE. CHANGE MTR. RIH. DRLG F/ 3114'-3671'. N/D DIVERTER. MW: 9.3 VIS:ll5 DRLG F/ 3671'-4070' CIRC. SHORT TRIP TO 1120' CIRC. POOH. R/U WOTCO. RIM W/ 13-3/8" CSG. CIRC. C~T CSG. N/D DIVERTER. PREP FOR TOP JOB. DRLG. MW: 8.9 VIS: 37 L/D CSG TOOLS. N/D DIVERTER. TOP JOB W/ 108 SX CL 'C' CMT @ 15.6 PPG. N/U BOPE. TEST BOPE. RIH W/ BHA. CIRC @ 3980'. TEST CSG. DRLG FC, CMT TO 4053'. TEST CSG. DRLG CMT, FS, 10' NEW HOLE TO 4080'. CIRC. LOT (12.6 PPG EMW). DRLG F/ 4080'-4656'. DRLG. MW: 9.2 VIS: 43 DRLG F/ 4656'-4938'. POOH LOOK FOR WASHOUT. FOUND 23 STDS OUT. RIH. DRLG F/ 4938'-6030'. CIRC. 15 STDS SHORT TRIP. DRLG F/ 6030'-6500'. DRLG. MW: 9.3 VIS: 43 DRLG TO 7533'. CIRC. 16 STDS SHORT TRIP. DRLG TO 8080'. 12/25/92 (8) TD: 8587' ( 507) 12/26/92 (9) TD: 9170'( 583) DRLG. MW: 9.4 VIS: 42 DRLG TO 8408'. CIRC. POOH. CHANGE BIT. RIH TO 8279'. REAM TO BTM. DRLG TO 8587'. DRLG. DRLG TO 9170'. MW: 9.5 VIS: 42 RECEIVED AU O 2 6 1993 Alaska Oil & Was (Jons. uummiss~o~' Anchorage WELL : AGI #3 OPERATION: RIG : AUDI 2 PAGE: 2 12/27/92 (10) TD: 9525' ( 355) DRLG. MW: 9.5 VIS: 43 DRLG TO 9194'. POOH. CHANGE BIT. RIH. DRLG TO 9525'. 12/28/92 (11) TD: 9787'( 262) 12/29/92 (12) TD: 10303' ( 516) DRLG. DRLG TO 9649'. CIRC . TO BTM. DRLG TO 9787'. POOH. DRLG TO 10303' POOH. MW: 9.4 VIS: 43 POOH. CHANGE BIT, BHA. RIH. REAM MW: 9.4 VIS: 41 12/30/92 (13) TD:10799' ( 496) 12/31/92 (14) TD:10935' ( 136) 01/01/93 (15) TD:10935' ( 0) 01/02/93 (16) TD:10935' ( 0) 04/08/93 (17) TD:10935' ( 0) 04/09/93 (18) TD:l1330' ( 395) 04/10/93 (19) TD:l1540' ( 210) REPLACE SHOCK HOSE. MW: 9.6 VIS: 42 POOH. CHANGE BHA. TEST BOPE. RIH. REAM F/ 10228'-10303'. DRLG F/ 10303'-10799'_ CIRC & WAIT ON GEOLOGIST. REPLACE MUD PUMP SHOCK HOSE. RUN 9-5/8" CSG. MW: 9.6 VIS: 41 REPLACE SHOCK HOSE. DRLG F/ 10799'-10935'. CIRC. SHORT TRIP TO 9500'. WASH F/ 10581'-10673'. RIH. CIRC. POOH TO 10884'. REAM F/ 10789'-10935'. CIRC. POOH. L/D BHA. R/U WOTCO RIH W/ 9-5/8" CSG. DISP TO SEAWATER. MW: 9.5 VIS: 40 RIH W/ 9-5/8" CSG. CIRC @ 4000'. RIH W/ CSG. WASH TO BTM. CIRC. PUMP 20 BBLS ARCO PREFLUSH, 50 BBLS ARCO SPACER, 78 BBLS (383 SX) 'G' CMT. DISP W/ MUD. BUMP PLUG W/ 2000 PSI. L/D LAND JT. RUN & TEST PACKOFF. TEST BOPE. L/D BHA. P/U BHA. RIH. TEST CSG. DISP W/ SEAWATER. RIG RELEASED. MW: 8.5 VIS: 0 DISP W/ SEAWATER. POOH. L/D DP. DISP TOP 2000' W/ DIESEL. N/D BOPE. N/U TREE. TEST TREE. RIG RELEASED @ 03:00 HRS, 1/2/93. DISP TO FLO PRO. MW: 8.5 VIS: 0 SKID RIG. N/D TREE. N/U BOPE. TEST BOPE. RIH W/ BHA. DISP OUT DIESEL. RIH. TAG FC @ 10841'. TEST CSG. OK. DRLG FS. CIRC. DISP WELL W/ FLO PRO. RELOG W/ MWD. MW: 9.2 VIS: 55 DISP WELL TO FLOPRO. DRLG F/ 10935'-10945'. FIT (12.9 PPG EMW). DRLG TO 11330' POOH FOR WASHOUT. FOUND @ 5690'. RIH. RELOG W/ MWD. SHORT TRIP TO SHOE. MW: 9.2 VIS: 0 DRLG F/ 11330'-11393'. CIRC. POOH. CHANGE BIT. RIH. REAM F/ 10960'-11393' DRLG TO 11540' TD WELL @ 04:30 HRS, 4/10/93. CIRC. SHORT TRIP TO SH6E. RECEIVED AU 6 2 6 1993 Alaska Oil & Gas Cons. Anchorage WELL : AGI #3 OPERATION: RIG : AUDI 2 PAGE: 3 04/11/93 (20) TD:11540 PB:l1540 04/12/93 (21) TD:l1540 PB:l1540 04/13/93 (22) TD:11540 PB:l1540 DISP WELL TO BRINE. MW: 9.3 NaCl CBU. POOH. HOLE TIGHT. CBU. POOH. R/U WOTCO. RIH W/ 7" LNR ON DP. CIRC. PUMP 100 BBLS XANVIS, 250 BBLS SEAWATER, 45 BBLS 9.3 PPG BRINE, 20 BBLS BREAKER, DART. BUMP PLUG. SET HGR W/ 3000 PSI, TOP PKR W/ 4000 PSI. TEST ANNULUS. DISP WELL TO 9.3 PPG BRINE. N/U TREE. MW: 9.3 NaCl DISP WELL W/ 9.3 PPG BRINE. POOH W/ LNR RUNNING TOOL. RIH W/ 7" TBG. TAG UP, SPACE OUT. PUMP 130 BBLS (2000') DIESEL. LAND TBG. TEST TBG. OK. SHEAR OUT PBR. TEST ANNULUS. OK. N/D BOPE. N/U TREE. TEST TREE. RIG RELEASED. MW: 9.3 NaCl TEST TREE. SECURE WELL. RIG RELEASED @ 08:00 HRS, 4/12/93. SIGNATURE: (drilling superintendent) DATE: RECEIVED AU G ~ 6 199;~ Alaska Oil & ~as L;ons. Anchorage SUB- SURFACE DIRECTIONAL SURVEY ~1 UIDANCE ~ ONTINUOUS r~ OOL RECEIVED AUG 2 6 199;~ AJaska Oil & Gas Cons. L;ommissio~ ,Anchorage Company ARco ALASKA, INC. Well Name AGI-3 (1701' FSL, 2411' FEL, SEC 36t T12N~ R14E) Field/Location PRUDHOE BAY, NORTH SLOPEr ALASKA Job Reference No. MIC ,OFILi E Lo~med By: Date ~/c~/'/~70 _ Date 25-APR-93 Computed By: SARBER SINES . SCHLLI~BERGER * GCT DIRECTIONAL SURVEY cuSTOMER LISTING FOR ARCO ALASKA INC. At.) G t 6 1993 AGI - .3 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE' APR-25-1993 ENGINEER' G. SARBER METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 88 DEG 26 MIN EAST COMPUTATION DATE' 27-APR-93 PAGE ARCO ALASKA INC. AGI - 3 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY' APR-25-1993 KELLY BUSHING ELEVATION' 49.00 ET ENGINEER* G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEQ MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 100.00 2OO.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 0 O0 99 97 199 97 299 97 399 97 499 97 599 97 699 96 799 93 899 85 -49 O0 50 97 150 97 250 97 350 97 450 97 550 97 650 96 750 93 850 85 0 0 N 0 0 E 0 8 S 37 14 W 0 9 N 40 20 E 0 18 N 19 55 W 0 22 S 42 54 W 0 12 N 54 40 E 0 28 S 61 18 W 0 56 S 68 25 E 1 52 S 83 18 E 2 57 S 86 2 E 0 O0 -0 09 -0 03 -0 01 -0 48 -0 36 -0 81 -0 36 2 15 6 11 0 O0 0 14 0 24 0 29 0 55 0 88 0 89 I 12 1 13 1 11 O00N 0 105 0 13S 0 25N 044N O03N 023N 0385 0865 1235 O00E 0 lOW 0 04W 000E 047W 0 36W 0 80W 0 37W 2 13E 6 08 E 000 N 0 0 E 14 S 44 40 W 14 S 15 52 W 25 N 0 7 E 65 N 46 59 W 36 N 85 24 W 83 N 74 16 W 53 S 44 26 W 30 S 67 55 E 20 S 78 34 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 999.59 950 59 4 56 O0 1099.15 1050 15 5 47 O0 1198.54 1149 54 6 50 O0 1297.67 1248 67 8 19 O0 1396.46 1347 46 9 17 O0 1495.12 1446 12 9 27 O0 1593.70 1544 70 10 12 O0 1691.78 1642.78 12 10 O0 1789.30 1740.30 13 37 O0 188S.75 1836.75 17 26 N 89 47 E N 8841 E N 88 22 E S 89 50 E S 87 26 E S 88 28 E S 88 52 E S 86 51E S 85 12 E S 85 58 E 13 2O 22 63 33 58 46 73 62 24 78 95 114 136 163 51 33 79 89 17 I . 72 1.25 O. 92 1.29 I .31 0.51 0.49 1.39 1.74 2.30 1 45 S I 31S 22 0 99 S 33 0 76 S 46 1 21S 62 I 81S 78 2 22 S 95 2 89 S 114 4 47 S 136 6 67 S 163 13 16 E 6O E 57 E 33 73 E 46 23 E 62 49 E 78 3O E 95 76 E 114 82 E 136 04 E 163 13.24 S 83 44 E 22 64 S 86 42 E 58 S 88 18 E 73 S 89 4 E 24 S 88 53 E 51 S 88 41E 33 S 88 40 E 80 S 88 33 E 89 S 88 8 E 18 S 87 39 E 2000.00 1979 68 1930 68 22 39 2100.00 2070 60 2021 60 26 12 2200 O0 2158 95 2109 2300 O0 2245 27 2196 2400 O0 2328 86 2279 2500 O0 2409 69 2360 2600 O0 2488 63 2439 2700 O0 2566.71 2517 2800 O0 2643.69 2594 2900 O0 2719.72 2670 72 41 I 95 29 21 27 31 27 86 34 57 69 37 6 63 38 21 71 39 7 59 40 8 3000 O0 2792.82 2743.82 45 25 3100 O0 2862.21 2813.21 46 36 3200 O0 2928.74 2879.74 50 7 3300 O0 2992.03 2943.03 51 21 3400 O0 3054.49 3005.49 50 48 3500 O0 3118.38 3069.38 49 40 3600 O0 3183.,54 3134.54 49 20 3700.00 3248.63 3199.63 49 17 3800.00 3313.91 3264.91 49 17 3900.00 3379.03 3330.03 49 24 N 88 51E N 88 2 E S 89 4 E S 87 39 E S 87 43 E S 87 37 E S 88 27 E S 89 44 E N 89 59 E S 89 26 E 197 35 238 85 285 64 336 10 390 95 449 81 511 20 573 66 637 46 702 40 S 88 47 E S 88 11E 842 S 89 22 E 917 S 87 33 E 994 S 86 4 E 1072 S 87 27 E 1149 S 88 40 E 1225 S 88 28 E 1301 S 88 5 E 1377 S 87 33 E 1452 770 59 59 22 64 69 56 42 34 09 98 2 O5 3 08 3 89 2 94 2 93 2 67 2 26 I 56 1 17 I O7 2.42 2.72 3.29 2.33 2.33 O. 95 1.16 i. 03 0.41 0.39 7 29 S 197 23 E 197 36 S 87 53 E 5 77 S 238 78 E 238 85 S 88 37 E 5 43 S 285 59 E 285 65 S 88 55 E 7 04 S 336 03 E 336 11 S 88 48 E 9 28 S 390 84 E 390 95 S 88 38 E 11 73 S 449 66 E 449 81 S 88 30 E 13 93 S 511 01E 511 20 S 88 26 E 14 89 S 573 47 E 573 66 S 88 31 E 14 91 S 637 29 E 637 47 S 88 40 E 15 24 S 702 25 E 702 41 S 88 45 E 16 30 S 770.43 E 770 60 S 88 47 E 0 18 20 21 26 31 33 35 37 40 18 S 842.41 E 842 61 S 88 46 E 04 S 917 02 E 917 24 S 88 45 E 78 S 994.42 E 994 66 S 88 45 E 39 S 1072.37 E 1072 69 S 88 35 E 14 S 1149.14 E 1149 57 S 88 27 E 31 S 1224.97 E 1225.42 S 88 27 E 24 S 1300 86 E 1301.34 S 88 27 E . 51S 1376.58 E 1377.09 S 88 26 E 38 S 1452.42 E 1452.98 S 88 24 E COMPUTATION DATE' 2?-APR-g3 PAGE 2 ARCO ALASKA INC. AGI - 3 PRUDHOE BaY NORTH SLOPE, ALASKA DATE DF SURVEY' APR-25-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3443.86 3394 86 49 42 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3509.09 3460 O0 3575 38 3526 O0 3643 19 3594 O0 3709 gg 3660 O0 3775 98 3726 O0 3842 38 3793 O0 3909 76 3860 O0 3978 04 3929 O0 4046 09 48 56 38 47 59 19 47 25 99 48 42 98 48 38 38 48 5 76 47 3 04 46 49 29 3997.29 47 23 S 87 8 E 1529 11 S 87 5 E 1604 S 86 47 E 1679 S 86 0 E 1753 S 86 31E 1827 S 87 49 E 1902 S 87 58 E 1977 S 88 0 E 2051 S 88 2 E 2124 S 88 4 E 2197 88 72 17 51 63 40 3O 35 43 0 42 0 55 0 68 1 21 I 41 1 22 0 97 0 73 0 69 0 63 43.93 S 1528.48 E 1529.11 S 88 21 E 47 73 S 1604 17 E 1604.88 S 88 18 E 51 77 S 1678 56 41S 1752 61 63 S 1826 64 99 S 1901 67 71S 1976 70 36 S 2050 72 86 S 2123 75.38 S 2196 93 E 1679.73 S 88 14 E 28 E 1753 19 S 88 9 E 51 E 1827 54 S 88 4 E 56 E 1902 67 S 88 3 E 29 E 1977 45 S 88 2 E 14 E 2051 34 S 88 2 E 15 E 2124 40 S 88 2 E 19 E 2197 49 S 88 2 E 5000.00 4113 69 4064 69 47 39 5100.00 4180 5200.00 4246 5300 O0 4312 5400 O0 4378 5500 O0 4445 5600 O0 4512 5700 O0 4579 5800 O0 4646 5900 55 4131 55 48 30 62 4197 62 48 42 62 4263 62 48 41 89 4329 89 48 5 68 4396 68 48 65 4463 65 48 11 50 4530 50 47 51 47 4597.47 48 7 O0 4713.51 4664.51 47 38 S 87 33 E 2271 31 S 87 28 E 2345 S 87 20 E 2420 S 87 21E 2495 S 86 59 E 257O S 86 36 E 2645 S 86 25 E 2719 S 86 22 E 2793 S 86 10 E 2867 S 87 17 E 2941 65 70 82 69 08 30 63 84 99 0 51 0 71 0 61 0 40 0 27 0 39 0 62' 0 50 0 42 0 49 78.15 S 2270 02 E 2271 36 S 88 2 E 81.42 S 2344 84.83 S 2419 88 32 S 2494 91 96 S 2569 96 14 S 2643 100 73 S 2717 105 38 S 2791 110 23 S 2865 114 90 S 2939 3O E 2345 29 E 2420 34 E 2495 14 E 257O 44 E 2645 56 E 2719 79 E 2793 89 E 2868 95 E 2942 72 S 88 I E 77 S 88 0 E 90 S 87 58 E 78 S 87 57 E 19 S 87 55 E 43 S 87 53 E 78 S 87 50 E 01 S 87 48 E 19 S 87 46 E 6000 O0 4780.45 4731 45 48 16 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4847 12 4798 O0 4913 O0 4979 O0 5046 O0 5111 O0 5177 O0 5242 O0 5309 O0 5375 60 4864 83 4930 04 4997 91 5062 10 5128 67 5193 03 5260 O0 5326 12 48 12 60 48 28 83 48 34 04 48 33 91 49 14 10 49 14 67 48 38 03 48 18 O0 49 17 S 88 56 E 3016.28 S 89 9 E 3090.81 S 89 14 E 3165.S0 S 89 11 E 3240.42 S 89 18 E 3315 35 S 89 0 E 3390 58 S 88 49 E 3466 41 S 88 38 E 3541 92 S 88 23 E 3616 72 S 87 59 E 3691 87 0 96 0 gl 0 48 0 2O 0 17 0 29 0 44 0 63 0 58 0 73 116.84 S 3014.21 E 3016.47 S 87 47 E 118.06 S 3088.73 E 3090.99 S 87 49 E 119.12 S 3163.43 E 3165.67 S 87 51 E 120.18 S 3238 34 E 3240.57 S 87 52 E 121.13 S 3313 27 E 3315.49 S 87 54 E 122.25 S 3388 51 E 3390.71 S 87 56 E 123.69 S 3464 32 E 3466.53 S 87 57 E 125.45 S 3539 81 E 3542.03 S 87 58 E 127.28 S 3614 59 E 3616.83 S 87 59 E 129.70 S 3689 70 E 3691.98 S 87 59 E 7000.00 ,5440 15 5391 15 49 22 7100 O0 5505 72O0 7300 7400 7500 7600 7700 7800 O0 5569 O0 5634 O0 5700 O0 5765 O0 5831 O0 5897 O0 5963 7900.00 6029 08 ,5456 84 5520 78 5585 31 5651 97 5716 60 5782 35 5848 37 5914 28 5980 08 49 39 84 49 50 78 49 9 31 49 7 97 48 57 60 48 $9 35 48 45 37 48 45 28 48 50 S 87 48 E 3767 73 S 87 36 E 3843 78 S 87 2 E 3919 96 S 86 18 E 3995 97 S 85 39 E 4071 43 S 85 13 E 4146 75 S 86 31 E 4222 10 S 88 14 E 4297.43 S 88 26 E 4372.54 S 88 23 E 4447.75 0 61 0 54 0 39 0 63 0 72 0 63 0 71 1 12 1 13 0 38 132.54 S 3765 52 E 3767 85 S 87 59 E 135.56 S 3841 139.11S 3917 143 58 S 3993 148 97 S 4068 155 07 S 4144 161 O0 S 4219 163 98 S 4294 166 13 S 4369 168 51E 3843 62 E 3920 53 E 3996 87 E 4071 O6 E 4146 27 E 4222 55 E 4297 63 E 4372 23 S 4444.81 E 4447 90 S 87 59 E 09 S 87 58 E 11 S 87 56 E 6O S 87 54 E 96 S 87 51E 34 S 87 49 E 68 S 87 49 E 79 S 87 49 E 99 S 87 50 E COMPUTATION DATE' 27-APR-93 PAGE 3 ARCO ALASKA INC. AGI - 3 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' APR-25-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 6095 02 6046.02 49 2 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 6160 O0 6225 O0 6289 O0 6354 O0 6419 O0 6483 O0 6548 O0 6611 O0 6675 21 6111.21 49 29 17 6176.17 49 33 84 6240.84 49 52 37 6305.37 49 31 24 6370.24 49 35 83 6434.83 49 58 O0 6499.00 50 13 60 6562.60 50 32 O0 6626.00 50 45 S 88 16 E 4523 10 S 88 7 E 4598 93 S 88 14 E 4674 96 S 88 8 E 4751 23 S 88 7 E 4827 63 S 88 24 E 4903 73 S 88 30 E 4980 07 S 88 43 E 5056 76 S 88 48 E 5133 93 S 88 44 E 5211.26 0.23 0.31 172 0.56 175 0.44 177 0.46 180 0.47 182 0.48 184 0,39 186 0.49 188 0.40 189 170 43 S 4520 13 E 4523 34 S 87 50 E 86 S 4595 34 S 4671 75 S 4748 35 S 4824 68 S 4900 75 S 4976 61S 5053 21S 5130 89 S 5208 92 E 4599 91E 4675 15 E 4751 5O E 4827 56 E 4903 88 E 498O 55 E 5056 70 E 5134 02 E 5211 17 S 87 51E 2O S 87 51E 47 S 87 51E 87 S 87 52 E 97 S 87 52 E 30 S 87 52 E 99 S 87 53 E 15 S 87 54 E 48 S 87 55 E 9000 O0 6738 04 6689 04 51 7 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 6800 O0 6863 O0 6924 O0 6985 O0 7046 O0 7106 O0 7168 O0 7233 76 6751 10 6814 79 6875 87 6936 66 6997 94 7057 43 7119 71 7184 O0 7302.28 7253 76 51 11 10 51 39 79 52 8 87 52 24 66 52 45 94 53 3 43 50 43 71 47 44 28 45 50 S 88 43 E 5288.89 S 88 32 E 5366.78 S 88 26 E 5444.96 S 88 47 E 5523.67 S 89 0 E 5602.84 S 88 52 E 5682.24 S 88 56 E 5762.03 S 88 52 E 5840.87 S 88 31 E 5916.61 S 87 48 E 5989.39 O. 30 0 30 0 37 0 43 0 53 0 46 0 39 1 O5 1 33 1 92 191.64 S 5285 62 E 5289 09 S 87 55 E 193.51S 5363 195.62 S 5441 197.56 S 5520 199.03 S 5599 200.56 S 5678 202.17 S 5758 203.65 S 5837 205.33 S 5913 207.58 S 5985 49 E 5366 64 E 5445 33 E 5523 49 E 5603 88 E 5682 65 E 5762 48 E 5841 21E 5916 95 E 5989 98 S 87 56 E 16 S 87 56 E 86 S 87 57 E 03 S 87 58 E 42 S 87 59 E 2O S 87 59 E O3 S 88 0 E 77 S 88 I E 55 S 88 1E 10000 O0 7373.00 7324 O0 44 12 10100 O0 7445.64 7396 64 42 43 10200 O0 7520.07 7471 10300 O0 7596 22 7547 10400 O0 7672 78 7623 10500 O0 7749 11 7700 10600 O0 7825 19 7776 10700 O0 7901 11 7852 10800 O0 7976 84 7927 10900 O0 8052 14 8003 14 41 6 07 41 9 22 39 52 78 40 11 11 40 19 19 40 35 11 40 25 64 41 0 S 86 23 E 6060 07 S 85 34 E 6128 S 84 33 E 6195 S 83 50 E 6260 S 84 0 E 6324 S 64 14 E 6388 S 84 29 E 6453 S 84 41E 6518 S 84 45 E 6583 S 84 46 E 6649 72 38 01 14 56 29 23 4O 08 2 24 1 81 1 75 1 62 I 21 0 53 0 29 0 36 0 46 0 77 211 22 S 6056.55 E 6060.23 S 88 0 E 216 221 228 235 241 248 254 260 266 04 S 6125.10 E 6128.91 S 87 59 E 83 S 6191.63 E 6195.60 S 87 57 E 51 S 6256.10 E 6260.27 S 87 ,54 E 33 S 6320.07 E 6324.45 S 87 52 E 93 S 6384.33 E 6388.91 S 87 50 E 34 S 6448.91 E 6453.69 S 87 48 E 50 S 6513.70 E 6518.67 S 87 46 E 47 S 6578.74 E 6583.89 S 87 44 E 36 S 6644.28 E 6649.62 S 87 42 E 11000.00 8126 87 8077 87 41 40 11100.00 8201 90 8152 90 41 8 11200.00 8277 42 8228 42 40 41 11300.00 8353 46 8304 46 40 21 11400.00 8429 58 8380 58 40 37 11500.00 8505 79 8456 79 40 23 11540.00 8536 27 8487 27 40 23 S 84 52 E 6715 4O S 84 51E 6781 38 S 84 58 E 6846 81 S 84 52 E 6911 62 S 85 47 E 6976 37 S 85 47 E 7041 O0 S 85 47 E 7066 88 0.83 0 87 0 62 0 65 0 69 0 O0 0 O0 272.26 S 6710 46 E 6715.98 S 87 41 E 278.13 S 6776 30 E 6782.01 S 87 39 E 284.06 S 6841 S9 E 6847.49 S 87 37 E 289.86 S 6906 27 E 6912.35 S 87 36 E 295.33 S 6970 90 E 6977.15 S 87 34 E 300.25 S 7035 41 E 7041.82 S 87 33 E 302.16 S 7061 26 E 7067.72 S 87 33 E r' COMPUTATION DATE: 27-APR-93 PAGE 4 ARCO ALASKA INC. AGI - 3 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: APR-25-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 O0 999 O0 1979 O0 2792 O0 3443 O0 4113 O0 4780 O0 5440 O0 6095 O0 6738 -49 O0 59 950 68 1930 82 2743 86 3394 69 4064 45 4731 15 5391 0 0 59 4 56 68 22 39 82 45 25 86 49 42 69 47 39 45 48 16 15 49 22 02 6046.02 49 2 04 6689.04 51 7 N 0 0 E N 89 47 E 13 N 88 51 E 197 S 88 47 E 770 S 87 8 E 1529 S 87 33 E 2271 S 88 56 E 3016 S 87 48 E 3767 S 88 16 E 4523 S 88 43 E 5288 0 O0 2O 35 59 11 31 28 73 10 89 0 O0 I 72 2 05 2 42 0 42 0 51 0 96 0 61 0 23 0 30 0 O0 N 1 45 S 13 7 29 S 197 16 30 S 770 43 93 S 1528 78 15 S 2270 116 84 S 3014 132 54 S 3765 170.43 S 4520 191.64 S 5285 16 E 13 23 E 197 43 E 770 48 E 1529 02 E 2271 21E 3016 52 E 3767 13 E 4523 62 E 5289 0 O0 E 0 O0 N 0 0 E 24 S 83 44 E 36 S 87 53 E 60 S 88 47 E 11 S 88 21E 36 S 88 2 E 47 S 87 47 E 85 S 87 59 E 34 S 87 50 E 09 S 87 55 E 10000.00 7373.00 7324,00 44 12 11000.00 8126.87 8077,87 41 40 11540.00 8536.27 8487.27 40 23 S 86 23 E 6060.07 S 84 52 E 6715.40 S 85 47 E 7066.88 2.24 O. 83 0.00 211.22 S 6056.55 E 6060.23 S 88 0 E 272.26 S 6710.46 E 6715.98 S 87 41 E 302.16 S 7061.26 E 7067.72 S 87 33 E AU G 6 Alaska Oil & Gas Cons. Anchorage COMPUTATION DATE: 27-APR-93 PAGE 5 ARCO A~ASKA INC. AGI - 3 PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY- APR-25-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGZNEER- G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 49 02 149 03 249 O3 349 03 449 03 549 O3 649 03 749 05 849 10 0 O0 49 O0 .149 O0 249 O0 349 O0 449 O0 549 O0 649 O0 749 O0 849 O0 -49.00 0.00 .100 O0 200 O0 300 O0 40O O0 500 O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 11 S 4'1 46 W 0 4 S 51 39 E 0 14 N 7 12 E 0 22 N 59 25 W 0 21 S 16 6 E 0 23 N 60 17 W 0 25 S 39 32 E .1 29 S 79 9 E 2 11 S 84 35 E 0 O0 0 O0 -0 10 0 O2 -0 19 -0 52 TO 44 -0 85 0 66 3 87 O0 O0 2O 29 33 76. 96 10 29 97 0 O0 N 0 O0 N 0 16 S 0 02 N 0 47 N 0 16 N 0 20 N 0085 0 645 1 055 OOOE 000 E 0 11 W O02E 0 17W 0 51 W 043W 0 85W 0 64 E 3 84E 0 O0 N 0 0 E O0 N 0 0 E lg S 33 45 W O3 N 52 0 E 5O N 20 22 W 53 N 73 3 W 48 N 64 50 W 86 S 84 34 W 91 S 44 49 E 98 S 74 45 E 949 24 1049 1150 1250 1351 1453 1554 1656 1758 1861 61 1049 13 1149 86 1249 93 1349 25 1449 63 .1549 29 1649 61 .1749 68 1849 949 O0 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 900 O0 4 11 O0 5 28 O0 6 18 O0 7 34 O0 9 1 O0 9 23 O0 9 38 O0 11 23 O0 12 50 O0 15 33 S 87 43 E N 89 10 E N 88 11 E N 88 5O E S88 13 E S 87 44 E S 88 39 E S88 2E S 85 44 E S85 I E g 13 17 70 27 89 39 95 54 56 7O 87 87 55 105 83 127 48 152 34 1 5O 1 69 0 97 1 11 1 47 0 91 0 28 0 91 1 61 1 99 1 39 S 9 09 E 67 E 17 87 E 27 94 E 39 56 E 54 85 E 7O 52 E 87 80 E 105 43 E 127 24 E 152 1 40 S 17 1 16 S 27 0 83 S 39 0 90 S 54 1 57 S 70 2 05 S 87 2 48 S 105 3 72 S 127 5 82 S 152 9 2O S 81 19 E 73 S 85 28 E 9O S 87 37 E 95 S 88 48 E 57 S 89 3 E 87 S 88 44 E 55 S 88 40 E 83 S 88 40 E 48 S 88 2O E 35 S 87 49 E 1966 96 1949 O0 1900 O0 20 49 2075 2188 2304 2424 2549 2677 2806 2939 3080 98 2049 61 2149 36 2249 65 2349 59 2449 21 2549 96 2649 12 2749 O0 2000 O0 25 28 O0 2100 O0 29 6 O0 2200 O0 31 36 O0 2300 O0 35 33 O0 2400 O0 37 57 O0 2500 O0 38 50 O0 2600.00 40 11 O0 2700.00 42 19 80 2849.00 2800.00 46 21 S 89 47 E N 87 35 E S 89 21E S 87 38 E S 87 41E S 87 53 E S 89 29 E S 89 59 E S 89 10 E S 88 21E 185 12 228 37 280 08 338 37 405 16 480 03 559 32 641 95 728 34 828 66 1 54 2 91 3 87 2 91 2 83 2 62 i 64 1 15 I 26 2 69 7.40 S 184 99 E 185 13 S 87 43 E 6 16 S 228 5 36 S 280 7 14 S 338 9 12 14 14 15 17 86 S 405 92 S 479 79 S 559 91S 641 56 S 728 29 E 228 O4 E 280 3O E 338 04 E 405 86 E 480 12 E 559 78 E 641 19 E 728 75 S 828.48 E 828 37 S 88 27 E 09 S 88 54 E 37 S 88 47 E 16 S 88 36 E O3 S 88 27 E 32 S 88 29 E 95 S 88 40 E 36 S 88 47 E 67 S 88 46 E 3231 74 2949 O0 2900.00 50 31 3391 3547 3700 3853 4007 4160 4308 4459 4609 33 3049 04 3149 56 3249 84 3349 95 3449 41 3549 59 3649 14 3749 90 3849. O0 3800 O0 3000 O0 50 57 O0 3100 O0 3200 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 49 15 O0 49 17 O0 49 24 O0 49 43 O0 48 22 O0 47 32 O0 48 43 O0 48 2 S 89 15 E 941 65 S 86 4 E 1065 98 S 88 31E 1185 28 S 88 28 E 1301 76 S 87 50 E 1417 92 S 87 7 E 1535 17 S 86 51 E 1650 21 S 85 57 E 1759 48 S 87 43 E 1871 95 S 87 57 E 1984.76 2.87 2.40 1.14 1 O2 0 35 0 42 0 63 I 21 1 55 0 94 20.34 S 941.44 E 941.66 S 88 46 E 25.93 S 1065 67 E 1065.99 S 88 36 E 32.35 S 1184 35.25 S 1301 38.97 S 1417 44.23 S 1534 50.13 S 1649 56.85 S 1758 63.79 S 1870 67.97 S 1983 83 E 1185.28 S 88 26 E 28 E 1301.76 S 88 27 E 39 E 1417 92 S 88 25 E 53 E 1535 17 S 88 21 E 45 E 1650 22 S 88 16 E 59 E 1759 50 S 88 9 E 90 E 1871 99 S 88 3 E 65 E 1984 81 S 88 2 E COMPUTATION DATE' 2T-APR-93 PAGE 6 ARCO ALASKA INC. AGI - 3 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' APR-25-1993 KELLY BUSHING ELEVATION' 49.00 FT ENGINEER' G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET Of SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOLrrH EAST/WEST DIST. AZIMLrTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4757 53 3949 O0 3900.00 46 56 49O4 5052 5203 5355 5504 5654 5803 5952 O0 4049 59 4149 60 4249 05 4349 96 4449 46 4549 79 4649 83 4749 6102.83 4849 O0 4000.00 47 27 O0 4100.00 48 3 O0 4200.00 48 43 O0 4300.00 48 32 O0 4400.00 47 58 O0 4500.00 48 3 O0 4600.00 48 6 O0 4700.00 48 2 O0 4800.00 48 12 S 88 3 E 2093 36 S 88 4 E 2200 S 87 28 E 2310 S 87 20 E 2423 S 87 14 E 2537 S 86 34 E 2648 S 86 27 E 2759 S 86 10 E 28~0 S 88 46 E 2981 S 89 9 E 3092 38 28 41 13 77 83 66 13 91 0 71 0 64 0 66 0 60 0 25 0 40 0 55 0 41 0 86 0 91 71 80 S 2092 18 E 2093 41 S 88 2 E 75 48 S 2199 79 85 S 23O8 84 95 S 2421 90 27 S 2535 96 36 S 2647 103.25 S 2758 110.42 S 2868 116.14 S 2979 118.09 S 3090 14 E 2200 95 E 2310 99 E 2423 61E 2537 12 E 2648 04 E 2759 71E 2870 06 E 2981 84 E 3O93 43 S 88 2 E 34 S 88 1E 48 S 87 59 E 21 S 87 58 E 87 S 87 55 E 97 S 87 51E 83 S 87 48 E 33 S 87 46 E 09 S 87 49 E 6253.43 4949 O0 4900 O0 48 31 6404.47 5049 O0 5000 6556 89 5149 O0 5100 6709 58 5249 O0 5200 6860 31 5349 O0 5300 7013 60 5449 O0 5400 7167 76 5549 O0 5500 7321 72 5649.00 5600 7474 17 5749.00 5700 7626 50 5849.00 5800 O0 48 33 O0 49 22 O0 48 32 O0 48 47 O0 49 22 O0 49 39 O0 49 3 O0 48 57 O0 48 55 7778.24 5949.00 5900 O0 48 38 7929.97 6049 O0 6000 O0 48 53 8082.74 6149 8236.79 6249 8391.73 6349 8545.99 6449 8701.57 6549 8858.92 6649 9017.46 6749 9177.29 6849 O0 6100 O0 49 27 O0 6200 O0 49 41 O0 6300 O0 49 32 O0 6400 O0 49 45 O0 6500 O0 50 14 O0 6600.00 50 42 O0 6700.00 51 9 O0 6800.00 51 34 9339.53 6949.00 6900.00 52 22 9503 87 7049.00 7000.00 52 47 9669 01 7149.00 7100.00 51 37 9822 59 7249.00 7200.00 47 11 9966 38 7349.00 7300.00 44 41 10104 57 7449.00 7400.00 42 39 10238 24 7549.00 7500.00 40 33 10368.88 7649.00 7600.00 40 10 10499.85 7749.00 7700.00 40 19 10631.34 7849.00 7800.00 40 33 S 89 12 E 3205 52 S 89 17 E 3318 70 S 88 56 E 3433 72 S 88 39 E 3549 11 S 88 7 E 3661 88 S 87 47 E 3778 05 S 87 15 E 3895 37 S 86 6 E 4012.38 S 85 16 E 4127.30 S 87 31E 4242.07 S 88 25 E 4356 20 S 88 23 E 4470 S 88 9 E 4585 S 88 13 E 47O2 S 88 4 E 4821 S 88 28 E 4938 S 88 44 E 5057 S 88 45 E 5179 S 88 42 E 5302 S 88 25 E 5427 32 81 99 34 79 97 46 48 16 S 88 56 E 5554.91 S 88 51 E 5685.33 S 88 55 E 5816.74 S 88 26 E 5933.24 S 86 43 E 6036.53 S 85 32 E 6131.82 S 84 8 E 6220.33 S 83 57 E 6304.13 S 84 14 E 6388.46 S 84 30 E 6473.62 0 23 0 17 0 36 0 64 0 61 0 60 0 36 0 66 0 68 0 92 1 . 14 0.29 0.31 0 52 0 45 0 48 0 39 0 47 0 29 0 35 0 49 0 46 0 77 1 49 2 32 1 81 1 69 1 36 0.53 0.26 119.67 S 3203.44 E 3205 68 S 87 52 E 121 18 S 3316.63 E 3318 84 S 87 54 E 123 125 128 132 137 144 153 162 05 S 3431.63 E 3433 84 S 87 57 E 62 S 3547.00 E 3549 22 S 87 58 E 67 S 3659.73 E 3661 99 S 87 59 E 94 S 3775.83 E 3778 17 S 87 59 E 88 S 3893.05 E 3895.50 S 87 58 E 66 S 4009.92 E 4012.53 S 87 56 E 45 S 4124.64 E 4127.50 S 87 52 E 03 S 4239.22 E 4242.32 S 87 49 E 165 67 S 4353.29 E 4356.45 S 87 49 E 168 172 176 180 183 186 189 191 195 87 S 4467 37 E 4470 56 S 87 50 E 43 S 4582 81 E 4586 05 S 87 51 E -- ~. 21S 4699 93 E 4703 23 S 87 51E 14 S 4818 21E 4821 57 S 87 52 E 65 S 4935 62 E 4939 03 S 87 52 E 64 S 5054 75 E 5058 20 S 87 53 E 19 S 5176 22 E 5179 67 S 87 54 E 95 S 5299 21 E 5302 68 S 87 56 E . 13 S 5423 85 E 5427 36 S 87 56 E 198 19 S 5551.57 E 5555 10 S 87 57 E 200 203 205 209 216 224 233 241 250 62 S 5681.96 E 5685 18 S 5813.35 E 5816 78 S 5929.83 E 5933 80 S 6033.04 E 6036 28 S 6128.19 E 6132 30 S 6216.52 E 6220 22 S 6300.10 E 6304 93 S 6384.23 E 6388 30 S 6469.19 E 6474 51 S 87 59 E 90 S 88 0 E 40 S 88 1E 69 S 88 0 E 01 S 87 59 E 56 S 87 56 E 42 S 87 53 E 81 S 87 50 E 03 S 87 47 E COMPUTATION DATE: 27-APR-g3 PaGe 7 ARCO ALASKA INC. AGI - 3 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: APR-25-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 10763 18 7949 O0 7900 O0 40 47 10895 82 8049 O0 8000 O0 41 1 11029 55 8149 O0 8100 O0 41 21 11162 48 8249 O0 8200 O0 40 53 11294 13 8349 O0 8300 O0 40 24 11425 51 8449 O0 8400 O0 40 12 11540 O0 8536 27 8487 27 40 23 S 84 49 E 6559 36 S 84 45 E 6646 32 S 84 51 E 6734 95 S 84 45 E 6822 35 S 84 52 E 6907 82 S 85 34 E 6992 88 S 85 47 E 7066 88 0.46 O. 75 0.88 O. 65 O. 65 0.76 O. O0 258 27 S 6554 74 E 6559.83 S 87 45 E 266 11 S 6641 52 E 6646.85 S 87 42 e 274 02 S 6729 97 E 6735.55 S 87 40 E 281 85 S 6817 19 E 6823.01 S 87 38 E 289 52 S 6902 48 E 6908.55 S 87 36 E 296 58 S 6987 38 E 6993.67 S 87 34 E 302 16 S 7061 26 E 7067.72 S 87 33 E RECEIVED Alaska O# & Gas Cons. Commission Anchorage ARCO ALASKA INC. AGI - 3 PRUDHOE BAY NORTH SLOPE, ALASKa MARKER GCT MST READING TI) COMPUTATION DATE: 27-APR-93 PAGE 8 DATE OF SURVEY: APR-25-1993 KELLY BUSHING ELEVATION: 49.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1TO1, FSL, & 2411' FEL, SEC36 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11460.00 8475.31 8426.31 298.27 S 7009.63 E 11540.00 8536.27 8487.27 302.16 S 7061.26 E RECEIVED ARCO ALASKA INC. AGI - 3 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER COMPUTATION DATE: 27-APr-93 PAGE 9 DATE OF SURVEY: APR-25-1993 KELLY BUSHING ELEVATION: 49.00 ET ENGINEER: G. SARBER ~~~ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 1701, FSL, & 2411' FEE, SEC36 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11540.00 8536.27 8487.27 302.16 S 7061.26 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 11540.00 8536.27 8487.27 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7067.72 S 87 33 E RECEIVED ,A I/G 2 6 ~iaska Oil & Gas Cons. Commission Anchorage DIRECTIONAL SURVEY COMPANY ARCO ALASKA INC. FIELD PRUDHOE BAY WELL AGI - 3 COUNTRY USA RUN I DATE LOGGED 25 - APR - 93 DEPTH UNIT FEET t ECEIVED REFERENCE 931 88 AUG 2 6 1993 Alaska Oil & Gas Cons. bun~miss~ol~ Anchorage All interpretations are opinions hued on inferences from electrical or other ma~Jurements and we cannot, and do not guarantee the accuracy or correctness of any Interpretations. and we shall not, except In the case of gross or wllfull negligence on our part. be liable or responsible for any loss. cost~, damages or expenses tncun'ed or su~all*led by anyone resulting from any Interpretation made by any of our olflcem, ag®nfs or employeel. These Inte~r®tatlons are al~o subject to our General Terms and Conditions as set out In our current price k'ELL: AGI-3 (1701' FSL, 2411' FEL, SEC 36, T12N, R14E) HORIZONTAL PROdECT[ON NOI::ITH 8000 FIEF 931e8 6OOO 4000 2OOO -2000 -4000 -6000 SOUTH -8000 -4000 WEST .~CALE = I / 2000 IN/FT -2000 0 2000 4000 6000 8000 10000 12000 ~$T k'ELL: AG;I-3 (1701' FSL, 2411' FEL, SEC 36, T12N, R14E) VERTZCAL PRO,IECTXON 272.00 -4000 -2000 0 0 2000 4000 6000 8000 10000 12000 92.00 PROJECTION ON VERTICAL PLANE 272.00 92.00 SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1 / 2000 IN/FT 6324/6116 Nielson Way Anchorage, AK 99518 907-563-3269 Fax: 907-563-5865 907-562-2646 Fax: 907-561-1358 BAKER HUGHES INTEQ MWD SURVEY WELL #AGI-3 APEX GAS INJECTION PAD Eastman Teleco now Baker Hughes INTEQ appreciates the opportunity to provide our services. Please find attached a copy of the directional surveys in each of the following formats: · No InterPolation · 100' MD Interpolated · 100' TVD Interpolated RECEIVED Date . J~! l/~,,, AUG 2 6 1993 0il & Gas Cons. Anchorage Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Group Well Name Date Surveyed Survey Performed By : AGI-3 : Apex Gas Injection Pad : North Slope, Alaska : : April 14, 1993 : : Don Lentz RECEIVED AUG ~ 6 ~99~ Alaska Oil & Gas Cons. Commissio,, Anchorage This survey is correct to the best of my knowledge and is supported by actual field data. COMPANY REPRESENTATIVE MEASURED DEPTH NO INTERPOLATION Alaska Oil & Gas Cons. Commission Anchorage Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : AGI-3 : Apex Gas Injection Pad : North Slope, Alaska : Date April 14, 1993 Filename : l163ETAK No 'Interpolation Plane of Vertical Section : 91.7° Latitude & Departure relate to : WELLSITE CENTER Vertical Section Originates at : WELLSITE CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.15°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-3 +0° 0' 0' ' (T) RECEIVED AU G 2 1993 Alaska 0il & Gas Cons. ~orm-nisslo~ Anchorage Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : AGI-3 : Apex Gas Injection Pad : North Slope, Alaska : MD CkL INC DIR TVD ft ft' deg deg ft 0 0 0.0 0.0 0 279 279 0.3 15.8 279 579 300 0.2 231.3 579 759 180 1.3 102.9 759 939 180 3.7 96.6 939 1120 1308 1495 1682 1870 2059 2247 2429 2617 2805 2995 3211 3430 3649 4000 4211 4460 4711 4962 5211 5460 5710 5960 6211 6462 6711 6960 7201 7463 7712 7961 8212 8456 8710 9020 Page 1 o f 2 Date April 14, 1993 Filename : l163ETAK No Interpolation VS LAT DEP ft ft ft 0 0 0 0 1 0 0 1 0 2 0 2 10 -1 10 m! LEG 100 0.0 0.1 0.2 0.8 1.3 BU I LD °/100 0.0 0.1 -0.0 0.6 1.3 181 6.0 88.2 1119 188 8.8 90.6 1306 187 9.2 93.5 1490 187 12.1 92.0 1674 188 15.3 95.9 1857 TURN °/100 0.0 5.7 -48.2 -71.3 -3.5 189 24.4 86.4 2034 188 30.1 91.0 2201 182 35.6 90.6 2354 188 38.6 91.0 2504 188 40.7 88.5 2649 25 -1 25 1.3 1.3 -4.6 49 -1 49 1.5 1.5 1.3 78 -2 78 0.3 0.2 1.6 113 -4 113 1.6 1.6 -0.8 157 -7 157 1.8 1.7 2.1 .8 .0 .0 .6 .1 190 44.6 90.3 2789 216 50.3 90.6 2935 219 50.3 94.2 3075 219 49.5 91.3 3216 351 49.8 91.3 3443 221 -7 221 5.1 4 307 -5 307 3.2 3 406 -7 406 3.0 3 519 -8 519 1.6 1 639 -8 639 1.4 1 .2 .6 .3 .1 .1 2 2 0 -0 0 .1 .6 .0 .4 .1 211 48.1 91.3 3581 249 48.9 91.0 3746 251 47.2 90.6 3914 251 47.8 91.0 4084 249 48.8 91.7 4249 768 -6 768 2 927 -8 927 2 1095 -15 1095 1 1262 -23 1262 1 1530 -29 1530 0 .8 .3 .7 .3 .5 -0.8 0.3 -0.7 0.2 0.4 249 48.2 92.4 4414 250 48.1 92.4 4581 250 48.3 89.6 4748 251 48.7 89.2 4914 251 48.8 88.9 5080 1689 -32 1689 1876 -36 1875 2062 -39 2062 2247 -41 2247 2433 -46 2433 0.3 0.0 0.8 0.2 0.1 -0.2 -0.0 0.1 0.2 0.0 249 48.8 89.6 5244 249 49.5 90.6 5407 241 49.9 91.7 5562 262 49.1 93.5 5733 249 49.0 91.0 5896 2620 -52 2619 2806 -60 2805 2992 -63 2992 3180 -61 3180 3368 -58 3368 .2 .4 .4 .6 .8 0 0 0 -0 -0 .0 .3 .2 .3 .0 249 49.0 90.3 6059 251 49.7 89.9 6223 244 49.7 92.4 6381 254 50.3 91.3 6544 310 51.2 93.1 6740 3556 -56 3556 3744 -56 3744 3928 -60 3928 4127 -69 4127 4315 -76 4315 0.2 0.3 0.8 0.4 0.5 0.0 0.3 0.0 0.2 0.3 4503 -78 4502 4693 -79 4693 4879 -83 4879 5074 -89 5073 5314 -98 5313 -5.0 2.4 -0.2 0.2 -1.3 0.9 0.1 1.6 -1.3 0.0 0.0 -0.1 -0.2 0.2 0.3 0.3 0.0 -1.1 -0.2 -0.1 0.3 0.4 0.5 0.7 -1.0 -0.3 -0.2 1.0 -0.4 0.6 Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : AGI-3 : Apex Gas Injection Pad · North Slope, Alaska MD CkL INC DIR TVD VS ft ft deg deg ft ft 9296 276 52.0 92.0 6911 5530 9576 280 53.0 91.7 7082 5752 9766 190 49.3 91.3 7201 5900 9945 179 45.5 93.5 7322 6032 10138 193 42.4 95.6 7461 6166 10233 95 41.0 96.3 7532 6229 10419 186 40.2 95.2 7673 6349 10604 185 40.6 94.9 7814 6469 10865 261 41.2 94.5 8011 6640 11111 246 41.2 94.2 8196 6802 11353 242 40.4 93.1 8380 6960 11485 132 39.9 93.8 8481 7045 Page 2 of Date April Filename : No Interpolation LAT DEP ft ft -108 5529 -115 5751 -119 5899 -124 6031 -135 6164 m! 2 14, 1993 1163 ETAK -141 6227 -153 6348 -164 6467 -178 6637 -I90 6799 LEG BUILD 100 °/100 0.4 0.3 0.4 0.4 2.0 -1.9 2.3 -2.1 1.8 -1.6 -200 6957 -205 7042 1.6 -1.5 0.6 -0.4 0.2 0.2 0.3 0.2 0.1 0.0 0.4 -0.3 O.5 -O.4 TURN °/100 -0.4 -0.1 -0.2 1.2 1.! 0.7 -0.6 -0.2 -0.2 -0.1 -0.5 0.5 Origin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 7045 ft 91.7 ° RECEIVED AUG 2 6 199 Alaska. Oil & Gas Cons. Anchorage MEASURED DEPTH 100' INTERPOLATED / ECEIVED AUG 2 6 1993 Alaska Oil & Gas Cons. Commission: Anchorage Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : AGI-3 : Apex Gas Injection Pad : North Slope, Alaska : Date April 14, 1993 Filename : l163ETAK Interpolated 100 ft of MD Plane of Vertical Section : 91.7° Latitude & Departure relate to : WELLSITE CENTER Vertical Section Originates at : WELLSITE CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.15°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-3 +0° 0' 0'' (T) RECE D AUG 6 Alaska Oil & Gas Cons. CommissiO° Anchorage Client Well Name Eastman Teleco · Prudhoe Bay Drilling Group : AGI-3 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 of Date April Filename : Interpolated 3 14, 1993 l163ETAK 100 ft of MD MD ft 0 100 200 3OO 400 5OO 600 700 8OO 9OO 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 350O 3600 3700 3800 3900 CkL INC DIR TVD ft deg deg ft 0 0.0 0.0 0 100 0.1 5.7 100 100 0.2 11.3 200 100 0.3 30.9 300 100 0.3 102.7 400 100 0.2 174.6 500 100 0.3 216.3 600 100 0.9 145.0 700 100 1.8 101.5 800 100 3.2 98.0 900 100 4.5 93.8 1000 100 5.7 89.1 1099 100 7.2 89.2 1198 100 8.7 90.5 1298 100 9.0 92.0 1396 100 9.3 93.5 1495 100 10.8 92.7 1593 100 12.4 92.4 1692 100 14.1 94.4 1789 100 16.7 94.4 1885 100 21.6 89.4 1979 100 25.6 87.4 2071 100 28.7 89.8 2160 100 31.7 90.9 2246 100 34.7 90.7 2330 100 36.7 90.8 2411 100 38.3 91.0 2491 100 39.5 89.9 2568 100 40.6 88.6 2645 100 42.7 89.4 2719 100 44.7 90.3 2792 100 47.4 90.4 2860 100 50.0 90.6 2927 100 50.3 92.1 2991 100 50.3 93.7 3055 100 50.0 93.3 3120 100 49.7 91.9 3184 100 49.5 91.3 3249 100 49.6 91.3 3313 100 49.7 91.3 3378 VS ft 0 0 0 0 0 15 23 35 48 63 79 98 117 141 167 201 240 286 336 390 448 509 572 636 703 LAT ft 0 0 1 1 1 1 1 1 0 -0 -1 -1 -1 -1 -1 -2 -3 -4 -6 -7 -7 -7 -6 -6 -6 -7 -8 -8 -8 -7 DEP D'LEG ft °/100 0 0.0 0 0.1 0 0.1 0 0.1 0 0.3 0 0.3 0 0.2 1 0.9 4 1.3 8 1.3 BUILD TURN °/100 °/100 0.0 0.0 0.1 5.7 0.1 5.7 0.1 19.6 -0.0 71.8 -0.0 71.8 0.1 41.8 0.6 -71.3 0.9 -43.5 1.3 -3.5 15 1.3 1.3 -4.2 23 1.3 1.3 -4.6 35 1.4 1.4 0.1 48 1.5 1.5 1.3 63 0.4 0.3 1.5 0.4 1.6 1.6 1.8 2.6 5.1 4.2 3.2 3.1 3.0 79 98 117 141 167 201 240 285 336 390 0.3 1.4 1.6 -0.8 1.6 -0.3 1.7 2.1 2.6 -0.1 4.8 -5.0 4.1 -2.0 3.0 2.4 3.0 1.0 3.0 -0.2 448 2.0 2.0 0.1 509 1.6 1.6 0.2 572 1.4 1.2 -1. 1 636 1.4 1.1 -1.3 703 2.1 2.0 0.8 771 -6 771 2.2 2.1 0.9 845 '-7 845 2.6 2.6 0.1 918 -8 919 2.6 2.6 0.1 995 -10 995 1.2 0.3 1.5 1072 -14 1072 1.3 0.0 1.6 1148 1225 1301 1377 1454 1148 1225 1301 1377 1454 -17 -21 -24 -25 -27 0.4 1.1 0.5 0.1 0.1 -0.3 -0.4 -0.4 -1.3 -0. 1 -0.6 0.1 0.0 0.1 0.0 Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : AGI-3 : Apex Gas Injection Pad : North Slope, Alaska : Page 2 of Date April Filename : Interpolated 3 14, 1993 l163ETAK 100 ft of MD MD CkL INC DIR TVD ft ft deg deg ft 4000 100 49.8 91.3 3443 4100 100 49.0 91.3 3509 4200 100 48.2 91.3 3574 4300 100 48.4 91.2 3640 4400 100 48.7 91.1 3707 4500 100 48.6 90.9 3773 4600 100 48.0 90.8 3840 4700 100 47.3 90.6 3907 4800 100 47.4 90.7 3974 4900 100 47.7 90.9 4042 5000 5100 5200 5300 5400 55OO 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 100 48.0 91.1 4109 100 48.4 91.4 4176 100 48.8 91.7 4242 100 48.6 92.0 4308 100 48.3 92.2 4375 100 48.2 92.4 4441 100 48.1 92.4 4508 100 48.1 92.4 4575 100 48.2 91.4 4641 100 48.3 90.3 4708 100 48.4 89.5 4774 100 48.5 89.4 4841 100 48.7 89.2 4907 100 48.7 89.1 4973 100 48.8 89.0 5039 100 48.8 89.0 5105 100 48.8 89.3 5171 100 48.8 89.6 5236 100 49.1 90.0 5302 100 49.3 90.4 5367 100 49.6 90.8 5432 100 49.7 91.2 5497 100 49.9 91.7 5562 100 49.6 92.4 5627 100 49.3 93.1 5692 100 49.1 93.1 5757 100 49.0 92.1 5822 100 49.0 91.1 5888 100 49.0 90.8 5954 100 49.0 90.5 6019 VS ft 1530 1605 1681 1756 1831 LAT DEP D'LEG ft ft °/100 -29 1530 0.1 -31 1605 0.8 -32 1681 0.8 -34 1755 0.2 -35 1830 0.3 1905 -37 1905 0.1 1980 -38 1979 0.7 2054 -39 2054 0.7 2128 -40 2128 0.2 2201 -41 2201 0.3 2276 2350 2425 2500 2575 2649 2724 2798 2873 2947 3022 3097 3172 3247 3322 3397 3472 3547 3623 3699 3774 3851 3927 4003 4079 4155 4230 4306 4381 4457 BUILD TURN o/loo o/loo 0.1 0.O -0.8 0.0 -0.8 0.0 0.2 -0.1 0.3 -0.1 -0.1 -0.1 -0.7 -0.2 -0.7 -0.2 0.1 0.1 0.2 0.2 -42 2275 0.3 0.3 0.2 -44 2350 0.5 0.4 0.3 -46 2425 0.5 0.4 0.3 -48 2499 0.3 -0.2 0.3 -51 2574 0.3 -0.2 0.3 -54 -57 -60 -61 -63 -63 -62 -62 -60 -59 -58 -57 -56 -56 -56 2649 0.2 2723 0.0 2798 0.0 2872 0.8 2947 0.8 3021 0.6 3096 0.2 3171 0.2 3246 0.1 3322 0.1 -0.2 0.2 -0.0 0.0 -0.0 0.0 0.1 -1.0 0.1 -1.1 0.1 -0.7 0.2 -0.2 0.2 -0.2 0.1 -0.1 0.0 -0.1 3397 0.0 0.0 0.0 3472 0.2 0.0 0.3 3547 0.2 0.0 0.3 3623 0.4 0.3 0.4 3698 0.4 0.3 0.4 -57 -58 -60 -63 -67 -70 -73 -76 -77 -78 3774 0.4 0.2 0.4 3851 0.4 0.2 0.5 3927 0.4 0.2 0.5 4003 0.6 -0.3 0.7 4079 0.6 -0.3 0.7 4155 0.2 4230 0.8 4305 0.8 4381 0.3 4456 0.2 -0.2 0.1 -0.0 -1.0 -0.0 -1.0 -0.0 -0.4 0.0 -0.3 Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : AGI-3 : Apex Gas Injection Pad · North Slope, Alaska : Page 3 of 3 Date April 14, 1993 Filename : l163ETAK Interpolated 100 ft of MD MD CkL INC DIR TVD ft ft deg deg ft 8000 100 49.1 90.2 6085 8100 100 49.4 90.1 6150 8200 100 49.7 89.9 6215 8300 100 49.7 90.8 6280 8400 100 49.7 91.8 6344 8500 100 49.8 92.2 6409 8600 100 50.0 91.8 6473 8700 100 50.3 91.3 6537 8800 100 50.6 91.8 6601 8900 100 50.9 92.4 6664 9000 100 51.1 93.0 6727 9100 100 51.4 92.8 6790 9200 100 51.7 92.4 6852 9300 100 52.0 92.0 6914 9400 100 52.4 91.9 6975 9500 100 52.7 91.8 7036 9600 100 52.5 91.6 7097 9700 100 50.6 91.4 7160 9800 100 48.6 91.7 7224 9900 100 46.5 92.9 7292 10000 10100 10200 10300 10400 10500 10600 10700 10800 10900 11000 11100 11200 11300 11400 100 44.6 94.1 7362 100 43.0 95.2 7434 100 41.5 96.1 7507 100 40.7 95.9 7583 100 40.3 95.3 7659 100 40.4 95.1 7735 100 40.6 94.9 7811 100 40.8 94.8 7887 100 41.1 94.6 7962 100 41.2 94.5 8038 100 41.2 94.3 8113 100 41.2 94.2 8188 100 40.9 93.8 8264 100 40.6 93.3 8340 100 40.2 93.3 8416 VS ft 4532 4608 4684 4760 4837 4913 4990 5066 5143 5221 5298 5377 5455 5533 5613 5692 5771 5849 5925 5999 6070 6139 6207 6272 6337 6402 6466 6532 6597 6663 6729 6794 6860 6925 6990 LAT ft -79 -79 -79 -80 -82 -84 -86 -89 -91 -94 -97 -101 -104 -108 -110 -113 -115 -117 -i20 -123 -127 -133 -139 -146 -152 -158 -164 -169 -174 -180 -185 -190 -194 -198 -202 ~EP D'LEG BUILD TURN o o o ft /100 /100 /100 4532 0.2 0.1 -0.2 4608 0.3 0.3 -0.2 4684 0.3 0.3 -0.2 4760 0.7 0.0 0.9 4836 0.8 0.0 1.0 4913 0.3 0.1 0.4 4989 0.4 0.2 -0.4 5066 0.4 0.2 -0.4 5143 0.5 0.3 0.5 5220 0.5 0.3 0.6 5298 0.5 0.3 0.6 5376 0.3 0.3 -0.2 5454 0.4 0.3 -0.4 5532 0.4 0.3 -0.4 5612 0.4 0.4 -0.1 5691 0.4 0.4 -0.1 5770 0.2 -0.2 -0.1 5848 2.0 -1.9 -0.2 5924 2.0 -2.0 0.3 5998 2.3 -2.1 1.2 6069 2.0 -1.8 1.2 6138 1.8 -1.6 1.1 6205 1.6 -1.5 0.9 6271 0.8 -0.8 -0.2 6335 0.6 -0.4 -0,6 6400 0.2 0.1 -0.2 6464 0.2 0.2 -0.2 6530 0.3 0.2 -0.2 6595 0.3 0.2 -0.2 6660 0.2 0.1 -0.1 6726 0.1 0.0 -0.1 6792 0.1 0.0 -0.1 6857 0.4 -0.3 -0.4 6922 0.4 -0.3 -0.5 6987 0.4 -0.4 0.0 11485 85 39.9 93.8 8481 7045 -205 7042 0.7 -0.7 0.5 Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : AGI-3 : Apex Gas Injection Pad : North Slope, Alaska : Page 4 Date April 14, 1993 Filename : l163ETAK Interpolated 100 ft of MD Origin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 7045 ft 91.7° RECE IV'F [': A U G 2 Alaska Oil & Gas Anchorage TRUE VERTICAL DEPTH 100' INTERPOLATED RECEIVED Alaska Oil & Gas Cons. Anchorage Eastman Teleco Client : Prudhoe Bay Drilling Group Well Name : AGI-3 : Apex Gas Injection Pad : North Slope, Alaska : Date April 14, 1993 Filename : l163ETAK Interpolated 100 ft of TVD Plane of Vertical Section : 91.7° Latitude & Departure relate to : WELLSITE CENTER Vertical Section Originates at : WELLSITE CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.15°WELLSITE North Grid convergence : +0.0000° Prudhoe Bay Drilling Group Apex Gas Injection Pad Well AGI-3 +0° 0' 0'' (T) RECEIVED AU G 2 6 993 Alaska Oil & Gas Cons. CommissioP Anchorage Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : AGI-3 : Apex Gas Injection Pad : North Slope, Alaska : Page 1 of 3 Date April 14, 1993 Filename · l163ETAK Interpolated 100 ft of TVD MD ft 0 100 200 30O 400 5OO 6OO 700 8OO 900 1000 1101 1202 1302 1404 1505 1607 1709 1812 1916 2023 2133 2245 2364 2486 2612 2742 2875 3012 3160 3313 3470 3625 3779 3934 4087 4239 4390 4540 4690 CkL INC DIR TVD ft deg deg ft 0 0.0 0.0 0 100 0.1 5.7 100 100 0.2 11.3 200 100 0.3 30.9 300 100 0.3 102.7 400 100 0.2 174.6 500 100 0.3 216.3 600 100 0.9 145.0 700 100 1.8 101.5 800 100 3.2 98.0 900 100 4.5 93.7 1000 100 5.8 89.1 1100 101 7.2 89.2 1200 101 8.7 90.5 1300 101 9.0 92.1 1400 101 9.4 93.4 1500 102 10.9 92.6 1600 102 12.6 92.6 1700 103 14.3 94.7 1800 104 17.5 93.6 1900 106 22.6 88.2 2000 110 26.6 88.2 2100 113 30.1 91.0 2200 119 33.6 90.7 2300 122 36.5 90.7 2400 125 38.5 91.0 2500 130 40.0 89.3 2600 133 42.1 89.2 2700 137 45.0 90.3 2800 148 48.9 90.5 2900 154 50.3 92.3 3000 156 50.2 93.7 3100 155 49.6 91.6 3200 155 49.6 91.3 3300 154 49.7 91.3 3400 153 49.1 91.3 3500 152 48.2 91.3 3600 151 48.7 91.1 3700 150 48.4 90.9 3800 150 47.3 90.6 3900 VS ft 0 0 0 0 0 15 23 35 48 64 8O 99 119 143 173 209 255 306 371 440 516 598 686 780 889 1005 1125 1244 1362 1479 1596 1710 1823 1935 2046 LAT ft 0 0 1 1 1 1 1 1 0 -0 -1 -1 -1 -1 -1 -2 -3 -4 -6 -7 -7 -6 -5 -6 -7 -8 -8 -7 -6 -11 -16 -22 -25 -28 -30 -33 -35 -37 -39 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 0 0.1 0.1 5.7 0 0.1 0.1 5.7 0 0.1 0.1 19.6 0 0.3 -0.0 71.8 0 0.3 -0.0 71.8 0 0.2 0.1 41.8 1 0.9 0.6 -71.3 4 1.3 0.9 -43.5 8 1.3 1.3 -3.5 15 1.3 1.3 -4.2 23 1.3 1.3 -4.6 35 1.4 1.4 0.1 48 1.5 1.5 1.3 64 0.4 0.3 1.5 8O 99 119 143 173 209 255 306 371 440 0.4 0.3 1.3 1.6 1.6 -0.8 1.6 1.6 -0.0 1.8 1.7 2.1 3.1 3.1 -1.1 5.1 4.8 -5.0 3.6 3.6 -0.0 3.2 3.0 2.4 3.0 3.0 -0.2 2.4 2.4 -0.0 516 1.6 1.6 0.2 598 1.4 1.1 -1.3 686 1.6 1.6 -0.1 780 2.2 2.1 0.8 889 2.6 2.6 0.1 1005 1125 1244 1362 1479 1595 1710 1823 1935 2046 1.2 0.9 1.1 0.7 -0.1 0.9 1. 1 -0.4 -1.3 0.2 0.0 -0.2 0.1 0.1 0.0 0.4 -0.4 0.0 0.6 -0.6 -0.0 0.3 0.3 -0.1 0.2 -0.2 -0.1 0.7 -0.7 -0.2 Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : AGI-3 : Apex Gas Injection Pad : North Slope, Alaska : Page 2 of 3 Date April 14, 1993 Filename · l163ETAK Interpolated 100 ft of TVD MD ft 4838 4986 5137 5287 5438 5588 5738 5888 6039 6190 6341 6493 6645 6797 6950 7104 7259 7413 7566 7718 7871 8024 8177 8332 8486 8642 8799 8957 9117 9278 9442 9605 9764 9912 10053 10190 10323 10454 10585 10718 CkL INC DIR TVD ft deg deg ft 148 47.5 90.8 4000 148 47.9 91.1 4100 150 48.5 91.5 4200 151 48.6 91.9 4300 151 48.3 92.3 4400 150 48.1 92.4 4500 150 48.1 92.1 4600 150 48.2 90.4 4700 150 48.4 89.5 4800 151 48.7 89.2 4900 152 48.8 89.0 5000 152 48.8 89.0 5100 152 48.8 89.4 5200 152 49.0 89.9 5300 153 49.5 90.6 5400 154 49.7 91.3 5500 154 49.7 92.1 5600 154 49.3 93.2 5700 153 49.1 92.5 5800 153 49.0 91.0 5900 152 49.0 90.6 6000 153 49.2 90.2 6100 154 49.6 90.0 6200 154 49.7 91.1 6300 155 49.8 92.3 6400 156 50.1 91.6 6500 157 50.6 91.8 6600 158 51.0 92.7 6700 160 51.5 92.7 6800 161 51.9 92.1 6900 164 52.5 91.8 7000 163 52.4 91.6 7100 159 49.3 91.3 7200 148 46.2 93.1 7300 141 43.8 94.7 7400 137 41.6 96.0 7500 132 40.6 95.8 7600 132 40.3 95.1 7700 131 40.6 94.9 7800 132 40.9 94.7 7900 VS ft 2156 2265 2378 2490 2603 2715 2827 2939 3051 3164 3278 3392 3506 3621 3736 3854 3972 4089 4205 4320 4435 4550 4667 4784 4902 5022 5143 5265 5390 5516 5646 5775 5899 6008 6107 6200 6287 6372 6457 6543 LAT ft -40 -42 -44 -48 -52 -56 -61 -63 -63 .62 -6O -58 -57 -56 -56 -58 -62 -67 -72 -76 -78 -79 -79 -81 -83 -87 -91 -96 -i01 -107 -111 -115 -119 -123 -130 -138 -147 -155 -163 -170 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 2156 0.1 0.1 0.1 2265 0.3 0.3 0.2 2377 0.5 0.4 0.3 2490 0.2 0.1 0.3 2603 0.3 -0.2 0.3 2715 0.1 -0.1 0.0 2826 0.2 -0.0 -0.2 2938 0.8 0.1 -1.1 3050 0.5 0.1 -0.6 3163 0.2 0.2 -0.2 3277 0.1 0.1 -0.1 3391 0.0 0.0 -0.0 3506 0.2 0.0 0.3 3621 0.3 0.2 0.3 3736 0.4 0.3 0.4 3854 0.4 0.2 0.5 3972 0.4 -0.0 0.5 4089 0.6 -0.3 0.7 4204 0.4 -0.1 -0.4 4319 0.7 -0.0 -1.0 4434 0.2 0.0 -0.3 4550 0.2 0.1 -0.2 4666 0.3 0.3 -0.2 4784 0.6 0.1 0.8 4902 0.6 0.0 0.7 5021 0.4 0.2 -0.4 5142 0.3 0.3 0.1 5264 0.5 0.3 0.6 5389 0.3 0.3 -0.0 5515 0.4 0.3 -0.4 5645 0.4 0.3 -0.1 5774 0.1 -0.1 -0.1 5898 2.0 -1.9 -0.2 6007 2.3 -2.1 1.2 6106 1.9 -1.7 1.1 6199 1.7 -1. 6 1.0 6285 0.8 -0.8 -0.2 6370 0.4 -0.3 -0.5 6455 0.2 0.2 -0.2 6541 0.2 0.2 -0.2 Client Well Name Eastman Teleco : Prudhoe Bay Drilling Group : AGI-3 : Apex Gas Injection Pad ' : North Slope, Alaska : Page 3 of 3 Date April 14, 1993 Filename · l163ETAK Interpolated 100 ft of TVD MD CkL INC DIR TVD VS ft ft deg deg ft ft 10850 132 41.2 94.5 8000 6630 10983 133 41.2 94.4 8100 6717 11116 133 41.2 94.2 8200 6805 11248 132 40.7 93.6 8300 6891 11380 132 40.3 93.2 8400 6977 11485 105 39.9 93.8 8481 7045 LAT ft -177 -184 -190 -196 -201 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 6628 0.3 0.2 -0.2 6715 0.1 0.0 -0.1 6802 0.1 -0.0 -0.1 6888 0.4 -0.3 -0.5 6974 0.4 -0.3 -0.3 -205 7042 0.7 -0.6 0.2 Origin of Bottom Hole Closure WELLSITE CENTRE Bottom Hole Closure 7045 ft 91.7° RECEIVED A U G ? 6 Alaska Oil & Gas Cons. Commission Anchorage ARCO Ahska, Inc. P.O2~x 1O0360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 3-18A ~q~-18.93 5-13 77- ~ 5-28-93 5-24~/'/~ 5-22-93 5-32 5 t-? ~ 5-27-93 6-14A ~/2~75-19-93 7-147~/ 5-25-93 9-3 ?S. 7~-- 5-18-93 9-3 5-24-93 * 9-4A ?~-~ ¥ 5-26-93 9-5A ~ ~'~' ~ 5-30-93 ** 9-28A ~'~ 5-28-93 9-31A ~'~35-19-93 9-32 ~3'-1/~5-30-93 12-15 ~'~ ~- 5-27-93 12-23 ~ ~- ~ 5-27-93 14-22 . 5-23-93 14.22A/~i ~Z]5.23.93 a-- 8-9 AGI- 1~..i ~ 5-20-93 AGI-1 5-20-93 AGI-2 q~.~¢°5-23-93 AGI-2 /5-23-93 Perf Record AGI-3 a,,~$s 5-20-93, GR/CCL AGI-3' ,~5-21-93 Prtmnry Perf Record AGI-4 ~A~ 5-22-93 Initial Perf Record Completion Record R-n 1, 5" Sch TDTP (Borax) Run 1, 5" Sch GR/Co11~r R-n 1, 5" Arias TDTP (Borax) Ru_n 1, 5" Sch TDTP (Borax) Run 1, 5" Sch Production Log R!m 1, 5" Sch Prod Profile Run 1, 5" Sch Perf Record Run 1, 5" Sch Frod Profile Run 1, 5" Sch Production Log Rim 1, 5" Sch Completion Record R.n 1, 5" Sch Production Log R-n 1, 5" Sch CBT Run 1, 5" Sch Completion Record R-n 1, 5" Sch Completion Record R;n 1, 5" Sch ' Leak Detection R.n 1, 2" Sch Perf Record Run 1, 5" Sch PITS Rnn 1, 5" Sch Perf Record R-n 1, 5" Sch Jewelry Run 1, 5" Sch Perf Record R~m 1, 5" Sch Jewelry Run 1, 5" Sch R-~ 1, 5" Sch R-n 1, 5" Sch R.~ 1, 5" Sch Rn_n 1, 5" Sch The correct well name for this log is 9-4A. The correct API# for 9-28A is 50-029-21292-01. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 6-9-93 REFERENCE: 5-3-93 SSTVD 5-s-93 5-3-93 BH Profile 5-2-93 SSTVD 5-2-93 BHCA/GR ~2/:~t-31/9~ MWD:. DPR/C,R 1/11-15/93 MWD: DPR/GR 1/11-15/93 MWD:. DFC/aR 1/~1-29/93 MWg:. Run 1, 1"&2' Run 1, Run 1, 2'&~' Run 1, Run 1, Y'~' R~ R~ ~9, 2'&~~ R~ ~7, R~ ~7, ~'&~~ Please sign and re~rn the attached copy as receipt of data. Have A Nice Day! Sonya Wallace ATO- 1529 APPROVED _~ Tr~__,s# 9306~~v~--- Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Teleco Teleco Teleco Teleco Teleco Teleco # CE rrm # CHEVRON #D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL # PHILLn~ # PB WELL FILES R&D # BPX # STATE OF AI2~KA ARCO Alaska, Inc. ~ Post Office Bc ~0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 June 7, 1993 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 95501 ,.,OMM RES ENG ~.~ - S ,-~-'-E-"~-G ~ ~N~ ASST I -s-?X¥-T-E~ ! I FILE ! Re' Notice of Gas Injection Dear Mr. Johnston: This is to inform you that on May 30, 1993 ~ARCO began gas injection on the Apex Gas Injection pad. AGI wells #1, #2, #3 and #4 are ~ei:forat~d and gas is being injected at this time. - Injection volumes, tubing and casing pressure information will be reported with the other gas injection wells on form 10-406. Donald F. Scheve Manager, Prudhoe Bay Operations Engineering DFS:llp c: M. L. Bill C. J. Phillips S. J. Wysocki AAI, ATO- 1528 BPX, MB9-2 AAI, ATO- 1554 ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company RECEIVED J UN - 9 199) Alaska Oil & Gas Cons. Commission Anchorage ARCO Alask~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-12-93 REFERENCE: ARCO CASED HOLE FINALS ?~._~~l~. 10 8-4-92 TMD (Boron) _~ 0..~J~9-42 7-3-92 DSN **Corrected** ~.~.9-49 1-2-93 USIT Color ~ ;L~ I) ?~_./11- lA 1-3-93 CBT Color ' -_ NI 1-1A 1-3-93 USIT Color ~.l 14-24 12-9-91 TMD cl. Z-IZ0 AGI-2 1-9-93 Segmented Bond/GR/CCL _~Z-~AGI-3 1-14-93 Segmented Bond/GR/CCL R-n 1, 5" Run 1, 5" R~_m 1, 5" R-n 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Please sign and return the attached copy as receipt of data. RECEIVED BY ~_.~-~ Have A Nice Day! Sonya Wallace ATO-1529 APPR OVED___~_____ Trans# 93031 I-ILS ItLS Sch Sch Sch HI~ Atlas Atlas # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILF~ R&D # BPX # STATE OF ALASKA TEXACO RECEIVED MAR 1 9 1996 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~,,,.,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown x Stimulate Plugging Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1819' NSL, 2432' WEL, Section 36, T12N, R14E, UM At top of productive interval N/A At effective depth N/A At total depth 1637' NSL, 1441' WEL, Section 31, T12N, R15E, UM 12. Present well condition summary Total depth: Effective depth: 5. Type of Well: Development Exploratory StratJgraphic Service 6. Datum elevation (DF or KB) KBE = 36 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number AG1-3 9. Permit number/approval number 92-135/93-006 10. APl number 50 - 029-22318 11. Field/Pool measured true vertical measured true vertical 10935 feet 8065' feet N/A feet N/A feet Plugs (measured) Junk (measured) Prudhoe Bay Field/Oil Pool Casing Length Structural Conductor 76' Surface 4019' Intermediate 10884' Production Liner Perforation depth: measured None Size 20" 13-3/8" 9-5/8" Cemented 27 cu fl Arcticset 1200 sx PF 'E"1400 sx 'G' 383 sx CI 'G' Measured depth 106' 4060' 10921' True vertical depth 106' 3482' 8054' true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None RECEIV[D MAR 0 5 !99,3 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska 0ii & 6as Cons. C;ommiss~o;'~ Anchorage 14. Prior to well operation Subsequent to operation Reoresentative Daily Avera(3e Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Wel~,Ope,~ations x Oil Gas Suspended 17. I hereby (~,ertify/fi~t/the ~regoing is true and corr,ect to the best of my knowledge. S i~]ned J, ~[~r/~'~~ ,~/~.. '-~o.,,,~ ~_,,: Title Drilling EngineerSupen/isor Service Apex Gas Injector Form 10-40'~4 Rev 1~'6/15/88 / SUBMIT IN DUPLICATE ~P/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: AGI %3 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 12/17/92 09:00 SPUD: 12/17/92 09:15 RELEASE: 01/02/93 03:00 OPERATION: DRLG RIG: AUDI 2 WO/C RIG: 12/18/92 ( 1) TD: 715'( 0) 12/19/92 (2) TD: 2129' (1414) DRLG. MW: 8.6 VIS:210 SKID RIG TO AGI 3. RIG ACCEPTED @ 09:00 HRS, 12/17/92. RIH W/ BHA %1. SPUD WELL @ 21:15 HRS, 12/17/92. DRLG F/ 106'-715' SHORT TRIP. MW: 9.0 VIS:170 DRLG F/ 715'-2129'. CBU. SHORT TRIP. 12/20/92 (3) TD: 3671'(1542) 12/21/92 ( 4) TD: 4070' ( 399) 12/22/92 ( 5) TD: 4656' ( 586) 12/23/92 (6) TD: 6500' (1844) 12/24/92 ( 7) TD: 8080' (1580) DRLG. MW: 9.4 VIS:ll5 SHORT TRIP. DRLG F/ 2129'-3114'. POOH FOR MTR FAILURE. CHANGE MTR. RIH. DRLG F/ 3114'-3671' N/D DIVERTER. MW: 9.3 VIS:ll5 DRLG F/ 3671'-4070' CIRC. SHORT TRIP TO 1120' CIRC. POOH. R/U WOTCO. RIH W/ 13-3/8" CSG. CIRC. CMT CSG. N/D DIVERTER. PREP FOR TOP JOB. DRLG. MW: 8.9 VIS: 37 L/D CSG TOOLS. N/D DIVERTER. TOP JOB W/ 108 SX CL 'C' CMT @ 15.6 PPG. N/U BOPE. TEST BOPE. RIH W/ BHA. CIRC @ 3980' TEST CSG. DRLG FC, CMT TO 4053' TEST CSG. DRLG CMT, FS, 10' NEW HOLE TO 4080' CIRC. LOT (12.6 PPG EMW) . DRLG F/ 4080'-4656' DRLG. MW: 9.2 VIS: 43 DRLG F/ 4656'-4938'. POOH LOOK FOR WASHOUT. FOUND 23 STDS OUT. RIH. DRLG F/ 4938'-6030' CIRC. 15 STDS SHORT TRIP. DRLG F/ 6030'-6500' DRLG. MW: 9.3 VIS: 43 DRLG TO 7533'. CIRC. 16 STDS SHORT TRIP. DRLG TO 8080'. 12/25/92 (8) TD: 8587'( 507) 12/26/92 (9) TD: 9170' ( 583) DRLG. MW: 9.4 VIS: 42 DRLG TO 8408' CIRC. POOH. CHANGE BIT. RIH TO 8279' REAM TO BTM. DRLG TO 8587'. DRLG. DRLG TO 9170'. MW: 9.5 VIS: 42 Gas 0ohs. Com'~fiss\°'~ ~ELL : AGI #3 OPERATION: RIG : AUDI 2 PAGE: 2 12/27/92 (10) TD: 9525'( 355) DRLG. MW: 9.5 VIS: 43 DRLG TO 9194' POOH. CHANGE BIT. RIH. DRLG TO 9525' 12/28/92 (11) TD: 9787' ( 262) 12/29/92 (12) TD:10303' ( 516) DRLG. MW: 9.4 VIS: 43 DRLG TO 9649'. CIRC. POOH. CHANGE BIT, BHA. RIH. REAM TO BTM. DRLG TO 9787' POOH. DRLG TO 10303'. POOH. MW: 9.4 VIS: 41 12/30/92 (13) TD:10799' ( 496) 12/31/92 (14) TD:10935' ( 136) 01/01/93 (15) TD:10935' ( 0) 01/02/93 (16) TD:10935' ( 0) REPLACE SHOCK HOSE. MW: 9.6 VIS: 42 POOH. CHANGE BHA. TEST BOPE. RIH. REAM F/ 10228'-10303'. DRLG F/ 10303'-10799' CIRC & WAIT ON GEOLOGIST. REPLACE MUD PUMP SHOCK HOSE. RUN 9-5/8" CSG. MW: 9.6 VIS: 41 REPLACE SHOCK HOSE. DRLG F/ 10799'-10935' CIRC. SHORT TRIP TO 9500' WASH F/ 10581'-10673' RIH. CIRC. POOH TO 10884'. REAM F/ 10789'-10935' CIRC. POOH. L/D BHA. R/U WOTCO. RIH W/ 9-5/8" CSG. DISP TO SEAWATER. MW: 9.5 VIS: 40 RIH W/ 9-5/8" CSG. CIRC @ 4000'. RIH W/ CSG. WASH TO BTM. CIRC. PUMP 20 BBLS ARCO PREFLUSH, 50 BBLS ARCO SPACER, 78 BBLS (383 SX) 'G' CMT. DISP W/ MUD. BUMP PLUG W/ 2000 PSI. L/D LAND JT. RUN & TEST PACKOFF. TEST BOPE. L/D BHA. P/U BHA. RIH. TEST CSG. DISP W/ SEAWATER. RIG RELEASED. MW: 8.5 VIS: 0 DISP W/ SEAWATER. POOH. L/D DP. DISP TOP 2000' W/ DIESEL. N/D BOPE. N/U TREE. TEST TREE. RIG RELEASED @ 03:00 HRS, 1/2/93. SIGNATURE: (drilling superintendent) DATE: APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend Operation Shutdown x Re-enter suspended well Alter casing ~ Repair well .__ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance__ Perforate ~ Other **REVISION" 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1819' FSL, 2432' FEL, Section36, T12N, R14E, UM At top of productive interval 1630' FSL, 380' FEL, Section 31, T12N, R15E, UM At effective depth N/A At total depth 1623' FSL, 108' FEL, Section 31, T12N, R15E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic__ Service x 6. Datum elevation (DF or KB) KBE = 36 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number AGI ~/3 9. Permit number 92-135 10. APl number 50- 029-22318 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11596 feet 8540 feet N/A feet N/A feet Casing Length Size Structural Conductor 76' 20" Surface 4035' 13-3/8" Intermediate 10906' 9-5/8" Production Liner 812' 7" Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Plugs (measured) Proposed Junk (measured) Cemented Measured depth True vertical depth 11 yds Arcticset 106' ,,~ ,~ PF '~" / ~o ,x ~' / ;~0 ,~ 'C"4064' 383 SX CI 'G' 10934' 106' 3500' 8097' 137 sx CI 'G' 10784'- 11596' 7997'-8540' P, EEEIVED ,JAN 1. Alas.ka Oil .& Gas Cons, CommiSSiOn; ~nchorage 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation December 31,1992 16. ff proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas ~ Suspended Service Apex Gas Injector 17. I hereby certify that thf~ foregoing is true and correct to the best of my knowledge. Signed )~( '-~,~/;4 TitleDrillingEnginoorSupervisor FOR COMMISSION USE ONLY 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 ~0 '; ~' ~:', , Form 10-403 Rev 06/15/88 JApproval No. ~.?.~_ / Commissioner Date SUBMIT IN TRIPLICATE SHUTDOWN OF WELL OPERATIONS Attached is an APPLICATION FOR SUNDRY APPROVAL to shutdown well operations on AGI #3 once 9-5/8" casing has been set and cemented. Shutdown of well operations once 9- 5/8" casing has been set and cemented is planned for wells AGI #3 thru AGI #9. Wells AGI #3- AGI #9 will be drilled to 12_-1/4" hole TD, 9-5/8" casing run and cemented. At this time operations will be shutdown and the rig will move to the next well and repeat the process. AGI #10 will be drilled to 8-1/2" TD, 7" liner run, and the well completed. Once AGI #10 is completed the rig will make its way back drilling 8-1/2" hole, running 7" liner and completing all the wells in which operations were shutdown. The decision to drill AGI #3 as described above is based solely on economics and therefore dictated by prudence alone. Operations on AGI #3 are expected to resume on or about 18APR93. All ten wells are estimated to be drilled and completed by 1MAY93. There are no known hydrocarbon bearing sands between surface and 9-5/8" casing point in any of the AGI wells. All 9-5/8" casing points are estimated to be above the top of the Sadlerochit sands. If there are any questions or if further information is required please contact J. E. Robertson at 564-5510. REEEIVED JAN I t99,$ ~.JaSk[! 0ii & Gas Corm. Commission Anchorage WALTER J. HICKEL, GOVERNOR ALAS~A ~ AND GAS ~ ~RVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 December 11, 1992 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit AGI-3 ARCO Alaska, Inc. Permit No. 92-135 Sur. Loc 1819'NSL, 2432'WEL, Sec. 36, T12N, R14E, UM Btmhole Loc. 1623'NSL, 108'WEL, Sec. 31, T12N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · , - STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrilll-]llb. Type of well. Exploratoryl-] Stratigraphic Testl-I Develol~ment OilF'l Re-Entry [] Deepenl-II Service [] Development Gas [] Single Zone [] Multiple Zone [] ~i" Name of Oper'ato~' 5. Datum Elevation (DF or KB) 10. Field and Pool .ARCO Alaska, Inc. KBE = 36'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool ~P. O. Box 196612. Anchorage. Alaska 99519-6612 ADL 4. Location of well at surface 7. Unit or property Name 11. Type Bond(we 20 ^^c 2s.o2s) 1819' NSL, 2432' WEL, SEC. 36, T12N, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1630' NSL, 380' WEL, SEC. 31, T12N, R15E AGI-3 U-630610 At total depth 9. Approximate spud date Amount 1623' NSL, 108' WEL, SEC. 31, T12N, R15E 12/14/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(UDandTVD) property line ADL34632-1623'feet AGI-2-117'@ 1151'MD feet 2560 11596'MD/8540'TVI~eet i16. To be completed for deviated wells ,17. Anticipated pressure (se~ 20 A~C 25.o35 Kickoff depth zzgfeet Maximum hole an~lle 49 0 Maximum surlace 3330PSig At total depth (TVD) 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5tt H-40 Weld 76' 30' 30' 106' 106' 11 yds Arcticset 16" 13-3/8" 68tt L-80 B TC 4035' 29' 29' 4064' 3500' 1148 sx PF "E"I400 sx "G"1250 sx "C" 12-1/4" 9-5/8" 4711 L-80 NSCC 10906' 28' 28' 10934' 8097' 383 sx Class "G" 8-1/2" 7" 2611 L-80 NSCC 812' 10784' 7997' 11596' 8540' 137 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor .., Surface Intermediate Production Liner DEC 0 ] Perforation depth: measured Alas~a.0it.& Gas Cons. true vertical ~,nch0rag~ 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] brilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report• 20 AAC 25.050 requirements[] 21. I hereby certify hat e fo ~going is true and corre~he best of my knowledge Signed /~'t- ~t CommissionJ TitleuseDri/lin~TEn~lineerSuperviSOronly Number IAPI number IA val date JSee cover letter Permi-jo~' J~.~" J50-02-0/ --~ 3 i~OI P~'--/,/- ~-,r~ Jfor other requirements Conditions of approval Samples required [] Yes [] No Mud log required []Yes [] No Hydrogen sulfide measures [] Yes 12~ No Directional survey required .~ Yes [] NO Required working pressure for BOPE EI2M; 1-13M; /~5M; I-]IOM' []15M; Other: . ORIGINAL SIGNED BY by order of Approved by ~!S.~Ei.L' A. DOUG~ Commissioner tne commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN Well: APEX GAS INJECTOR #3 (AGI #3) LOCATION: Surface: Target: T.D.: 1 819' FSL, 2432' FEL, Sec. 36, T12N, R14E 1630'FSL, 380'FEL, Sec. 31,T12N, R15E 1623'FSL, 108'FEL, Sec. 31,T12N, R15E ESTIMATED START: 14/DEC/92 OPR. DAYS TO COMPLETE: 20 (16 days drilling, 4 days completion) CONTRACTOR: AUDI RIG #2 MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 48°/S88.43E/779'/2.0/7200' Estimated Ground level elevation is 13' AMSL. KB to ground level elevation is 36'. Item TVD(BKB) MD(_BKB) Mud Wt. 20" CONDUCTOR 106 1 06 8.5 13-3/8" SHOE 3500 4064 9.0 9-5/8" SHOE 8097 10934 TOP SADLEROCHIT 8102 1 0941 9.2-1 0.0 7" SHOE 8540 11596 9.2-10.0 · TARGET 8296 11231 9.2-1 0.0 TOTAL DEPTH 8540 11596 9.2-1 0.0 CASING PROGRAM: Hole Csg Wt Grade Conn Length Top 30" 20" 91.5# H-40 WELD 76 30 1 6" 13-3/8" 68# L-80 BTC 4035 29 12-1/4" 9-5/8" 47# L-80 NSCC 10906 28 8-1/2" 7" 26# L-80 NSCC 812 10784 Btm 106 4064 10934 11596 COMPLETION: Tubing: 7" GLMs: None Packer: Baker 26# L-80 NSCC 10706 29 10735 9-5/8" x 6" BORE Baker set at 10734' MD or +/- 50' above Top of liner LOGGING PROGRAM: Open Hole 12-1/4" hole: 8-1/2" hole GR/RESISTIVITY WHILE DRILLING TO PICK CASING POINT. GR/RESISTIVITY WHILE DRILLING ACROSS SADLEROCHIT Cased Hole SBT IN 7" AND 9-5/8" before running tubing (GR to be run up to 13-3/8") WELL PLAN Well: APEX GAS INJECTOR #3 (AGI #3) LOCATION: Surface: Target: T.D.: 1819' FSL, 2432' FEL, Sec. 36, T12N, R14E 1630' FSL, 380' FEL, Sec. 31, T12N, R15E 1623' FSL, 108' FEL, Sec. 31, T12N, R15E ESTIMATED START: 14/DEC/92 OPR. DAYS TO COMPLETE: 20 (16 days drilling, 4 days completion) CONTRACTOR: AUDI RIG #2 MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 48°/S88.43E/779'/2.0/7200' Estimated Ground level elevation is 13' AMSL. KB to ground level elevation is 36'. Item TVD(BKB) MD(BKB) Mud Wt, 20" CONDUCTOR 106 106 8.5 13-3/8" SHOE 3500 4064 9.0 9-5/8" SHOE 8097 10934 TOP SADLEROCHIT 8102 10941 9.2-10.0 7" SHOE 8540 11596 9.2-10.0 TARGET 8296 11231 9.2-10.0 TOTAL DEPTH 8540 11596 9.2-10.0 CASING PROGRAM: Hole Csg Wt Grade Conn Length T~p Btm 30" 20" 91.5# H-40 WELD 76 30 106 16" 13-3/8" 68# L-80 BTC 4035 29 4064 12-1/4" 9-5/8" 47# L-80 NSCC 10906 28 10934 8-1/2" 7" 26# L-80 NSCC 812 10784 11596 COMPLETION: Tubing: 7" GLMs: None Packer: Baker 26# L-80 NSCC 10706 29 10735 9-5/8" x 6" BORE Baker set at 10734' MD or +/- 50' above Top of liner LOGGING PROGRAM: Open Hole 12-1/4" Hole: None 8-1/2" Hole: NONE Cased Hole SBT IN 7" AND 9-5/8" before running tubing · ,,sEX GAS INJECTOR #3 (AGI .. 3) DRILLING DISCUSSION AGI #3 is the third of a ten well program at the new Apex Gas Injection pad. All ten wells are to be gas injectors targeted to the apex of the Prudhoe Bay gas cap. They are intended to meet the additional gas injection requirements associated with the GHX-2 project and to "strip" residual liquid hydrocarbons from the gas cap. All ten bottom hole locations lie within an area where the Lower Cretaceous Unconformity truncates the top of the Ivishak Sand. Therefore the Cretaceous shales ("K" shales) will directly overlie the Ivishak sand injection interval (target interval) comprised of Zones 1, 2, 3, and partially truncated Zone 4. Ivishak sand thicknesses are likely to range between 350' and 405'. None of the wells are expected to encounter Putt River, Sag River, Shublik, or an oil column. The proposed casing program is the conventional 20" conductor x 13-3/8" surface casing x 9-5/8" intermediate casing x 7" liner. Gas tight connections will be used on the 9-5/8" intermediate casing as well as the 7" liner. 7" tubing with 5-1/2" tailpipe will be the completion assembly. This assembly will be run with a completion rig after the drilling has moved off the well. ANNULAR_!_.NJECTION The 13-3/8" x 9-5/8" annulus of AGI #2 may be available for injection purposes. Ensure the annulus has been properly permited before commencing injection. The 1 3-3/8" x 9-5/8" annulus on AGI #1 is not to be injected into. Fluids can be injected at the central CC-2 injection facility. AOGCC has informed Prudhoe Bay Drilling that only associated fluids from drilling operations can be pumped down surface x intermediate annuli. Completion fluids CANNOT be injected down the aforementioned annuli. FREEZE PROTECTION The 7" tubing along with the 7" x 9-5/8" annulus will be freeze protected with diesel before the drilling rig moves off the well. CLOSE APPROACHES WE.LLNAME SLOT DISTAN(:E DEPTH (' TVD) AGI #1 AGI #1 236' 1350' TVD AGI #2 AGI #2 118' 1150' TVD LGI # 10 LGI # 10 240' 4600' TVD nE O 01 o,o,.o Alaska 0il & Bas Cons. Anchorage. · , , , , , , 10. ° Anticipated BHP: ° Maximum Anticipated Surface Pressure: ° Planned Completion Fluid: Notes: a, PROPOSED DRILLING AND COMPLETION PROGRAM AGI #3 Procedure MIRU drilling rig. Notify AOGCC of upcoming diverter function test. N/U diverter and function test same. Drill 16" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5000 psi. PU 12-1/4" BHA and RIH. Test casing to 3500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. Drill intermediate hole to intermediate casing point. MU and run 9-5/8 casing string and cement as per well plan. Bump cementing plug with mud. RIH and drill/LOG 8-1/2" hole through reservoir to TD. MU 7" liner on 5" DP. RIH to TD. Cement same. Set liner hanger and packer. Circulate excess cement from wellbore. POOH. MU casing scraper & clean out 7" liner. Run 7", L-.80 and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 4000 psi. Have witnessed by state. NU tree and test to 5000 psi. Release drilling rig. 3850 psi @ 8800' TVD SS 2970 psi 9.6 ppg filtered brine The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/~. c. No potential productive zones are anticipated above 8125' TVD (9-5/8" casing shoe). d. No potential hazardous levels of H2S are anticipated in this well. ,-.Jcl PROGRAM: Well AGI The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casing point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.0 Funnel Viscosity sec/qt ~300 < 1 O0 YP lbs/100ft2 40 - 60 20 - 40 10 sec Gel lbs/100ft2 30 - 60 15 - 20 10 min Gel lbs/100ft2 60- 80 20 - 30 pH - 9.0- 10 9.0- 10 APl Fluid loss mi/30 min 15-25 15-?_5 Hardness mg/I < 2_00 <200 MUD SPECIFICATIONS-INTERMEDIATE HOLE Surface casing shoe to Top of Sadlerochit Sandstone: LSND Gel/Water System Mud Weight ppg 9.2-10.0 Yield Point lbs/100ft2 10 - 15 10 sec Gel lbs/10Oft2 5 - 10 10 min Gel lbs/100ftZ 10 - 20 APl Fluid Loss mi/30 min 6-8 pH - 8.5 - 10.0 Hardness mg/I <200 MUD SPECIFICATIONS-PRODUCTION INTERVAL: Build new mud system to replace mud used in intermediate hole. Mud Weight ppg 9.0-9.5 Yield Point lbs/100ft2 10 - 2:0 10 sec Gel lbs/100ft2 5 - 10 10 min Gel lbs/100ft2 15 - 25 APl Fluid loss mi/30 min 6.0 - 8.0 pH - 9.5 - 10.0 Hardness mg/I <200 The mud salinity should be compatible with the Reservoir logging program. The mud should be run at 10,000- 20,000 ppm chlorides. Alaska Oil & Gas Cons, ~nchorag~ AGI #3 Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-SS 3450 1950 L-80 5020 2260 PBYS (#) 1 O69OOO 1556000 TJYS (#) 1300000 1585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SI PRESSURE 14 3500 2198 Burst S.F. 1.57 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 3500 1729 Collapse S.F, 1,31 Tension Calculation Based 6n full string weight in mud Casg Wt. (#/ft) MD (FT) 68 4064 PBYS Tension S.F. 4.53 Mud Wt. 9.5 ppg TJYS 5.50 String Wt. (#) 236226 AGI Casing Design Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (#) TJYS (#) 4750 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SITP 3850 Burst S.F. 1.78 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift blud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/fi) Collapse press 10.2 8097 0.1 3485 Collapse S.F. 1.36 Tension Calculation Based on full string weight in mud Casg Wt. (fl/fi) MD (FT) 47 10934 PBYS Tension $.F. 2.50 Mud Wt. 10.2 TJYS 2.68 String Wt. (#) 433781 AGi #3 Casing Design PRODUCTION LINER 7", 26#,L-80,NSCC Casing GRADE BURST L-80 724O COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SITP 9.7 9.5 3942 3850 Burst S.F. 1.84 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/fi) Collapse Press 10.2 8097 0.1 3485 Collapse S.F. 1.55 Tension Calculation Based on full string weight in mud Casg Wt. (f/fi) MD (FT) 26 812 Mud Wt. String Wt. (#) 10.2 17821 Tension S.F. PBYS TJYS 33.89 37.43 CEMEN, PROGRAM - HALLIBURTOK SERVICES 1 3 3/8" SURFACE CASING CASING SI.ZE: 13 3/8", 68# CIRC, TEMP: 60°F LEAD CEMENT TYPE: TYPE 'E' PERMAFROST ADDITIVES: n/a WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx APPROX #SACKS: 11 48 PUMP TIME: 4:30 hrs MIX WATER: 11.63 gps FW Mix water temp: 50-65F TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.16 ft3/sx APPROX #SACKS: 400 PUMP TIME: 4 hrs MIX WATER: 5.00 gps FW Mix water temp: 50-65 F TOP JOB CEMENT TYPE: TYPE "C" PERMAFROST (if necessary) ADDITIVES: n/a WEIGHT: 15.6 ppg YIELD:0.94 ft3/sx APPROX #SACKS: 250 PUMP TIME: 2:30 hrs MIX WATER: 3.5 gps FW Mix water temp: 50-65 F SPACER: 100 bbls fresh water ahead of lead slurry. The WATER temperature should be S0-6SF CEMENT VOLUME 1. Lead slurry to surface w/100% excess. 2. Tail slurry volume 400 sx 3. Top job volume +/- 250 sx. 9 5/8" INTERMEDIATE CASING CASING SIZE: 9 5/8", 47# CIRC. TEMP 135°F TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.2_5% HR-5 (Retarder) + 0.2% Halad 344 (Fluid Loss) WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.00 gps FW APPROX #SACKS: 383 PUMP TIME: 4 hrs Mix water temp: 70-80 F SPACER,g: Pump 2_0 bbls Alpha(ARCO) Preflush; 50 bbls Alpha(ARCO) spacer @ 11 ppg. OTHER CONSIDERATIONS: Continuously mix tail slurry. Displace at 12-1 5 bpm. CEMENT VOLUME 1. Lead Slurry will not be needed unless the WEST SAK and UGNU give a hydrocarbon show. 2. Tail Slurry to 1000' MD above shoe w/30% excess. 7" LINER CASING SIZE: 7" 26fl ~_.~"".~'~, 0 'J ~r.,.,.,,,> CEMENT TYPE: C~SS G ~nch0ra~ ADDITIVES: 0.2% CFR-3 (Dispersant)+0.4% HR-5(Retarder)+0.3% Econolite (extender) + 0.4% HA~D 344 (Fluid Loss) + 2% KCI (Clay control) + +0.01% D-AIR-3 (defoamer)+0.9% ~P-1 (Fluid Loss) +0.1 gps Stabilizer 434B. WEIGHT: 15.Tppg YIELD:1.20 ff3/sx MIX WATER: 5.0 gps APPROX ~SACKS' 137 PUMP TIME: 3'30 hrs + 1 hr mixing ~surface FLUID LOSS: 150 cc Mix water temp: 70-80 F ~ 20 bbls ARCO preflush + 2% KCL SPACER: 50 bbls ARCO spacer + 2% KCL, weighted to 11 ppg OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 20-30cc. Displace @ 8-10 bpm. LINER CEMENT VOLUME 1. Open hole (8 1/2" X 7") annulus + 40% excess. 2. 7" 26# casing capacity below landing collar (80 feet). 3. 1 50' liner lap (9 5/8" x 7" liner) 4. 100' of cement on top of the liner in the 9 5/8" casing (without DP in hole). Smith International, inc. Proposal Report Calculated usfl~g the Minimum Curvature Method Comf)uted by the $ii Win-CADDS System Vertical Section Plane: 91.57 deg. Survey Reference: ~JELLHEAD ~eference IJorld Coordinates: lat. 70.20.55.00 N - Long. 148.28.00.22 ~/ ~eference GR~D System: Alaska State Plane Zone: Alaska 4 ~eference GRID Coordinates: (feet): 5979458.89 N 688853.59 E /erticat Section Reference: ~/ELlHEAD :losure Reference: IJELLHEAD ~orth Aligned To: TRUE NORTH P;ge 1 Date: 11/20/92 getlpath ID: AGI-03 Last Revision: 11/~0/92 )rudhoe Bay Dri t ling ~rudhoe Bay, Alaska ~ett: AGI-03 Measured lnc[ Drift TVD Depth Dir. (ft) (deg.) (deg.) (ft) Subsea Depth (fl) I.K.B. ELEVATION (49.0' ABOVE SEA LEVEL) 0.00 0.00 0.00 0.00 ;TART OF BUILD 779.12 0.00 0.00 779.12 879.12 2.00 91.57 879.10 -49.00 730.12 830.10 979.12 4.00 91.57 978.96 1079.12 6.00 91.57 1078.57 1179.12 8.00 91.57 1177.82 929.96 1029.57 1128.82 1279.12 10.00 91.57 1276.58 1379.12 12.00 91.57 1374.74 1479.12 14.00 91.57 1472.17 1227.58 1325.74 1423.17 1579.12 16.00 91.57 1568.76 1679.12 18.00 91.57 1664.39 1779.12 20.00 91.57 1758.93 1519.76 1615.39 1709.93 1879.12 22.00 91.57 1852.29 1979.12 24.00 91.57 1944.33 2079.12 26.00 91.57 2034.96 1803.29 1895.33 1985.96 2179.12 28.00 91.57 2124.05 2279.12 30.00 91.57 2211.51 2379.12 32.00 91.57 2297.22 2075.05 2162.51 2248.22 2479.12 34.00 91.57 2381.09 2579.12 36.00 91.57 2463.00 2679.12 38.00 91.57 2542.86 2332.09 2414.00 2493.86 2779.12 40.00 91.57 2620.57 2879.12 42.00 91.57 2696.04 2979.12 44.00 91.57 2769.17 2571.57 2647.04 2720.17 3079.12 46.00 91.57 2839.87 o OF BUILD ~1~'9.12 48.00 91.57 2908.07 1-3/8" CSG PT 4063.74 48.00 91.57 3500.00 2790.87 2859.07 3451.00 TOTAL Rectangular Offsets (fl) (fl) 0.00 N 0.00 E 0.00 N 0.00 E O.05 S 1.74 E 0.19 S 6.98 E 0.43 S 15.69 E 0.76 S 27.87 E 1.19 S 43.51 E 1.71 S 62.58 E 2.33 S 85.06 E 3.03 S 110.94 E 3.83 S 140.16 E 4.72 S 172.70 E 5.70 S 208.52 E 6.77 S 247.58 E 7.92 S 289.83 E 9.17 S 335.21E 10.49 S 383.67 E 11.90 S 435.15 E 13.39 S 489.59 E 14.95 S 546.92 E 16.60 S 607.08 E 18.32 S 669.98 E 20.11 S 735.56 E 21.98 S 803.73 E 23.91 S 874.41 E 25.91 S 947.52 E 43.88 S 1604.68 E Geographic Coordinates Latitude / Longitude 70.20.54.9959 70.20.54.9959 70.20.54.9954 70.20.54.9940 70.20.54.9917 70.20.54.9884 70.20.54.9842 70.20.54.9791 70.20.54.9730 70.20.54.9661 70.20.54.9582 70.20.54.9495 70.20.54.9398 70.20.54.9293 70.20.54.9180 70.20.54.9058 70.20.54.8927 70.20.54.8789 70.20.54.8642 70.20.54.8488 70.20.54.8326 70.20.54.8157 70.20.54.7981 70.20.54.7798 70.20.54.7608 70.20.54.7411 70.20.54.5644 N 148.28.00.2237 N 148.28.00.2237 N 148.28.00.1727 N 148.28.00.0198 N 148.27.59.7653 N 148.27.59.4093 N 148.27.58.9523 N 148.27.58.3949 N 148.27.57.7378 N 148.27.56.9818 N 148.27.56.1278 N 148.27.55.1768 N 148.27.54.1299 N 148.27.52.9886 N 148.27.51.7541 N 148.27.50.4280 N 148.27.49.0118 N 148.27.47.5073 N 148.27.45.9164 N 148.27.44.2409 N 148.27.42.4830 N 148.27.40.6447 N 148.27.38.7283 N 148.27.36.7362 N 148.27.34.6706 N 148.27.32.5343 N 148.27.13.3302 GRID Coordinates Northing Easting (fl) (ft) 5979458.89 688853.59 5979458.89 688853.59 5979458.89 688855.33 5979458.88 688860.57 5979458.86 688869.28 5979458.84 688881.47 5979458.80 688897.11 5979458.76 688916.19 5979458.71 688938.68 5979458.66 688964.56 5979458.60 688993.80 5979458.53 689026.35 5979458.45 689062.19 5979458.37 689101.26 5979458.28 689143.51 5979458.19 689188.91 5979458.09 689237.39 5979457.98 689288.89 5979457.87 689343.35 5979457.75 689400.70 5979457.62 689460.88 5979457.50 689523.80 5979457.36 689589.40 5979457.22 689657.60 5979457.08 689728.30 5979456.93 689801.43 5979455.64 690458.82 Closure Dist. Dir. (ft) deg. 0.00 @ 0.00 0.00 @ 0.00 1.75 @ 91.57 Vertical DLS Section (ft) (dg/lOOft) 0.00 0.00 0.00 0.00 1.75 2.OO 6.98 @ 91.57 6.98 2.00 15.69 @ 91.57 15.69 2.00 27.88 @ 91.57 27.88 2.00 43.52 @ 91.57 43.52 2.00 62.60 @ 91.57 62.60 2.00 85.10 @ 91.57 85.10 2.00 110.98 @ 91.57 110.98 2.00 140.21 @ 91.57 140.21 2.00 172.77 @ 91.57 172.77 2.00 208.60 @ 91.57 247.67 @ 91.57 289.93 @ 91.57 208.60 2.00 247.67 2.00 289.93 2.00 335.33 @ 91.57 335.33 2.00 383.81 @ 91.57 383.81 2.00 435.31 @ 91.57 435.31 2.00 489.77 @ 91.57 547.13 @ 91.57 607.30 @ 91.57 670.23 @ 91.57 735.84 @ 91.57 804.03 @ 91.57 874.74 @ 91.57 489.77 2.00 547.13 2.00 607.30 2.00 670.23 2.00 735.84 2.00 804.03 2.00 874.74 2.00 947.87 @ 91.57 947.87 2.00 1605.28 @ 91.57 1Ans.?R n nn 3mith International, Inc. Proposal Report P&ge Z Date: 11/20/92 gettpath ID: AGI-03 Measured Inc[ Drift TVD Depth Dir. (ft) (deg.) (deg.) (ft) Subsea Depth (ft) TOTAL Rectangular Offsets (ft) (ft) -5/8" CSG PT 10933,85 48.00 91,57 8097,00 8048,00 183,42 S 6708,25 E OS 10941,32 48,00 91,57 8102,00 8053,00 183,57 S 6713,80 E ARGET 11231.25 48.00 91,57 8296,00 8247,00 189,46 S 6929,18 E 11331,25 48,00 91,57 8362,91 8313,91 191,49 S 7003,47 E 11431,25 48,00 91,57 8429.83 8380,83 193,53 S 7077,76 E ~VIK 11521,18 48.00 91,57 8490,00 8441,00 195,35 S 7144,56 E 11531.25 48.00 91,57 8496.74 8447,74 195,56 S 7152.04 E )TAL DEPTH 11595.90 48.00 91,57 8540,00 8491,00 196.87 S 7200.07 E Geographic Coordinates Latitude / Longitude 70,20,53,1919 N 148,24,44,1898 70,20,53,1904 N 148,24,44,0276 70,20,53,1325 N 148,24,37,7337 70.20,53,1125 N 148,24,35,5628 70,20,53,0925 N 148.24,33,3920 70.20,53,0746 N 148.24,31,4398 70.20.53,0726 N 148.24,31,2212 70.20.53,0597 N 148.24,29,8177 GRID Coordinates Closure Northing Easting Dist. Dir. (ft) (ft) (ft) deg. 5979447.58 695564,17 6710,76 @ 91,57 5979447,58 695569,73 6716,31 @ 91,57 5979447.31 695785,18 6931,77 @ 91,57 5979447,22 695859,49 7006,09 @ 91,57 5979447,13 695933,81 7080,40 @ 91.57 5979447,06 696000,63 7147,23 @ 91,57 5979447,05 696008,12. 7154,72 @ 91.57 5979446,99 696056,16 7202,76 @ 91.57 Vertical DLS Section (ft) (dg/lOOft) 6710,76 0.00 6716,31 0,00 6931,77 0,00 7006.09 0.00 7080,40 0,00 7147,23 0,00 7154,72 0,00 7202.76 0.00 Prudhoe Bay Drilling Prudhoe Bay, Alaska Well: AGI-03 VERTICAL VIEW SCALE 1000 ft. / DIVISION REFERENCE: WELL HEAD 0.0~I O 0 MD ~EiB. ELEVATION (49.0' A~OVE 800( 700C ~oo~ D007 )102 ~06 0.00' ~ 770MI) ~-'TART 0P BUILD BUILD PATE: 2.00 DEG/100 FT 2.00' O 679MD 4.00. ~ 979MD 6.00' O 1070 MD 6.00. ~ 1179 10.00. O 1279 MD 12.00' O 1370 MD 14.00' 0 1479 16.00' O 1579 MD 500 18.00. O 1679 ),iD 50.00' ~ 1'779 ~ 1879 lid 0 1972 0 2072 0 2170 30,OO' 36,00' ~ ~§?g hiD 40.0O' 44.O0. 0 ~gTg KD 500 15~0 I HORIZONTAL VIEW SCALE 1000 ft. / DIVISION REFERENCE' WELL HEAD 2500 3500 4500 5.500 6500 750O 1605 48.00. O 3179 }~) END OF BUILD CRITICAL PDINT DATA HD In¢ AZI IVD NorthEast [R,K.B. 49' 0 0.00 0.00 0 0 0 .~"~ ISTART OF DUILD779 0.00 0.00 779 0 0 48.0~ o 4064 KD 13-3/8' CSt PT I £ND OF BUILD 3]79 48.0091.57e~oe -~6 948 ~Pxx 113-3/8' CSG PT 4064 48.0091,573500 -44 1603 ~. J9-5/8' CSG PT 10934 48.0091.578097 -183 6708 ~ JlO~ 1094148.0091.57810~ -184 6714 ~ ITARG[T Jla3148.0091.579a96 -189 6929 ~ ]KAV]K 115~140.0091.578490 -195 714~ ~!1596 4e.0~ 91.57 854~ -19~ 7~0~ ~ i -- - m I ASP' Y = 5979458.89 ~ IND 11595.9q ~ 181~F~LJ~43~ FEL, SEC. 36~ TI~NI RI4E ~ Ivs 7~o~. ~ / ~ I No.th-19G.g~ l - ~ m TARGET LOCATION, ~ J ASP, Y - 5979447.309 ~ J X = 6~5784.~5 ~ [ BOITDH HOLE LDCAT[DN. ~ ]ASP~ Y = 5979446.99 48.~' O 10034 ~D 0-5/8' CSG 6716 '~ 48.0~ ~ 10041 MD T0S 6932 ~ 4B.0D O 1l~31 ~D 48.00' 0 115al liD KAYIK 7203 48.0¢ Q 11596 ~D TOTAL DEI~rH VERTICAL SECTION PLANE' 91.57' I (~30 2000 3000 4000 5000 6000 7000 §000 Pm udhoe ~ey, ALcskcl · WELL' AOI-03 T~eveLLin9 Cy_Lindem - Nominal PLane FRe£epence WeLL- A61-03 TV:B: 0 - 8540 ~, !ntemva~, 50 rt, ALL Dimections ReL to Tmue Nop-tjh _JSHITH T~ F~IB de~ Eos'~ 315° 345° 15° 3-30° 30° 270 240 180 150 45° 75° 27C~ C~° CUl 105° 24(~ 225° 2~0o 195o AG]-O 1 wP AG]-C~,4P LG]-08 LG]-04 CLOSEST POINIS LG]-06 L~-08 LG]-IO Slot AC~-OI LG]-0~ LG1-10 Dstonce Dr'ec-t;o~ ReF MD Re£ TVD L::~3~.03 178.64 117.55 181,53 ~tst.C~ ttso.oo N/A N/A N/A NVA N/A N/A N/A N/A NYA N/A N/A NYA N/A N/A N/A N/A 240.63 97.C:~ 5707.67 46(0.00 LG]-I2 llOl 1108 IIC~ 1127 t128 t130 ~c~l ~Ch 1 o ~3 N/A N/A N/A N/A hl/A N/A N/A N/A N/A N/A N/A NVA N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NL/A N/A N/A N./A N/A N/A N/A N./A N/A N/A N/A N/A N/A N/A NVA N/A N/A N/A ~I/A N/A N/A FU'A NVA N/A N/A NVA N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 165° 150° []2]TIC.~L POINT DATA MD ]nc Az; i'VO Nc~lh Eos-t R.K.B. L-LEVATID',I (49 0 O.O0 O.DO 0 0 0 SIA,?T EF iiJILD 779 0.00 0.00 779 0 0 END [}- ]~JED gl~ 48.03 91.57 ~ -2¢~ ~48 c~-5./8' C.~3 pl log04 481~9 91.57 80~7 -18'2670~ TO~ lOg~l 48.00 91._57810~ - l [-,4 6714 TAK:'C~T 1 lff"3! 481~[)gl .~7B -~B'c) 6c~:x:) ~,V'J~ t 15~148.00 91.$? 8"lgO -lc,~7145 ll]lpi_ ~pTN 115~ 48/30 91.57 8540 -197 7203 B-L DA'/A TVD 854000 14D 115~5g0 VS 7E{]~ 76 ~t=~lh -~g687 Eos-t 720007 Psudhoe Bey lDPitlin9 Pm ucthoe lBey, ALeslxe · WeLl' lpeve[Lin9 Cy. Lindem - kees~c Dis~cence ReCemence R/eLL- A61-03 IV]il: 0 - 8540 AL~ Dimec~cions ReL ~co lpue Nom~ch hSMITH w E 315~ 345© 15° 87O 84O 810 180 150 45° ~5° 75° 870© 105© 240© 180° 285° 155© CL[]SES'T F~DINTS ~o't P~-OI LI~-O~ LG]-04 [.Gl -06 LG]-08 LGI- 10 L~-18 LI L1-08 Ll-09 LI-10 L1-14 LI-15 L!-~] L 1-27 LI-88 LI-30 Dstonce l~,ec-tlon Ret MD Re{' TVD 836.03 178.63 ] 353.85 I ~.~ 117,55 181,53 1151.~ 11~.~ ~A N/A N/A ~A ~A N/A N/A ~A ~A N/A N/A ~A ~A N/A N/A ~A ~40. ] 5 ~.63 5707.67 4~.~ N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NYA N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NYA N/A N/A N/A NYA N/A N/A N/A N/A i N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 165° 150° GqITICAL PEIINT DATA R,K.B. L-I_£VATICN (49 0 0.~ 0,~ 0 ST~T ~ ~LD ~g 0.~ 0.~ ~g 0 0 END ~ ~D 3l~ 48.~ gl.SZ ~ -~ ~8 ~ C~ PT 1~ ~8.~ gl.57 ~7 -1~ 67~ T~ I~l 4~.~ gi.57 8I~ -184 67~4 ~ ISA'IA I TVD 85~000 I N::r-t h -~g6 87 I Cost 7"dO0 07 J Smith International, lrlc. Travelling Cylinder Report Computed by the S# Win-CADDS System Date: Page 1 11/20/92 Least Distance Method REFERENCE WELL: Prudhoe Bay Drilling Prudhoe Bay, Alaska ge[[: AGI-03 TVD, N/S and E/W are measured from the WELLHEAD Wettpath Stot Distance AGI-OlWP AGI-01 236.03 AGI-O2WP AGI-02 117.55 LGI-02 LGI-02 2524.87 LGI-04 LGI-04 3223.85 LGI-06 LGI-06 597.66 LGI-08 LGI-08 628.03 LGI-IO LGI-IO 240.15 LGI-12 LGI-12 1661.22 1101 L1-01 4932.52 [102 L1-02 4905.92 [109 L1-09 4692.83 1110 L1-10 4666.52 1114 L1-14 3256.67 1115 L1-15 4513.28 [121 L1-21 4333.91 1127 L1-27 3998.48 [128 L1-28 2010.38 [130 L1-30 1440.85 wbeach01 WBCH01 3660.12 wbeachla ~BCH01 3660.12 wbch03 WBCH03 3629.36 wbchO3a ~BCH03 3629.36 wbchO3b WBCH03 3628.12 Closest Points Direction Ref MD Ref TVD 178.63 1353.85 1350.00 181.53 1151.04 1150.00 215.02 6230.73 4950.00 165.77 100.00 100.00 104.13 8248.28 6300.00 267.32 7276.87 5650.00 94.63 5707.67 4600.00 235.05 6230.73 4950.00 184.60 50.00 50.00 182.54 100.00 100.00 184.58 300.00 300.00 182.43 200.00 200.00 188.94 10116.37 7550.00 184.55 0.00 0.00 184.54 0.00 0.00 228.32 4586.81 3850.00 141.53 11536.13 8500.00 206.50 11386.68 8400.00 344.58 850.01 850.00 344.58 850.01 850.00 346.40 850.01 850.00 346.40 850.01 850.00 346.39 850.01 850.00 P udhoe 3ay 9 Pm ud¼oe Bay, A(aslxo · WELL' · -T~aveLling CxLinde~ - Homizon~eL SLide Re¢emence WeLL- AGT-03 TV]3:0 - 8540 Ct, Tn~e~vol, 50 Ct, ALL ]3i~ec~ions ReL ~o T~ue No~h 3D.18 Eos-t I)ed;no~on 345° 15° 870 180 150 45° ~5° 870° ~0° ~'5o 105° 240° AG] LG]-08 LG]-04 LG]-06 LG]-08 LGI-lO LG]-12 {]~0 iii4 IIEI 1127 t128 v~oeachO ! w,oeclch Io ,,,'cC'hO] '~chO3b 225° ~ 210° CLOSCS'T POINTS ,~o'c AG]-OI LG]-08 LGI-04 LG]-06 LG]-08 LG]-10 LI-O] Ll-02 LI-O9 L!-]O LI-14 L1-~5 L1-2~ -27 LI-28 Li-]O ~BD-03 ~BC~3 Dstonce I~ec~ion ReF MD Ref TVD 236,04 178.57 1353.85 1350.00 117.55 18] .53 ] 151.04 1150.00 N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NYA N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A NYA N/A N/A N/A IXL/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A ~¢/A N/A N/A NYA N/A N/A N/A N/A 165° 1 35° 150° CRITICAL POINT DATA __ MO ]nc AZ~ TVD h~th Eos-SJ R.K.B. ELEVATION (49 0 0.~ 0.~ 0 0 u SI~T ~ ~LD ~9 0.~ 0.~ 779 0 0 END ~ ~ C~ PT i~ l~l 4B.~ gl.57 81~ -]84 6714 T~T KA~K I J~J 48.~ 91.57 ~ -1~ 7j45 T~ ~P~ l~ 48.~ g~.57 ~0 -~g7 7~ 7a::e.76 I Eos~ OL-- OlVEETER SYSTE?v1['''....:': Two lines venling 90 deg. apart in direclions 1hat ensure sale down wind venling, and tending lo a point at least 100' Irom any polential source of ignilion. 10' Full Opening Valves -' 35' or as required Dresser Sleeve 1. All pipe connections 150¢ ANSi Flanges or welded connedbns and secured to preve~ movemenL 2_ Manual 10' full opening valves me.'-',..hanic~lly c.onnec'J, ed to ensure that one valve is [ail-s~ie open at all limes. 10" Diverter Line 3. All tums are 90 de"¢. an-,d targeted. I0' Full opening b~ll valve w/Hydraulic Actuator Cellar 20' DiverlPr Spool w/ 10' Side Oulle[ M E M 1 F3 ~D 0 iA( Jt~t. t'ltlO ro rlLJO t l &~J t r o~ D 1- l.'e[~o 41611 w/16 cones ,1Bll w/].6 co[les (Des].lter) 1 - t')]:i.1,.co AL:]T~ospl~e~ic Hud L~gasser [~'1~7T7 II[~ T;d.! r,. JJ ~0 -'[-,,,,~.~c J"- r^l/( Z 50 ~t. 5o d~L 1 - 200 gpli~ O~eraLlng CaDacLLy. CenL~lfuge 15 - BrandL t-~5 Hud 1.~[x Ag[Labors 1- 150 bl)l. Trip 'ra~k ].- Bem[d~ng ~ill/ng [luid pLL level t~di. caL~r with l~hl~ visual and audLo warbling.devices aL duilleu's mnsole 1- Drfl].l.ng fluid f lo,.1 s0nsor wit]~ readout at drlll%~f'.',s console AUDI #2 13 5/8" 5,000 psi Stack 2.00 4.12 12.72 4.50 . 3.01 3.01 ,f RKB 1 [ I RIG FLOOR DRIP PAN 17.88 HYDRIL PIPE RAM BLIND RAM 22.38 25.3 3.01 I 2.52 I MUD CROSS 1.5 PIPE RAM I MUD CROSS L 30.23 i34.25 GROUND L-\ -L BASE FLG / 35.75 AGI-3CI,,tT.XI_S State: WeE Field: State Permit Work Sheet: Date: N. Nin~f £en~! Volurr~ £alcd~tion,t Casing T.Vle Casing Size -ir~cl',es Casing Length - Feet Hole Diametef -Inches Cement- Sacks Cement- Yield Cement- Cubic ftt:11 Cement- Cubic It1:I1 Cement- Sacks ~12 Cement- Yield ~2 Cement- Cubic tt ~2 Cement-Cubic tt~2 Cement- Sacks $t3 Cement-Yield 1:I3 Cement- Cubic It Cement- Cubic it ~3 Cement- Cubi.'c ft /Vol Cement- Fill Factor Conducto~ '-"' 20.000 7E000 30.000 0.000 0.000 0.000 297.000 0.000 0.000 0. O00 0.000 297.000 1.433 Surface 13.375 4,035.000 16.000 1,1 48. 0O0 2.170 2,491.160 2,491.000 400.000 1.160 464.000 464.800 0.940 235.000 235.000 3,190. 000 1.880 Liner 7.000 812.000 8.500 137.000 1.200 164.400 164.400 0.000 0.000 0.000 0.000 164.400 1.597 Casing Type Casing Size -inches Casing Depth- Feet Hole Diameter -Inches Cerr~nt- S~cks ~Ii Cement-Yield :1:11 Cement- Cubic ft Cement- Cubic tt ~I1 Cement-Sacks I:I2 Cement- Yield Cement- Cubic ft~.2 Cernent - Cubic It :1:t2 Cement-Sacks :i:I3 Cema-Yield 1:I3 Cement- Cubic R ~3 Cement- Cubic It Cement- Cubic it / Vol Cement Interval ~t Top of Cement- Feet Inte~rr~diate 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~IDIV/0! I~DIV/0! Inte~mediate ~2 0.000 0.000 0.000 0.00 0.00 0.O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~IDIV/0! ~DIV/0! F~oduction 9.625 10,934.000 12.250 383.00 1.15 440.45 440.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 440.50 1,406.53 9,527.5 Measured Depth State: Alaska Borough: Well: AGI-3 Field: Prudhoe Bay St. Perm ~ 92-1,35 Dale 12./9/92 Engr: M. Minder AGI-3.×LS Casing Interval Interval Size Boflom Descriptionescriptionescription Tension Top LenCh 1A 13.,375 3500 29 4035 2A 9.625 8097 28 10906 8A 7 8540 7997 812 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Lbs Grade Thread Lbs 68 K-55 BTC 0 47 L-80 NSCC 0 26 L-80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mud Hydraulic Wieght Gradient ppg psi/ft 1B 9.5 0.494 2B 10.2 0.530 3B 9.5 0.494 4B 0.0 0.000 5B 0.0 0.000 6B 0.0 0.000 7B 0.0 0.000 8B 0.0 0.000 9B 0.0 0.000 1 OB 0.0 0.000 Maximum Minimum Pressure Yield psi psi BDF 3330 3450 1.0 8:380 6870 ?.1 3330 7240 2.2 0 o #DIVI0! 0 0 #DIM/0! 0 0 #DIVI0! 0 0 #DIV/O! 0 0 #DIVI0! 0 0 #DIM/0! o o #DIV/O! Tension Strength K/Lbs K/Lbs 1 C 274,38 1069 2C 512.582 1086 3C 21.112 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 TDF 3.90 2.12 604 28.61 0 #DIV/O! 0 #DIV/O! 0 #DIViO! 0 #DIM/0! 0 #DIM/El 0 #DIVI0! 0 #DIV/O.I Collapse Collapse Pr-Bot-Psi Resist. CBF 1729 1950 1.128 4295 4750 1.106 4219 5410 1.282 0 0 #DIV/0! 0 0 #DIVi0! 0 0 #DIV/O! 0 0 #DIM/0! 0 0 #DIVi0~ 0 0 #DIM/0! 0 0 #DIM/0! ** CHECK LIST FOR NEW WELL PERMITS ** ITEM AP.P~ROVE DATE Fee ~ ~c~ Loc 't~ i ~-~¢~ ~ [2 thru 8] (3) Admin [8],~, .13~~_] [9 ~bru [ 10 & 13] EI~ thru 22] (5) BOPE [23 thru 28] Company ,, /iq IL~.~ Lease & Well psu,. · 2. 3. 4. 5. 6. 7. 8. · 10. 11. 12. 13 14. 15. 16. 17. 18 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. YES NO Is permit fee attached ............................................... ~ . Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... ~L~ Is well located proper distance from other wells ..................... ~.~ Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... _~ . Does well have a unique name & number ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~/C Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... ~/~t' .. Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... ~,~." Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ /f'~¢ Is drilling fluid program schematic & list of equipment adequate ..... /f/~ Are necessary diagrams & descriptions of diverter & BOPE attached .... ~_ Does BOPE have sufficient pressure rating -- test to ~-~ psig ..... ~ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... REMARKS (6) Other [29 thru 31] (7) Contact . [32 ] (8) Addl geo 1 ogy' eng i nee r i ng' DWJ MTM~ ~ tX-~° rev 08/18/~2 jo/fi. 011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... Additional requirements Additional remarks' INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE 0 TZ ~"-, 0 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 simpl.ify finding information, informati;3n of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. LIS VERIFICATION LISTING FOR: ARCO ALASKA AGI-3 PRUDHOE BAY RECEIVED OCT 1 9 199,~ Alaska 0il & Gas Cons. Commission Anchorage ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM Note: BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR ARCO ALASKA AGI-3 Attenuation Borehole Corrected [RWD] Attenuation Dielectric Corrected [RWD] Conductivity (AT) Dielectric Corrected [RWD] Conductivity (PD) Dielectric Corrected [RWD] Calculated Dielectric Constant Gamma Ray MEMORY (APl) [RWD] Phase Difference Borehole Corrected [RWD] Phase Difference Dielectric Corrected [RWD] Phase Difference Elapsed Time [RWD] Resistivity (AT) Borehole Corrected [RWD] Resistivity (AT) Corrected for Dielectric Effect [RWD] Rate of Penetration Averaged Rate of Penetration Resistivity (PD) Borehole Corrected [RWD] Resistivity (PD) Corrected for Dielectric Effect [RWD] CDS Temperature [RWD] -dB -dB mmho/m mmho/m MWD-API deg deg mins ohm-m ohm-m fi/hr fi/hr ohm-m ohm-m deg F AT is Attenuation PD is Phase Difference RWD is Recorded While Drilling Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 2.64 Start of execution: Tue 14 SEP 93 2:21p != = ECHOING INPUT PARAMETERS= INPUT PARAMETER FILE: TAPESCAN.INP 1 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 1 AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, I=ON 2 AUTOFILE = 0 , ! Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = 1 , ! Decode LIS Comment records: 0=OFF, I=ON 4 INFORECS = I , ! Decode LIS Information records: 0=NO, I=YES 5 LISTMETHOD = 0 , ! Listing Method: 0=depth units 1=tape units 6 LISTFREQ = 50, ! Listing Frequency: Every n units 7 LISTMAX = 0 , ! Listing Maximum (0=no limit, value=list limit) 8 STATS = 0 , !Statistics generation: 0=OFF, I=ON 9 FORCETYP = 0 , ! (I=BIT,2=LIS ... thru 35=ArrayAccoustic) (see table) 10 WRITEASCll = 0 , ! If 1, all ascii files will be written (file0001.dat,etc.) 11 WRITETAP = I , ! WriteTape-lmage File: 0=NO, I=YES 12 SPLITLIS = 1 , ! If 1 and WRITETAP on, split LIS logical files to physical 13 SUBFILES = /0/, ! Tape Subfile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END != = USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = 1 , INFORECS = 1 , LISTMETHOD = 0 , LISTFREQ = 50, LISTMAX = 0 , STATS = 0, FORCETYP = 0 , WRITEASCII = 0 , WRITETAP = 1 , SPLITLIS = 1 , SUBFILES /0/, INTERPOLATE = 'YES' END !-- PROCESSING INTERVAL FROM 0.000 TO 0.000 ............. CONSTANT PARAMETERS AUTOCURV= O.O00000E+O0 AUTOFILE= O.O00000E+O0 COMMENTS= 1.00000 FORCETYP= 0.000000E+00 INFORECS= 1,00000 LISTFREQ= 50.0000 LISTMAX = O.O00000E+O0 LISTMETH= O.O00000E+O0 SELFTEST= O.O00000E+O0 SPLITLIS= 1.00000 STATS = 0.000000E+00 WRITEASC= 0.000000E+00 WRITETAP= 1.00000 dpcoef = 1,00000 dpcte = 1.00000 ddength= 0.000000E+00 listwave= 0,000000E+00 maxrecln= O,O00000E+O0 minrecln= 0.000000E+00 nsamples= 0.000000E+00 numcurvs= O.O00000E+O0 numdatar= 0.000000E +00 numrecfl = O.O00000E + O0 tfendep = 0,000000E + O0 tflevsp = 0.000000E+00 ffstdep = 0.000000E+00 wcrbot = O.O00000E+O0 wcflevsp= 0.000000E+00 wcrtop = O.O00000E +00 !-- ARRAY PARAMETERS ............................................. SUBFILES(1) = O.O00000E+O0 SUBFILES(3) =-9999.00 SUBFILES(5) =-9999.00 SUBFILES(7):-9999.00 SUBFILES(9):-9999.00 SUBFILES(11) = -9999.00 SUBFILES(13) = -9999.00 SUBFILES(15) = -9999.00 SUBFILES(17) = -9999.00 SUBFILES(19) = -9999.00 SUBFILES(21) = -9999.00 SUBFILES(23) = -9999.00 SUBFILES(25) = -9999.00 SUBFILES(27) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES(31) = -9999.00 SUBFILES(33) = -9999.00 SUBFILES(35) = -9999.00 SUBFILES(37) = -9999.00 SUBFILES(39) = -9999.00 SUBFILES(41) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(45) = -9999.00 SUBFILES(47) = -9999,00 SUBFILES(49) = -9999.00 SUBFILES(51) = -9999.00 SUBFILES(53) ---9999.00 SUBFILES(55) = -9999.00 SUBFILES(57) = -9999.00 SUBFILES(59) = -9999,00 SUBFILES(61) = -9999.00 SUBFILES(63) = -9999.00 SUBFILES(65) = -9999.00 SUBFILES(67) ---9999.00 SUBFILES(69) = -9999.00 SUBFILES(71) = -9999.00 SUBFILES(73) = -9999.00 SUBFILES(75) = -9999.00 SUBFILES(77) = -9999.00 SUBFILES(79) = -9999,00 SUBFILES(81) = -9999.00 SUBFILES(83) = -9999.00 SUBFILES(85) = -9999,00 SUBFILES(87) = -9999,00 SUBFILES(89) = -9999.00 SUBFILES(91) = -9999.00 SUBFILES(2) =-9999.00 SUBFILES(4) =-9999.00 SUBFILES(6) =-9999.00 SUBFILES(8) =-9999.00 SUBFILES(10) = -9999.00 SUBFILES(12) = -9999.00 SUBFILES(14) = -9999.00 SUBFILES(16) = -9999.00 SUBFILES(18) = -9999.00 SUBFILES(20) -- -9999.00 SUBFILES(22) = -9999.00 SUBFILES(24) - -9999.00 SUBFILES(26) = -9999.00 SUBFILES(28) = -9999,00 SUBFILES(30) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(34) = -9999.00 SUBFILES(36) = -9999.00 SUBFILES(38) = -9999.00 SUBFILES(40) = -9999.00 SUBFILES(42) = -9999.00 SUBFILES(44) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(50) = -9999,00 SUBFILES(52) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(56) = -9999,00 SUBFILES(58) = -9999.00 SUBFILES(60) -- -9999,00 SUBFILES(62) - -9999.00 SUBFILES(64) = -9999.00 SUBFILES(66) = -9999.00 SUBFILES(68) = -9999.00 SUBFILES(70) = -9999.00 SUBFILES(72) = -9999.00 SUBFILES(74) = -9999.00 SUBFILES(76) = -9999.00 SUBFILES(78) = -9999.00 SUBFILE$(80) = -9999.00 SUBFILES(82) = -9999.00 SUBFILES(84) = -9999.00 SUBFILES(86) = -9999.00 SUBFILES(88) = -9999.00 SUBFILES(90) = -9999.00 SUBFILES(92) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(94) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(97) = -9999.00 SUBFILES(98) = -99cJ9.00 SUBFILES(99) = -9999.00 SUBFILES(IO0) = -9999.00 SUBFILES(101) = -9999.00 SUBFILES(102) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(106) = -9999.00 SUBFILES(107) = -9999.00 SUBFILES(108) = -9999.00 SUBFILES(109) -- -9999.00 SUBFILES(110) = -9999.00 SUBFILES(111) = -9999.00 SUBFILES(112) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(116) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(118) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(120) = -9999.00 SUBFILES(121) = -9999.00 SUBFILES(122) = -9999.00 SUBFILES(123) -- -9999.00 SUBFILES(124) -- -9999.00 SUBFILES(125) = -9999.00 SUBFILES(126) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(128) = -9999.00 !-- STRING PARAMETERS ........................................ INTERPOL= YES Input Tape Device, LU (1) is: TAPEC: Output Tape-Image file, LU (2) is: J:\1163\1163.TAP (Output Tape-Image file will be created) Listing Method ("LISTMETH") = 0, Depth Unit oriented listing. Listing Frequency ("LISTFREQ") is every ( 50) units of Depth. Listing output limiting (LISTMAX) not enabled... (to enable list limiting set LISTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS = 1 to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE=n" card generation is disabled. (This is the program default, AUTOFILE=0) (Specify AUTOFILE= 1 to enable this feature) LIS comment record decoding (COMMENTS= 1) has been enabled by user input. LIS information record decoding (INFORECS=I) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC= 1) Tape Subfile 1 is type: LIS **** REEL HEADER **** MWD 93/9/14 1163 01 **** TAPE HEADER **** MWD 93/9/14 1163 01 Tape Subtile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subtile 2 is type: LIS LIS COMMENT RECORD(s)' 12345678901234567890123456789012345678901234567890123456789012345678901234567890 TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: APl NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA AGI-3 50-029-22318 Arco Alaska Inc. BAKER HUGHES INTEQ 14 SEP 93 BIT RUN1 BIT RUN2 BIT RUN3 JOB NUMBER: 1163 1163 1163 LOGGING ENGINEER: R. ST.PIERRE P. SMITH R. ST.PIERRE OPERATOR WITNESS: S. WALLS S. WALLS S. WALLS BIT RUN4 BIT RUN5 BIT RUN6 JOB NUMBER: 1163 1163 1163 LOGGING ENGINEER: P. SMITH D. LENTZ S. BURKHARDT OPERATOR WITNESS: G. COOPER S. WALLS S. WALLS 37.00 8.00 31 12N 15E # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1819 2432 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 30.000 20.000 106.0 2ND STRING 16.000 13.375 4060.0 3RD STRING 12.250 9.625 10935,0 PRODUCTION STRING 8.500 REMARKS: $ **** FILE HEADER **** MWD ,001 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH MWD 8347.0 11540.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) - ....... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD MWD MWD MWD MWD MWD $ REMARKS: $ CN WN FN COUN STAT 4 8347.O 9140.0 5 9140.0 9595.0 6 9595.0 10250.0 7 10250.0 10885.0 7 10913.0 11371.0 8 11371.0 11540.0 : Arco Alaska Inc. : AGI-3 : Prudhoe Bay : North Slope :Alaska LIS COMMENT RECORD(s)' 123456789012345678,90123456789012345678901234567890123456789012345678901234567890 THIS FILE CONSISTS OF EDITED MERGED MWD DATA. * FORMAT RECORD ('rYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 910111213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 4 16 Sum: 4 16 16 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 GR MWD 68 1 GAPI 4 2 RA MWD 68 1 OHMM 4 3 ROP MWD 68 I FPHR 4 4 RP MWD 68 1 FPHR 4 16 498660 71 6 49866O 71 6 4 98660 71 6 498660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 50 FRAMES * DATA RECORD (TYPE# O) 1006 BYTES * Total Data Records: 128 Tape File Start Depth = 8347.000000 Tape File End Depth = 11540.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7164 datums Tape Subtile: 2 206 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** MWD .002 1 O24 LIS COMMENT RECORD(s): 12345678`9012345678901234567890123456789012345678`90123456789012345678901234567890 FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8347.0 9140.0 $ LOG HEADER DATA DATE LOGGED: 26 DEC 92 SOFTWARE SURFACE SOFTWARE VERSION' M1.33 DOWNHOLE SOFTWARE VERSION: M1.33 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT)' 0.0 TOP LOG INTERVAL (F'r): 8347.0 BOTTOM LOG INTERVAL (FT): 9140.0 BIT ROTATING SPEED (RPM)' 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 49.7 MAXIMUM ANGLE: 51,3 TOOL STRING (TOP TO BO'I-rOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 0.0 BOREHOLE CONDITIONS MUD TYPE: DISPERSED MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S): 42.0 MUD PH: 9,5 MUD CHLORIDES (PPM): 1450 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) TOOL NUMBER 2245-38 MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.000 MUD FILTRATE AT MT: 0.000 0,0 MUD CAKE AT MT: 0.000 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: $ CN :Arco Alaska Inc. WN : AGI-3 FN : Prudhoe Bay COUN : North Slope STAT :Alaska 0.0 0.0 LIS CO~,~'.:~,ENT RECORD(s): 12345(~ :) 1234567890123456789012345678901234567890123456789012345678901234567890 THIS FILF_ CONSISTS OF RAW MWD DATA FROM BIT RUN 4. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 ATCMMWD 68 1 -dB 4 4 98 660 71 6 2 ATDCMWD 68 1 -dB 4 4 98 660 71 6 3 CADEMWD 68 1 MMHO 4 4 98 660 71 6 4 CPDEMWD 68 1 MMHO 4 4 98 660 71 6 5 DCCMMWD 68 1 4 4 98 660 71 6 6 GRAMMWD 68 1 GAPI 4 4 98 660 71 6 7 PDCMMWD 68 1 DEG 4 4 98 660 71 6 8 PDDCMWD 68 1 DEG 4 4 98 660 71 6 9 PDEMMWD 68 1 MINS 4 4 98 660 71 6 10 RACMMWD 68 1 OHMM 4 4 98660 71 6 11 RADE MWD 68 1 OHMM 4 4 98 660 71 6 12 ROPAMWD 68 1 FPHR 4 4 98 660 71 6 13 ROPSMWD 68 1 FPHR 4 4 98660 71 6 14 RPCMMWD 68 1 OHMM 4 4 98 660 71 6 15 RPDE MWD 68 1 OHMM 4 4 98 660 71 6 16 TCDMMWD 68 1 DEGF 4 4 98 660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 227 Tape File Start Depth = 8347.000000 Tape File End Depth = 9140.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7094 datums Tape Subtile: 3 291 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 4 is type: LIS **** FILE HEADER **** MWD .003 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 3 RAW MWD Curves and Icg header data for each bit run in separate files. BIT RUN NO: 5 .... DEPTH INCREMENT: 0.2500 # FILE SUMMARY _ VENDOR TOOL CODE START DEPTH MWD 9140.0 9595.0 $ 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): BO'I-I'OM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 27 DEC 92 M1.33 M1.33 MEMORY 0.0 9140.0 9595.0 0 52.0 53.0 TOOL STRING (TOP TO BO'i-rOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 2247-39 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 0.0 BOREHOLE CONDITIONS MUD TYPE: DISPERSED MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S): 4.0 MUD i~H: 9,2 MUD CHLORIDES (PPM): 1100 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.000 MUD FILTRATE AT MT: 0.000 0.0 MUD CAKE AT MT: 0.000 0.0 0.0 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0,0 0 REMARKS: INTERVAL FROM 9140 TO 9194' (6816 TO 6850' TVD) WAS LOGGED 9 HOURS AFTER BEING DRILLED. $ CN :Arco Alaska Inc. WN : AGI-3 FN : Prudhoe Bay COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 123456789012345678,9012345678901234567890123456789012345678,9012345678901234567890 THIS FILE CONSISTS OF RAW MWD DATA FROM BIT RUN 5. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(68) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 ATCM MWD 68 1 -dB 4 2 ATDC MWD 68 I -dB 4 3 CADE MWD 68 1 MMHO 4 4 CPDE MWD 68 1 MMHO 4 5 DCCM MWD 68 1 4 6 GRAM MWD 68 1 GAPI 4 7 PDCM MWD 68 1 DEG 4 8 PDDC MWD 68 1 DEG 4 9 PDEM MWD 68 1 MINS 4 10 RACMMWD 68 1 OHMM 4 11 RADEMWD 68 1 OHMM 4 12 ROPAMWD 68 1 FPHR 4 13 ROPS MWD 68 1 FPHR 4 14 RPCMMWD 68 1 OHMM 4 15 RPDE MWD 68 1 OHMM 4 16 TCDMMWD 68 1 DEGF 4 498660 71 6 498660 71 6 4 98660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 498660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES * Total Data Records: 131 Tape File Start Depth = 9140.000000 Tape File End Depth = 9595.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11258 datums Tape Subfile: 4 196 records.., Minimum record length: Maximum record length: 62 bytes 958 bytes Tape Subfile 5 is type: LIS **** FILE HEADER **** MWD .004 1024 LIS COMMENT RECORD(s): 123456789012345678901234567~ 12345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 9595.0 10250.0 $ '-~ LOG HEADER DATA DATE LOGGED: SOFTWARE ,_ SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (F-r)' '~- TOP LOG INTERVAL (FT): BO'FrOM LOG INTERVAL (F-I'): BIT ROTATING SPEED (RPM): -, HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BO'I-rOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ STOP DEPTH 29 DEC 92 M1.33 M1.33 MEMORY 0.0 9595.0 10250.0 0 41.0 49.3 TOOL NUMBER 2247-39 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN)' DRILLER'S CASING DEPTH (FT): 12.250 0.0 BOREHOLE CONDITIONS MUD TYPE: DISPERSED MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 41.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 850 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.000 MUD FILTRATE AT MT: 0.000 0,0 MUD CAKE AT MT: 0.000 0.0 0,0 0,0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12.250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 9595 TO 9649' (7093 TO 7126' 'I'VD) WAS LOGGED 10 HOURS AFTER BEING DRILLED. $ CN :Arco Alaska Inc. WN : AGI-3 FN : Prudhoe Bay COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678,90123456789012345678,90123456789012345678,90123456789012345678901234567890 THIS FILE CONSISTS OF RAW MWD DATA FROM BlT RUN 6. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0 0 0 00 0 0 1 0 0 0 1 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod 1 ATCM MWD 68 1 -dB 4 2 ATDC MWD 68 1 -dB 4 3 CADE MWD 68 1 MMHO 4 4 CPDE MWD 68 1 MMHO 4 $ DCCM MWD 68 1 4 6 GRAM MWD 68 1 GAPI 4 7 PDCM MWD 68 1 DEG 4 8 PDDC MWD 68 1 DEG 4 9 PDEM MWD 68 I MINS 4 10 RACMMWD 68 1 OHMM 4 11 RADEMWD 68 1 OHMM 4 12 ROPAMWD 68 1 FPHR 4 13 ROPSMWD 68 1 FPHR 4 14 RPCMMWD 68 I OHMM 4 15 RPDEMWD 68 1 OHMM 4 16 TCDMMWD 68 1 DEGF 4 4 98660 71 6 49866O 71 6 498660 71 6 498660 71 6 49866O 71 6 498660 71 6 4 98660 71 6 49866O 71 6 49866O 71 6 498660 71 6 49866O 71 6 498660 71 6 49866O 71 6 498660 71 6 49866O 71 6 4 9866O 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES * Total Data Records: 188 Tape File Start Depth = 9595,000000 Tape File End Depth = 10250.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12964 datums Tape Subfile: 5 253 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile 6 is type: LIS **** FILE HEADER **** MWD .005 1024 LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH -- MWD 10250.0 $ 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 INCUNATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 10885.0 STOP DEPTH 3O DEC 92 M1.33 M1,33 MEMORY 0.0 10250.0 10885.0 0 40.1 40.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ TOOL NUMBER 2247-39 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 0.0 BOREHOLE CONDITIONS MUD TYPE: DISPERSED MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 42.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 0,000 MUD AT MAX CIRCULATING TEMPERATURE: 0.000 MUD FILTRATE AT MT: 0.000 0,0 MUD CAKE AT MT: 0.000 0.0 0.0 0,0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 12,250 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 1050 TO 1030' (7545 TO 7585' TVD) WAS LOGGED 11.5 HOURS AFTER BEING DRILLED. $ CN : Arco Alaska Inc. WN : AGI-3 FN : Prudhoe Bay COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 1234567890123456789012345678.90123456789012345678.90123456789012345678901234567890 THIS FILE CONSISTS OF RAW MWD DATA FROM BIT RUN 7., * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 910111213141516 000 1 000 0000 1 000 1 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: APl APl APl APl Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ CIs Mod I ATCM MWD 68 1 -dB 4 2 ATDC MWD 68 1 -dB 4 3 CADE MWD 68 1 MMHO 4 4 CPDE MWD 68 1 MMHO 4 5 DCCM MWD 68 1 4 6 GRAM MWD 68 1 GAPI 4 7 PDCM MWD 68 1 DEG 4 8 PDDC MWD 68 1 DEG 4 9 PDEM MWD 68 I MINS 4 10 RACM MWD 68 I OHMM 4 11 RADEMWD 68 1 OHMM 4 12 ROPA MWD 68 1 FPHR 4 13 ROPS MWD 68 I FPHR 4 14 RPCMMWD 68 1 OHMM 4 15 RPDE MWD 68 I OHMM 4 16 TCDMMWD 68 1 DEGF 4 49866O 71 6 498660 71 6 498660 71 6 498660 71 6 49866O 71 6 498660 71 6 498660 71 6 498660 71 6 49866O 71 6 4 98660 71 6 49866O 71 6 498660 71 6 498660 71 6 49866O 71 6 498660 71 6 49866O 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES * Total Data Records: 182 Tape File Start Depth = 10250.000000 Tape File End Depth = 10885.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16936 datums Tape Subtile: 6 247 records... Minimum record length: Maximum record length: 62 bytes 958 bytes Tape Subfile 7 is type: LIS **** FILE HEADER **** MWD .006 1024 LIS COMMENT RECORD(s): 12345678,9012345678,9012345678,9012345678901234567890123456789012345678901234567890 FILE HEADER FILE NUMBER: 6 RAW MWD Curves and Icg header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 10913.0 11371.0 $ LOG HEADER DATA DATE LOGGED: 09 APR 93 SOFTWARE SURFACE SOFTWARE VERSION: M1.33 DOWNHOLE SOFTWARE VERSION: M1.33 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 0.0 TOP LOG INTERVAL (FT): 10913.0 BOTTOM LOG INTERVAL (FT): 11371.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 40.4 MAXIMUM ANGLE: 41.2 TOOL STRING (TOP TO BO'I-rOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL FLOPRO MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 0.0 MUD PH: 0.0 MUD CHLORIDES (PPM): 41000 FLUID LOSS (0,3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) TOOL NUMBER 1639-35 MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.000 MUD FILTRATE AT MT: 0.000 0.0 MUD CAKE AT MT: 0.000 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: $ CN : Arco Alaska I nc, WN : AGI-3 FN : Prudhoe Bay COUN : North Slope STAT :Alaska 0.0 0.0 LIS COMMENT RECORD(s): 123456789012345678,90123456789012345678901234567890123456789012345678901234567890 THIS FILE CONSISTS OF RAW MWD DATA FROM BIT RUN 7. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 0000000 1 000 1 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 ATOM MWD 68 1 -dB 2 ATDC MWD 68 I -dB 3 CADE MWD 68 1 MMHO 4 CPDE MWD 68 1 MMHO 5 DCCM MWD 68 1 6 GRAM MWD 68 1 GAPI 7 PDCM MWD 68 1 DEG 8 PDDC MWD 68 1 DEG 9 PDEM MWD 68 1 MINS 10 RACMMWD 68 1 OHMM 11 RADE MWD 68 1 OHMM 12 ROPAMWD 68 1 FPHR 13 ROPSMWD 68 1 FPHR 14 RPOMMWD 68 1 OHMM 15 RPDE MWD 68 1 OHMM 16 TCDMMWD 68 1 DEGF APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod 4 498660 71 6 4 49866O 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 49866O 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES* Total Data Records: 131 Tape File Start Depth = 10913.000000 Tape File End Depth = 11371.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17070 datums Tape Subfile: 7 195 records,., Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subtile 8 is type: LIS **** FILE HEADER **** MWD .007 1024 LIS COMMENT RECORD(s): 123456789012~7~123456789012345678901234567~1234567~1234567~12345678~ FILE HEADER FILE NUMBER: 7 RAW MWD Curves and Icg header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 11371.0 11540.0 $ LOG HEADER DATA DATE LOGGED: 10 APR 93 SOFTWARE SURFACE SOFTWARE VERSION: M1.33 DOWNHOLE SOFTWARE VERSION' M1.33 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 0.0 TOP LOG INTERVAL (FI'): 11371.0 BO~-I'OM LOG INTERVAL (F'F): 11540.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 39,9 MAXIMUM ANGLE: 40.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE MWD DUAL PROPAGATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 0.0 BOREHOLE CONDITIONS MUD TYPE: KCL FLOPRO MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 0.0 MUD PH: 0.0 MUD CHLORIDES (PPM): 40000 FLUID LOSS (C3): 0.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) TOOL NUMBER 1639-35 MUD AT MEASURED TEMPERATURE (MT): 0.000 MUD AT MAX CIRCULATING TEMPERATURE: 0.000 MUD FILTRATE AT MT: 0,000 0.0 MUD CAKE AT MT: 0.000 0.0 0.0 0.0 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): 8.500 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.0 0 REMARKS: INTERVAL FROM 11371 TO 11393' (8398 TO 8421' TVD) WAS LOGGED 10.5 HOURS AFTER BEING DRILLED, INTERVAL FROM 11518 TO 11540' (8509 TO 8521' TVD) WAS NOT LOGGED DUE TO BIT TO SENSOR OFFSET, NO RESISTIVITY DATA DUE TO SENSOR MALFUNCTION, $ CN : Arco Alaska I nc, WN : AGI-3 FN : Prudhoe Bay COUN : North Slope STAT :Alaska LIS COMMENT RECORD(s): 12345678.9012345678901234567890123456789012345678.90123456789012345678.9012345678.90 THIS FILE CONSISTS OF RAW MWD DATA FROM BIT RUN 8. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 91011 1213141516 000 1 00000 O0 1 000 1 Rep Code Count Bytes 68 16 64 Sum: 16 64 64 fndun a [F ] 1.0(X)O0000 ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units APl APl APl APl Log Crv Crv Size Length Typ Typ CIs Mod I ATCM MWD 68 I -dB 2 ATDC MWD 68 I -dB 3 CADE MWD 68 1 MMHO 4 CPDE MWD 68 I MMHO 5 DCCM MWD 68 1 6 GRAM MWD 68 1 GAPI 7 PDCM MWD 68 1 DEG 8 PDDC MWD 68 1 DEG 9 PDEM MWD 68 1 MINS 10 RACMMWD 68 1 OHMM 11 RADEMWD 68 1 OHMM 12 ROPAMWD 68 1 FPHR 13 ROPS MWD 68 1 FPHR 14 RPCMMWD 68 I OHMM 15 RPDEMWD 68 1 OHMM 16 TCDMMWD 68 1 DEGF 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 49866O 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 49866O 71 6 4 49866O 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 498660 71 6 4 49866O 71 6 ** Routine LEVONE detects data discrepancy: DSB indicates: 1 FRAMES Data Record Length indicates: 14 FRAMES * DATA RECORD (TYPE# O) 958 BYTES * Total Data Records: 49 Tape File Start Depth = 11371.000000 Tape File End Depth = 11540.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18478 datums Tape Subfile: 8 119 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 9 is type: LIS **** TAPE TRAILER **** MWD 93/9/14 1163 01 **** REEL TRAILER **** MWD 93/9/14 1163 01 Tape Subtile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 14 SEP 93 2:22p Elapsed execution time = I minute, 19.5 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH GR ROP RP 8347.0000 -999.2500 -999.2500 -999.2500 -999.2500 8347.5000 32.8041 -999.2500 -999.2500 -999.2500 8350.0000 43.2376 -999.2500 -999.2500 -999.2500 8400.0000 40.7773 1.7964 -999.2500 1.71 71 8450.0000 68.8945 5.3402 28.1261 4.9804 8500.0000 53.1391 2.5764 48.7897 2.2965 8550.0000 63.5344 -999.2500 29.9937 -999.2500 8600.0000 87.8256 -999.2500 20.0115 -999.2500 8650.0000 52.7242 -999.2500 122.0703 -999.2500 8700.0000 55.3410 -999.2500 79.6111 -999.2500 8750.0000 62.2139 -999.2500 61.051 7 -999.2500 8800.0000 75.5255 -999.2500 14.4060 -999.2500 8850.0000 50.1690 -999.2500 93.1842 -999.2500 8900.0000 74.8807 -999.2500 13.4636 -999.2500 8950.0000 61.4488 -999.2500 53.6952 -999.2500 9000.0000 77.4172 -999.2500 44.8593 -999.2500 9050.0000 76.4665 -999.2500 39.8189 -999.2500 9100.0000 103.4498 -999.2500 20.4587 -999.2500 9150.0000 86.8245 8.0040 24.7440 6.3598 9200.0000 93.6438 8,0119 43.5965 6.3586 9250.0000 86.9216 8.2966 42.6974 6.5332 9300.0000 95.4785 8.5242 48.7897 6.5758 9350,0000 81.9047 13.2881 43.0836 9.9692 9400.0000 86.5314 13.3247 33.7513 9.2835 9450.0000 85.4391 10.4156 39.3765 7.4716 9500.0000 85.3342 10.7850 22.7172 7.3485 9550.0000 86.9467 14.6495 22.7172 10.9253 9600,0000 86.6917 11,7782 45.2112 8.2592 9650.0000 79.9145 12.7304 58.1287 9.4857 9700.0000 79.9743 11.8812 20.5737 8.4957 9750.0000 81.9905 10.0919 23.01 40 7.3351 9800.0000 64.3074 10.8251 24.9123 7.9822 9850.0000 84.5272 9.6604 25.4956 6.8259 9900.0000 66.3107 11.1005 25.3714 8.9437 9950.0000 95.1115 5.8220 25.1339 4.8346 10000.0000 99.7253 7.3652 25.4113 5.7626 10050.0000 91.9899 7.8895 33.2657 6.1356 10100.0000 98.3220 8.6754 25.8678 6.3444 10150.0000 90.5220 2.4417 26.9061 3.1707 10200.0000 92.6659 7.8946 28.5797 5.7517 10250.0000 83.1576 8.5794 26.6457 6.4677 10300.0000 91.7383 7.7966 23.1597 6.2637 10350.0000 94.9210 5.3687 85.4600 4.8731 10400.0000 135.1793 6.3087 77.9172 4.9934 10450.0000 101.3092 16.6727 80.5428 11.7094 10500.0000 131.6019 26.5328 75.4018 13.3549 10550.0000 123.5026 11.1778 42.7631 7.6800 10600.0000 120.5284 13.4304 126.5673 7.1609 10650.0000 85.9714 10.2390 47.8513 6.9768 10700.0000 133.2970 5.0079 79.6111 4.3358 10750.0000 142.2325 6.2500 77.9135 5.5713 10800.0000 174.6923 8.1163 99.1200 6.0918 10850.0000 158.7719 10.2702 51.1292 7.4234 10900.0000 -999.2500 -999.2500 121.9742 -999.2500 10950.0000 86.1125 20.4456 80.4700 32.6315 11000.0000 26.4057 -999.2500 76.2900 99.1073 11050.0000 14.8684 -999.2500 51.5700 176.5359 11100.0000 16.2316 -999.2500 42.7000 233.8028 11150.0000 22.1106 -999.2500 47.5600 263.2363 11200.0000 19.1449 -999.2500 67.8100 51.1206 11250.0000 41.0380 -999.2500 17.8600 14.0077 11300.0000 17.3373 -999.2500 39.4500 54.0311 11350.0000 95.4320 13.2064 9.6301 7.8224 11400.0000 51.7523 -999.2500 36.9155 47.8081 11450.0000 45.6316 -999.2500 32.6717 -999.2500 11500.0000 123.3262 -999.2500 10.8582 -999.2500 11540.0000 -999.2500 -999.2500 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100.5167 5.8795 5.3402 25.9525 28.1261 4.7890 4.9804 110.8625 8500.0000 1.3180 1.3777 388.1356 435.4489 151.0576 53.1391 16.7849 16.4804 95.3333 2.7315 2.5764 45.7689 48.7897 2.2287 2.2965 113.3375 8550.0000 4.6989 -999.2500 -999.2500 -999.2500 -999.2500 63.5344 35.6180 -999.2500 155.8834 -999.2500 -999.2500 29.0480 29.9937 -999.2500 -999.2500 115.4750 8600.0000 9.8802 -999.2500 -999.2500 -999.2500 -999.2500 87.8256 51.5712 -999.2500 126.3000 -999.2500 -999.2500 20.0154 20.0115 -999.2500 -999.2500 119.8062 8650.0000 2.6080 -999.2500 -999.2500 -999.2500 -999.2500 52.7242 131.6033 -999.2500 69.9167 -999.2500 -999.2500 107.9358 122.0703 -999.2500 -999.2500 119.5250 8700.0000 2.5591 -999.2500 -999.2500 -999.2500 -999.2500 55.3410 47.1972 -999.2500 78.4833 -999.2500 -999.2500 69.5921 79.6111 -999.2500 -999.2500 121.5500 DEPTH ATOM ATDC CADE CPDE DOOM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 8750.0000 5.2395 -999.2500 -999.2500 -999.2500 -999.2500 62.2139 46.2143 -999.2500 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-999.2500 133.7000 9100.0000 8.0847 -999.2500 -999.2500 -999.2500 -999.2500 103.4498 54.2653 -999.2500 179.9167 -999.2500 -999.2500 24.4841 20.4587 -999.2500 -999.2500 132.6313 9140.0000 0.4729 0.5359 131.3492 164.1727 95.6969 88.3075 9.2131 8.9517 708.6166 8.9564 7.6133 25.1340 22.1946 5.8581 6.0911 136.6500 Tape File Start Depth = 6347.000000 Tape File End Depth = 9140.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS DEPTH ATOM ATDC CADE CPDE DOOM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 9140.0000 0.4729 0.5359 131.3492 164.1727 95.6969 88.3075 9.2131 8.9517 708.6166 8.9564 7.6133 25.1340 22.1946 5.8581 6.0911 136.8500 9140.2500 0.4708 0.5339 130.8101 164.1496 95.5398 86.8506 9.2119 8.9508 709.2832 8.9001 7.6447 25.1340 24.1542 5.8789 6.0920 136.7375 9150.0000 0.4475 0.5111 124.9377 157.2367 94.3781 86.8245 8.9594 8.6993 708.9166 9.2639 8.0040 31.7631 24.7440 6.0356 6.3598 137.4125 9200.0000 0.4476 0.5106 124.8139 157.2672 93.4875 93.6438 8.9579 8.7004 108.1323 9.4232 8.0119 43.8598 43.5965 6.1600 6.3586 123.7437 9250.0000 0.4303 0.4938 120.5313 153.0638 92.7807 86.9216 8.8010 8.5449 78.5156 9.6095 8.2966 43.6267 42.6974 6.2615 6.5332 122.1125 9300.0000 0.4171 0.4812 117.3131 152.0737 92.5129 95.4785 8.7648 8.5080 78.7324 9.9209 8.5242 47.7527 48.7897 6.3006 6.5758 125.9375 9350.0000 0.2460 0.3096 75.2554 100.3089 76.5790 81.9047 6.6299 6.3989 108.0484 16.6670 13.2881 46.7463 43.0836 9.4998 9.9692 127.6250 9400.0000 0.2430 0.3087 75.0488 107.7181 79.0736 86.5314 6.9606 6.7258 118.9000 16.8615 13.3247 31.8294 33.7513 8.8563 9.2635 130.7750 9450.0000 0.3300 0.3957 98.0099 133.8400 87.2608 85.4391 8.0559 7.8075 256.4833 12.5476 10.4156 39.8691 39.3765 7.1483 7.4716 133.9250 9500.0000 0.3150 0.3823 92.7209 136.0816 87.9232 85.3342 8.1450 7.8958 200.1333 13.1330 10.7850 23.1157 22.7172 7.0323 7.3485 13§.8500 DEPTH ATOM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 9550.0000 0.2165 0.2799 68.2619 91.5307 73.4930 86.9467 6.2231 5.9981 255.8000 18.7903 14.6495 22.7813 22.7172 10.3979 10.9253 137.9750 9595.0000 0.2320 0.2993 72.8123 110.0798 79.8586 83.1881 7.0651 6.8280 115.0156 17.6109 13.7339 45.7195 46.0245 8.6673 9.0843 134.0375 Tape File Start Depth = 9140.000000 Tape File End Depth = 9595.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 5 is type: LIS DEPTH ATCM ATDC CADE CPDE DCCM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 9595.0000 0.2320 0.2993 72.8123 110.0798 79.8586 83.1881 7.0651 6.8280 115.0156 17,6109 13.7339 45.7195 46.0245 8.6673 9.0843 134.0375 9595.2500 0.2513 0.3173 77.0864 117.1266 80.1521 85.3339 7.3614 7.1272 115.0117 16.9055 12.9725 45,7195 45.8212 8.5982 8.5378 134.1500 9600.0000 0.2838 0.3500 84.9026 121.0767 83.4658 86.6917 7.5353 7.2916 639.1666 14.4568 11.7782 56.5327 45.2112 7.8722 8.2592 135.6125 9650.0000 0.2594 0.3235 78.5524 105.4213 78.4842 79.9145 6.8607 6,6255 734.0167 15.9719 12.7304 47.5804 58.1287 9.0023 9.4857 140.9000 9700.0000 0.2814 0.3469 84.1669 117.7072 82.3961 79.9743 7.3922 7.1515 167.9333 14.5753 11.8812 19.2477 20.5737 8.0961 8.4957 129.3125 9750.0000 0.3427 0.4082 99.0896 136.3309 88.0697 81.9905 8.1535 7.9039 156.9667 12.0263 10.0919 21.3763 23.0140 7.0070 7.3351 132.9125 9800.0000 0.3158 0.3808 92.3781 125.2784 84.7645 84.3074 7.7075 7.4622 159.6166 13.0270 10.8251 23.1149 24.9123 7.6125 7.9822 135.8375 9850.0000 0.3599 0.4261 103.5158 146.5010 90.5622 64.5272 8.5490 8.2964 117.7500 11.4518 9.6604 24.7947 25.4956 6.5969 6.8259 138.4250 9900.0000 0.3087 0.3713 90.0858 111.8111 81.0064 66.3107 7.1396 6.9005 134.3167 13.3230 11.1005 25.0990 25.3714 8.4017 8.9437 140.9000 9950.0000 0.6239 0.6870 171.7616 206.8423 107.9241 95.1115 10.6840 10.4063 143.0667 6.5164 5.8220 25.2379 25.1339 4.5294 4.8346 142.9250 DEPTH ATOM ATDC CADE CPDE DOOM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 10000.0000 0.4891 0.5528 135.7727 173.5313 98.0085 99.7253 9.5458 9.2833 129.9000 8.1999 7.3652 26.1048 25.4113 5.5655 5.7626 144.6125 10050.0000 0.4540 0.5180 126.7503 162.9845 95.5755 91.9899 9.1671 8.9071 152.5667 9.0509 7.8895 29.9563 33.2657 5.8741 6.1356 145.9625 10100.0000 0.4073 0.4730 115.2690 157.6193 94.1270 98.3220 8.9706 8.7117 151.3333 10.1134 8.6754 36.8871 25.8678 6.0702 6.3~ 146.5250 10150.0000 1.3778 1.4379 409.5498 315.3848 155.8609 90.5220 13.9169 13.5643 142.4000 2.5758 2.4417 28.3724 26.9061 2.0876 3.1707 146.1875 10200.0000 0.4514 0.5177 126.6689 173.8607 98.9488 92.6659 9.5600 9.2948 125.0000 9.1685 7.8946 29.5004 28.5797 5.4527 5.7517 143.1500 10250.0000 0.4133 0.4781 116.5577 154.6149 93.2948 83.1576 8.8578 8.6008 117.9500 9.9646 8.5794 28.5858 26.6457 6.1874 6.4677 147.0875 Tape File Start Depth = 9595.000000 Tape File End Depth = 10250.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 6 is type: LIS DEPTH ATOM ATDC CADE CPDE DOOM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 10250.0000 0.4133 0.4781 116.5577 154.6149 93.2948 83.1576 8.8578 8.6008 117.9500 9.9646 8.5794 28.5858 26.6457 6.1874 6.4677 147,0875 10250.2500 0.4460 0.5089 124.4218 154.3974 93.2363 83.8939 8.8496 8.5927 135.6543 9.2147 8.0372 28,5658 27.9391 6.1958 6.4768 147,0875 10300.0000 0.4608 0.5239 128.2606 159.6491 94.6856 91.7383 9.0463 8.7860 773.1001 8.9135 7.7966 25.5494 23.1597 5.9935 6,2637 148.3250 10350.0000 0.6793 0.7391 186.2645 205.2086 106.2781 94.9210 10.6255 10.3533 103.3333 5.8953 5.3687 82.0002 65.4600 4.6802 4.8731 128.0750 10400.0000 0.5747 0.6384 158.5119 200.2650 105.0941 135.1793 10.4636 10.1916 48.9167 7.0665 6.3087 81.9222 77.9172 4.7934 4.9934 128.4125 10450.0000 O. 1798 0.2444 59.9782 65.4018 71.3307 101.3092 5.9269 5.7068 65.6824 22.1653 16.6727 84.0922 80.5428 11.1054 11.7094 132.0125 10500.0000 0.0758 0.1473 37.6892 74.8787 67.1672 131.6019 5.4007 5.1898 78.3792 47.1292 26.5328 61.7356 75.4018 12.6881 13.3549 133.4750 10550.0000 0.3018 0.3688 89.4633 130.2082 86.2722 123.5026 7.9398 7.6612 60.1163 13.6175 11.1778 53.0908 42.7631 7.3269 7.6800 136.5875 10600.0000 0.2319 0.3063 74.4582 139.6476 89.0539 120.5284 8.2874 8.0363 56.5823 17.5231 13.4304 97.5623 126.5673 6.8406 7.1609 138.0875 10650.0000 0.3351 0.4026 97.6656 143.3328 90.1270 85.9714 8.4323 8.1765 56.6333 12.2979 10.2390 45.1659 47.6513 6.6659 6.9768 139.6625 DEPTH ATOM ATDO CADE CPDE DOOM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPCM RPDE TCDM 10700.0000 0.7255 0.7867 199.6850 230.6388 112.2050 133.2970 11.4391 11.1593 47.9500 5.4831 5.0079 78.6473 79.6111 4.1696 4.3358 140.9000 10750.0000 0.5838 0.6442 159.9994 179.4909 99.9091 142.2325 9.7591 9.4939 358.8000 6.9508 6.2500 87.7829 77.9135 5.3410 5.5713 141.8000 10800.0000 0.4394 0.5044 123.2083 1 64.1549 95.9020 174.6923 9.21 43 8.9523 50.1833 9.3651 8.1163 99.1200 99.1200 5.8313 6.0918 125.1875 10850.0000 0.3357 0.4013 97.3693 134.7088 87.6038 158.7719 8.0920 7.8432 46.6500 12.2757 10.2702 57.2705 51.1292 7.0878 7.4234 133.8125 10885.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 115.3608 118.1295 -999.2500 -999.2500 135.7250 Tape File Start Depth = 10250.000000 Tape File End Depth = 10885.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 7 is type: LIS DEPTH ATOM ATDO CADE CPDE DOOM GRAM PDCM PDDC PDEM RACM RADE ROPA ROPS RPOM RPDE TCDM 10913.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 139.2673 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 117.3860 114.5556 -999.2500 -999.2500 136.7375 10913.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 141.8275 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 117.3860 116.4426 -999.2500 -999.2500 136.7656 10950.0000 0.1480 0.1935 48.9103 30.6453 46.7434 86.1125 2.7158 2.5618 10.2167 25.5417 20.4456 79.8287 80.4700 28.9937 32.6315 113.3214 11000.0000 -999.2500 -999.2500 -999.2500 10.0901 30.8767 26.4057 1.0596 0.9680 3.7000 -999.2500 -999.2500 74.2612 76.2900 80.5725 99.1073 111.7625 11050,0000 -999.2500 -999.2500 -999.2500 5.6646 25.6970 14.8684 0.6214 0.5527 7.2667 -999.2500 -999.2500 54.0187 51.5700 132.6296 176.5359 111.5375 11100.0000 -999.2500 -999.2500 -999.2500 4.2771 23.7473 16.2316 0.4734 0.4133 4.9000 -999.2500 -999.2500 41.6162 42.7000 166.5797 233.8028 111.0875 11150.0000 -999.2500 -999.2500 -999.2500 3.7989 20.2429 22.1106 0.4124 0.3640 2.2722 -999.2500 -999.2500 50.1700 47.5600 274.2067 263.2363 111.0875 11200.0000 -999.2500 -999.2500 -999.2500 19.5616 39.1934 19.1449 1.8811 1.7549 4.1000 -999.2500 -999.2500 61.3675 67.8100 44.1748 51.1206 110.8625 11250.0000 -999.2500 -999.2500 -999.2500 71.3892 66.3790 41.0380 5.1407 4.9293 3.3583 -999.2500 -999.2500 26.4362 17.8600 13.0257 14.0077 111.3000 11300.0000 -999.2500 -999.2500 -999.2500 18.5079 38.1094 17.3373 1.7676 1.6456 6.1500 -999.2500 -999.2500 40.4400 39.4500 47.3119 54.0311 112.2125 DEPTH ATOM ATDO CADE CPDE DOOM GRAM PDOM PDDC 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-999.2500 -999.2500 46.3513 45.6316 2.5528 2.3998 24.9333 -999.2500 -999.2500 40.2550 32.6717 29.5731 -999.2500 111.8750 11500.0000 0.4790 0.5482 -999.2500 -999.2500 105.9495 123.3262 10.2022 9.9239 100.5500 8.2648 -999.2500 10.5299 10.8582 4.7112 -999.2500 117.5375 11540.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.6743 10.6743 -999.2500 -999.2500 123.6393 Tape File Start Depth = 11371.000000 Tape File End Depth = 11540.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subfile 9 is type: LIS