Alaska Logo
Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
Loading...
HomeMy WebLinkAbout193-0237. 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 03-25a Install new tbg Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-023 50-029-21021-01-00 12395 Conductor Surface Intermediate Production Liner 9262 80 2507 8767 3728 11802 20" 13-3/8" 9-5/8" 7" 8482 26 - 106 26 - 2533 24 - 8791 8667 - 12395 27 - 107 26 - 2507 24 - 6686 6599 - 9262 11794 , 11823 , unknown 470 2670 4760 7020 11802 , 11839 , 11844 1490 5380 6870 8160 11476 - 12076 5-1/2" 17# x 4- 1/ 2" 12.6# L-80 27 - 11377 8557 - 9012 Structural 4-1/2" HES TNT , 7615 , 5991 No SSSV 7615 , 11321 5991 , 8447 Bo York Operations Manager Dave Wages David.Wages@hilcorp.com 907.564.4545 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 0028328 27 - 8486 831 953 40167 16376 2365 3296 1904 1518 864 329 323-471 13b. Pools active after work:PRUDHOE OIL 4-1/2" BKR SABL-3 , 11321 , 8447 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 1:00 pm, Oct 06, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.10.06 11:29:17 - 08'00' Bo York (1248) ACTIVITYDATE SUMMARY 8/22/2023 ***WELL S/I ON ARRIVAL*** (RWO expense) POLLARD #60 RIG UP ***CONTINUE ON 8/23/23 WSR*** 8/23/2023 ***CONTINUED FROM 8/22/23 WSR*** (RWO expense) PULLED 2-7/8" XX-PLUG AT 11,371' MD PULLED 4-1/2" x 2-7/8" NIPPLE REDUCER AT 11,371' MD ***WELL S/I ON DEPARTURE*** 8/25/2023 ***WELL SHUT IN ON ARRIVAL*** SET 5.5'' SLIP STOP CATCHER @ 8,625' MD (tbg xo) PULLED T2-DGLV (7,870' MD) PULLED 5.5'' SLIP STOP CATCHER @ 8,625' MD (empty) THUNDERBIRD DISPLACE TBG & IA W/ 864 BBLS KCL SET 4.5'' PXN PLUG BODY W/ FILL EXT @ 11,371' MD RAN 4.5'' X-CHECK SET TO 11,371' MD (sheared indicating good set) SET P-PRONG @ 11,371' MD (tfs unable to pressure up, ordered more seawater to test) SET T2-DGLV (7870' MD) ***WSR CONTINUED ON 8-26-23*** 8/25/2023 T/I/O= 110/50/0 TFS Unit 4 Assist SlickLine (Load and Secure) Pumped a total of 278 BBLS SeaWater and 586 BBLS of 2% KCL. Followed by 6 BBLS of 60/40 Methanol to freeze protect suface lines and tree. JOB CONTINUES ON 8-26-23 8/26/2023 ***WSR CONTINUED FROM 8-25-23*** LAY DOWN EQUIPMENT AND RETURN IN THE AM RIG DOWN POLLARD UNIT 58 ***WELL SHUT IN ON DEPARTURE / DSO INFORMED OF WELL STATUS*** 8/26/2023 JOB CONTINUES FROM 08-25-23 Assist SL wth Load and Test, Pumped 53 BBLS SW followed by 10 BBLS 60/40 to FP, CMIT failed, FWHP=548/679/0 S/W/SSV/M/IA/OA= C/C/O/O/OTG/OTG 8/27/2023 T/I/O=350/350/0 TFS unit 3 (Circ Out/CMIT-TxIA) Pumped 6BBLS SW downTBG and IA to pressure up for a CMIT-TxIA @ 2500psi MAP. Reached test pressures @ (2480/2506 psi) TBG/IA. First 15 minutes TBG lost 47 psi, IA lost 47 psi. Second 15 minutes TBG lost 15 psi, IA lost 16 psi. CMIT-TxIA ****PASSED****. Pumped 249 BBLS of 2% KCL down the TBG taking returns up the IA to 03-15 FL to circ out crude. Pumped 2 bbls of 50/50 down the TBG to FP TBG surface line. pumped 1 bbls of 50/50 down the IA/Return surface line to FP. FWHPS=250/250/0. SV,WV,SSV=C/C/O(SSV forced open by DSO). MV=O. I/O=OTG 8/29/2023 T/I/O= 325/25/0 TFS Unit 4 (circ out) Pumped 50 BBLS of 2% KCL down the IA up the Tubing to 03-15 Flowline. Pumped 246 BBLS of 2% KCL down the Tubing up the IA to 03-15 Flowline followed by a Surface Line Freeze protect of 3 BBLS 60/40. DSO Notified of well status upon departure. SV/WV= Shut, SSV/MV= Open IAC/OAC= OTG FWHP= 550/525/0. 8/30/2023 T/I/O= 275/225/0 TFS Unit 4 (Circ Out/FP) Pumped 240 BBLS of Diesel Down the Tubing up the IA down 03-15 Flowline to Freeze Protect. Tag Hung on Master Valve. Valve Positions= SV/WV= Closed MV/SSV=Open IAC/OAC=OTG FWHP= 0/0/0 Daily Report of Well Operations PBU 03-25A Daily Report of Well Operations PBU 03-25A 8/31/2023 ***WELL SHUT IN ON ARRIVAL*** PCE pressure tested from 200LP - 3000HP (Failed) Shut down the the day to make repairs to PCE Job continued on 9-1-23 9/1/2023 Job continued from 8-31-23 ***WELL SHUT IN ON ARRIVAL*** Pressure test PCE from 200LP - 3000HP RIH with 1 7/16" Cable Head, (2X) 1 11/16 All-Steel Weight Bar, Titan centralizer, 1 11/16" GR/CCL,Titan centralizer, 1 11/16" Shock Sub, Jet Cutter. (Max Lenth = 22' , Max OD = 4.125) Shooting depth = 7,700' , CCL Offset = 7.8', CCL Stop Depth = 7,692.2' ***WELL SHUT IN ON DEPARTURE*** 9/4/2023 T-I-O= VAC-0-0. Set 6" CIW "J" TWC #421 @135". Set good.***JOB COMPLETE***. RDMO. Final WHP's= TWC-0-0. 9/8/2023 T/I/O=TWC/0/0. Pre TB-01. RD 6x7 Tree and 13" FMC THA. RU 2' 13 5/8" spacer spool and shttoing flange. Toruqed flanges to spec. ***Job in progress*** Final WHP's TWC/0/0. 9/8/2023 Check void/bleed off, N/D THA, clean void, ring groove, & hanger ID, cut & cap (2) 1/4" CCL, install 3/8" NPT plugs in back side of CCL termination nipples & re-install them, M/U 7" NSCC sub to tubing hanger lift threads to ensure they're good, 7-1/2 RH, back out & L/D sub, function upper LDS 1 at a time, 3-1/2" out, re-torque 500 ft/lbs, install new BX-160, RDMO while well support N/U 13-5/8" x 2' spool. 9/9/2023 TB-1 RWO Job Scope: Pull & Re-Run Completion to repair Tbg Leaks. Move Rig and support equipment from L5-29 to 03-25. MIRU Thunderbird-1. Spot basebeam, pits, rig, and upright tanks. R/U pit interconnects and lines. R/U coflex to choke / kill manifolds. ........Continued on 9/10/23 WSR 9/9/2023 T/I/O=TWC/0/0. Pre TB-01. RD shooting flange and RU 13 5/8" CIW BOP stack with additional single ram on bottom. Torqued flanges to spec. ***Job Complete*** Final WHP's TWC/0/0. 9/10/2023 TB-1 RWO Job Scope: Pull & Re-Run Completion to repair Tbg Leaks. Well Support installed BOPE Stack. Rig up scaffolding. Rig up Koomy hoses. Rig up to choke & kill lines. Shell test BOPE 250 psi low / 3000 psi high. AOGCC Austin McLeod waived witness. Begin BOPE testing 250 psi low / 3000 psi high as per sundry. Tested w/2-7/8", 4-1/2", and 5-1/2" test mandrels. ........Continued on 9/11/23 WSR 9/11/2023 T/I/O=TWC/0/0 Pulled with T-bar, 6" CIW "J" TWC #421 through stack for T-bird. FWP's 0/0/0 job complete. FWP's vac/0/0 9/11/2023 M/U 7" NSCC L/J to tubing hanger 7-1/2RH, ensure IA valve is open to tank, back out upper lock down screws to 3-1/2" min., tighten gland nuts, POOH, L/D tbg hgr & L/J together 9/11/2023 ***ASSIST RIG ON 03-25*** TRAVEL & RIG UP ON THUNDERBIRD 1 ***CONTINUE 9/12/23*** Daily Report of Well Operations PBU 03-25A 9/11/2023 TB-1 RWO Job Scope: Pull & Re-Run Completion to repair Tbg Leaks. BOPE Test Completed. R/D test equipment. R/U GBR tongs and powerpack. WS pulled 6" CIW "J" TWC from tubing hanger. Circulate 207 bbls of 1% KCI STS 4 bpm @ 415 psi. M/U Landing Joint, BOLDS. Pull Hanger to floor @ 42k to release, PUW 32k. Lay down Hanger. Rig up control line spooler and sheave. Pull and lay down 5- 1/2" 17# NSCC tubing w/dual encapsulated control lines. At Joint #24/#25 control lines are severely wrapped around the tubing. Cut and remove control line. Resume pulling tubing while pulling out control lines. Recovered 54 full Joints + 2.10' Parted pup. Pin end threads are parted at bottom of the 2.10' pup. Recovered 46 of 59 SS Bands. Discuss plan forward w/OE and Wells Foreman. M/U YJ BHA #1 - 8-1/8" Overshot but unable to lower BHA into well. Drain stack and see rubber encapsulation below BOPE stack. Discuss plan forward w/Wells Foreman. MIRU Pollard Slickline w/.125 wire. ........Continued on 9/12/23 WSR 9/12/2023 TB-1 RWO Job Scope: Pull & Re-Run Completion to repair Tbg Leaks. MIRU Pollard Slickline w/.125 wire. Fished 50' piece of dual encapsulated control line from 30' slm. Ran baited 8.50" junk basket to 1,543' slm, unable to work past. Ran baited 5.21" 4 prong wire grab to 2,100' slm. Ran 8.50" junk basket to 2,130' slm no issues. RDMO Slickline. M/U BHA #1 - 8-1/8" overshot. TIH w/BHA #1 on 2-7/8" 7.9# PH-6 workstring. Pick up Joint #70. Circulate down workstring 3bpm @ 260psi. Overshot 5-1/2" Tbg Stub @ 2185.58' ORKB (23' In on Jt #70). PUW 80k over and pull 5-1/2" Tbg free. TOH w/BHA #1. L/D BHA #1, lay down BAL-O SVLN. Reverse circulate 375 bbls STS 4 bpm / 120 psi. Begin pulling and laying down 5-1/2" 17# NSCC tubing. ........Continued on 9/13/23 WSR 9/12/2023 ***CONTINUE FROM 9/11/23*** RAN KJ, 8" BLB, 8.50" GAUGE RING S/D @ 24' SLM RAN KJ, 8" BLB, 3.80" GAUGE RING, S/D @ 24' (recovered 53' of control line & coating) RAN BAITED JUNK BASKET, 8.50 GAUGE RING S/D @ 1,543' SLM (recovered small pieces of bands & coating) RAN BAITED 5.21" 4-PRONG WIRE GRAB, STOP @ 2,080' SLM (recovered 18" of control line) RAN BAITED JUNK BASKET, 8.50" GAUGE RING STOP @ 2,130' SLM (no obstruction) ***JOB COMPLETE*** 9/13/2023 ***ASSIST RIG ON 03-25*** RUN JUNK BASKET W/ 8.50" GAUGE RING S/D @ 5,533' SLM (recovered control line bands & coating) RUN JUNK BASKET W/ 8.50" GAUGE RING S/D @ 7,438' SLM (recovered control line bands & coating) RUN KJ, 8" BLB, 5.23" WIRE GRAB S/D @ 7,722' SLM (no recovery) RUN JUNK BASKET W/ 8.50" GAUGE RING S/D @ 7,719' SLM (recovered 12" of banding) RUN KJ, 4.50" CENT. BULL NOSE, S/D @ 7,785' (STUB @ 7,722') ***JOB COMPLETE 9/13/23*** Daily Report of Well Operations PBU 03-25A 9/13/2023 TB-1 RWO Job Scope: Pull & Re-Run Completion to repair Tbg Leaks. Continue pulling and laying down 5-1/2" 17# NSCC tubing. Recovered 1 BAL-O SVLN, 3 GLM, 137 full joints and 7.58' cut joint. Rig up Slickline. Slickline RIH w/ Junk Basket w/ 8.50" Gauge Ring. SL Tagged at 5533', had to jar out of. Tag higher at 5525'. Pooh. Recover 2.5 bands, encapsulation rubber & small broken control line pieces. Re-run Junk Basket. Start loosing weight at ~ 7255'. Work junk catcher down to 7450'. Pooh. Recover ~ 3/4 of a band & encapsulation rubber. Run 5.23" 4- Prong Wire Grab. Tag at 7722', appear to be at 5-1/2" Stub. Pooh w/ no recovery. R- run Junk Basket. Tag 5-1/2" stump at 7719' slm. Pooh. Recover 1 band. 8 bands still in hole. RIH w/ 4.50" Centralizer/bullnose. Tag Tbg stub? @ 7722'. Worked into easily and tagged @ 7735'. Worked past in ~10 mins. Drift to 7785' SLM and tagged. Depth acceptable to run completion. POH and RD slickline. Prep completion and rig- up GBR. Align derrick due to settling. ........Continued on 9/13/23 WSR 9/14/2023 TB-1 RWO Job Scope: Pull & Re-Run Completion to repair Tbg Leaks Complete derrick alignment. Run 4-/12 L-80 VamTop Tailpipe and Packer Assy and 5- 1/2 L-80 Completion. Tag 33.70' In on JT # 200. = 7724.4' ORKB. Calculate space out. No space out pups needed to be 5.62' above nogo depth. LD Jt #200 and make up FMC Hanger. Land completion @ 7719'. Up Dn Wts 113/85K. RILDS and break out landing joint. Close blinds and pump 84 bbls corr inhib (in progress) ***Continued on 9/15/2023 WSR*** 9/14/2023 Make up hanger to string, drain stack, inspect & grease hanger OD, run in hole, land on RKB, run in lock down screws, torque 500 ft/lbs, tighten gland nuts, RDMO 9/14/2023 T/I/O=0/0/0. TB-01 completion. RU CIW lubricator 68-839 to BOP shooting flange. Set 6" "J" TWC #408 with lubiricator @ 135" with 10' of extentions and setting tool. ***Job Complete*** Final WHP's TWC/0/0. 9/15/2023 T/I/O=TWC/0/0. Post TB-01. Removed shooting flange and Birdbath. Evacuated welbore fluids above TWC. RD 13" CIW BOP assembly. RD 13 5/8" FMC THA and 6x7 CIW tree assembly. Torqued flanges to spec. Pressure tested tree against TWC to 500/5000 psi. Passed. Pulled 6" "J" TWC #408 with dryrod. Installed tree cap and PT to 500 psi. pass. ***Job Complete*** Final WHP's 0/0/0. 9/15/2023 TB-1 RWO Job Scope: Pull & Re-Run Completion to repair Tbg Leaks Pumped 84 bbls 1% EPT-3744 in 120F 1% KCL. Displaced w/ 257 bbls 1% KCL to spot C.I from above GLM #2 and to below packer. Drop ball and rod and set packer w/ 3600 psi. MIT-T Passed. Initial pressure 3675 psi. 15 min loss 85 psi. 2nd 15 min loss 40 psi. Final pressure 3550 psi. MIT- IA Passed. Initial pressure 3630 psi. 15 min loss 20 psi. 2nd 15 min loss 5 psi. Final pressure 3605 psi. Shear valve in upper GLM. Bled T and IA to zero and flow check well. Open blinds and MU shooting flange. Valve shop set J plug w/ lubricator. Rig down. ***Job Complete**** Daily Report of Well Operations PBU 03-25A 9/16/2023 ***WELL S/I ON ARRIVAL*** (RWO expense) PULLED BALL & ROD f/ RHC AT 7689' MD PULLED RKP-SOV IN ST#1 AT 3519' MD, REPLACED w/ RK-LGLV PULLED RK-DGLV IN ST# 2 AT 5971' MD, REPLACED w/ RK-OGLV PULLED 3.81" RHC PLUG BODY AT 7689' MD ATTEMPT TO PULL P-PRONG & ENCOUNTER POTENTIAL RIG TRASH AT 8,608' SLM RAN BAIT SUB, 4-1/2" BRUSH & 3-PRONG WIRE GRAB TO 11,348' SLM (recovered thin metal piece) ***CONTINUE ON 9/17/23 WSR*** 9/16/2023 Clean void, ring groove, & SBMS profile, install new SBMS, install new BX-160, orient THA same as it was before decompletion, well support torqued it up along w/ tree, test tubing hanger void 500 psi/5 min, 0 psi loss, test void 5000 psi/30 min., lost 200 psi first 15 min., lost 0 psi second 15 min., monitored SBMS port during void test, no leakage, bleed off test psi.,monitor SBMS port while well support test tree, no leakage,RDMO. 9/17/2023 ***CONTINUED FROM 9/16/23 WSR*** (RWO expense) RAN 3.75" CENT BARBELL W/ 3.50" LIB TO 10,060' SLM (inconclusive) MADE VARIOUS RUNS TO FISH RIG TRASH AT 11,348' SLM (recovered multiple pieces of metal & rubber) PULLED P-PRONG AT 11,371' MD MADE ONE ATTEMPT TO PULL PLUG BODY AT 11,371' MD (unable to latch, suspect more trash) RAN 10' x 3.50" PUMP BAILER TO 11,371' MD (recovered large pieces of metal) ***CONTINUE ON 9/18/23 WSR*** 9/18/2023 ***CONTINUED FROM 9/17/23 WSR*** (RWO expense) MADE MULTIPLE UNSUCCESSFUL ATTEMPTS TO PULL PLUG BODY AT 11,371' MD MADE VARIOUS RUNS TO FISH RIG TRASH AT 11,371' MD (recovered multiple metal pieces) ***CONTINUE ON 9/19/23 WSR 9/18/2023 T/I/O=0/0/0 Assist Slickline W/ Freezez Protects Pumped 110 BBLS crude down the IA for a Freeze Protect, Pumped 58 BBLS crude down TBG for a Freeze protect. FWHP=0/0/0 9/19/2023 ***CONTINUED FROM 9/18/23 WSR*** (RWO expense) MADE VARIOUS RUNS TO FISH RIG TRASH (recovered conical piece of brass) ***CONTINUE ON 9/20/23 WSR*** 9/20/2023 ***CONTINUED FROM 9/19/23 WSR*** (RWO expense) MADE VARIOUS RUNS TO CLEAR DEBRIS FROM PX-PLUG BODY AT 11,371' MD 11,354' SLM (no recovery) ***CONTINUE ON 9/21/23 WSR*** 9/21/2023 ***CONTINUED FROM 9/20/23 WSR*** (RWO expense) MADE VARIOUS RUNS TO RECOVER RIG TRASH AT 11,371' MD (no recovery) PULLED 4-1/2" PXN PLUG BODY AT 11,371' MD (jet cutter parts & bands) DRIFT W/ 3.50" CENT & 2.50" SAMPLE BAILER TO HARD BOTTOM AT 11,776' SLM (bailer empty) ***WELL S/I ON DEPARTURE*** 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 03-25a Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 193-023 50-029-21021-01-00 ADL 0028328 12395 Conductor Surface Intermediate Production Liner 9262 80 2507 8767 3728 11371 20" 13-3/8" 9-5/8" 7" 8482 26 - 106 26 - 2533 24 - 8791 8667- 12395 2373 27 - 107 26 - 2507 24 - 6686 6599- 9262 11794 , 11823 , unknown 470 2670 4760 7020 11371 , 11802 , 11839 , 11844 1490 5380 6870 8160 11476 - 12076 5-1/2" 17# x 4- 1/ 2" 12.6# 13Cr80 22 - 113778557 - 9012 Structural 4-1/2" Baker SABL-3 , 11326 , 8451 No SSSV Date: Bo York Operations Manager Dave Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY 9/1/23 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 Install new completion By Grace Christianson at 1:31 pm, Aug 18, 2023 323-471 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.08.18 12:53:48 -08'00' 10-404 DSR-8/18/23SFD 8/22/2023 2373 BOPE test to 3000 psi. Annular to 2500 psi. MGR28AUG23*&: 08/29/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.29 16:00:16 -08'00' RBDMS JSB 083123 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 Well Name:03-25a API Number:50-029-21021-01 Current Status:Not Operable PAL Rig:SL / EL / RWO Estimated Start Date:August 2023 Estimated Duration:5day(s) AFE:Cost: IOR:377 Regulatory Contact:Carrie Janowski First Call Engineer:David Wages 713.380.9836 Second Call Engineer:David Bjork 907.564.4672 (O)907.440.0331 (M) Current Bottom Hole Pressure:3243 psi @ 8,700’ TVD 7.2 PPGE MASP:2373 psi 0.1 psi/ft gas gradient Last SI WHP:0 psi Current Min ID:3.725” @ XN @ 11,371’ MD Max Angle:61 deg @ 7,900’ MD. Partner Approval?:Required AOGCC Approval?:10-403/404 required Add’l Regulatory: 03-25a is a CO736 well due to its 2018 packer squeeze. This proposed workover will install a new production packer over the cement top and should remove the well for the CO736 bi-annual MIT-T and MIT-IA requirements. However, to monitor the integrity of the packer squeeze cement above the 7” x 9-5/8” liner hanger we will continue to set a plug in the tubing tail @ 11,371’ and MIT-T every 4years. Brief Well Summary: 03-25A is a sidetracked vertical Ivishak producer that was completed in 1993. In June 1993 perforations were shot @ 11,695' - 11,710' MD, and in Dec 1993 these perfs were squeezed off due to being considered high GOR (~30,000 scf/stb) with new perfs being added in Dec 1993 in Z3/Z4. In July 1999 a brief WSO was performed with an IBP being set at 11,859' MD but the IBP was pulled in Dec 1999 when the well returned to pre WSO rate. In 2001 the active perfs were squeezed again due to high gas/water rates and the well was reperforated to include Z2. In 2011 a plug was set to shut off all perforations below 11,839' MD to reduce water production, however, no change was noted in the water rates possibly due to leak-by, fractures, or channeling. In Feb 2016 a borax-C/O log was run and the results from the log did not identify any channeling and determined much of the Ivishak to be swept. Recently in July 2016 perforation were added to the Sag Reservoir, however, there was little change to the IOR post perforations so in August 2017 a HEX plug was set at 11,802' MD with 10' of perfs being added in Z4. Performance post profile mod demonstrated that the majority of liquid had been shut off and 03-25A was producing at ~150 bopd with ~10 MM/d of gas. Shortly after this in March 2018 03-25 failed a CMIT-TxIA with an LDL noting a small Packer Leak. To remediate CT pumped an IA cement squeeze that successfully passed integrity testing in July 2018 & EL shot another 30' of Z4 perfs to increase gross rates which increased production to 800 bopd, 250 bwpd, & 35 MMscf/d. Add’l: 4/20/19: Eline ADP, brought in some water and gas, no change in oil. Since: GLRDFR and MITs 7/7/2023: IA exceeded NOL, first indication of an issue 8/6/2023: PTS log shows pup(s) above SSSV with potential issue 8/11/2023: Caliper shows parted 5.5” tubing at 2174’ in pup above SSSV (log attached) 8/14/2023: Set nipple reducer w/ plug @ 11,371’, passing CMIT to 3000 psi Objective: RWO to restore integrity – Re-Use existing tubing install a new production packer over the cement top a 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 Procedure: Pre RWO work: Wellhead/DHD – 1. Cycle LDSs 2. PPPOT-T failed 7/29/23,re-attempt while monitoring IA to verify ability to BOP test 3. PPPOT-IC pass 3/27/2018 (NEED UPDATED) Slickline –(DONE 8/14/23) 1. Set TTP 2. CMIT to 3000 psi 3. Drift for cutter Proposed RWO Procedure: Slickline/Fullbore – 1. Pull Nipple reducer and plug 2. Fullbore flush tubing and IA to part with warm 120degF 2% KCL a. Continue to rock and bullhead until as much crude is out of the well as possible b. T x IA Vol to part: 148 bbls c. Tubing volume below part to tubing tail: 64 bbls d. Freeze protect as necessary, pending RWO timing 3. Set TTP with catcher sub on top 4. Pressure test plug to 2500 psi Eline– 1. Jet cut tubing @ 7700’ per tie in below a. AK Eline has two 5-1/2” Jet cutters Valve Shop - 1. Set and test TWC 2. ND tree and THA, inspect lift threads 3. NU 13-5/8” BOPE configured top down, Annular, Blinds, 4-1/2” x 7” VBRs, flowcross, 2-7/8” x 5” VBRs TB#1 – De-complete 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 4-1/2” x 7” VBR’s with 5-1/2” test joint. E. Test the 2-7/8” x 5” VBR’s with 2-7/8” test joint. F. Test the Annular preventer with a 2-7/8” test joint. G. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull TWC. Utilize lubricator if pressure is expected. 4. At WSL discretion, circ well out to 2% KCl 5. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~35K 6. RU control line spooler for control lines. Expect 59 stainless steel bands. a. 3/31/1993 completion report 7. Pull 5-1/2” tubing to floor, Circulate a wellbore volume if possible. Utilize lubricator if pressure is expected. 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 a. Passing pressure test on the tubing tail plug, maintain fluid level at surface. b. T x IA Vol to part: 148 bbls 8. The tubing will be re-used if possible 9. If the 5.5” completion threads are unsalvageable, we will run the 4.5” completion per stager below. a. Notify ops so they can start planning a new flowline/tree configuration. b. FS2 Lead OP: 659-5493 (Peter and Mike) Fish lower tubing section 10. PU workstring, fishing assembly and spear for 5.5” tubing. a. We need to latch below the corroded pup, the grapple should no-go at least 3’ into the tubing stub looking up and go no further than 5’ into the stub to avoid contact with the SSSV. b. If an overshot is preferred, we should be able to grab onto the 5.5” collar, caliper pulled collars to determine grapple size. 11. Spear into fish and POH a. 2-7/8” workstring weights ~13k# b. 5-1/2” existing tubing string weights ~90k# c. Discard first 4 full joints below SSSV nipple – caliper shows line of pits over 20% penetration d. Discard bottom 5 joints just above cut – general corrosion e. New 4-1/2” packer and lower assembly will need to make up for discarded ~360’ (9 joints) Run Completion 12. Run 5-1/2” 13Cr tubing with packer and gas lifted completion as detailed on proposed schematic. a. Previous GLM depths will be used b. 5.5” L80 primary backup completion c. 4.5” 13CR secondary backup 13. Land Hanger and reverse in corrosion inhibited 8.6ppg 1% KCl 14. Drop ball and rod and set packer with 3,500psi pump pressure. 15. Perform MIT-T to 3,500 psi and MIT-IA to 3,500 psi for 30 charted minutes 16. Shear valve in upper GLM. 17. Set TWC 18. Rig down Thunderbird #1. Post rig valve shop work 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,000ft with diesel. Post rig Slickline Work 1. Pull Ball and rod and RHC profile. 2. Set GLV’s per GL Engineer 3. RDMO & pop well. Obtain AOGCC witnessed SVS test within 5 days of putting well online. 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 Current Wellbore Schematic: 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 Proposed RWO Wellbore Schematic: 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 7/25/2018 packer squeeze CBL w/ tubing cut annotated 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 8/11/2023 READ Caliper showing tubing part w/ previous caliper: 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 Tubing tally over parted pup area 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 BALO SSSV profile: 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 5.5 NSCC Connection Data: 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 Proposed 5.5” Completion Stager: 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 RWO BOPs 03-25a Tubing Swap PTD: 193-023 API: 50-029-21021-01 Revision 1 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. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Sunday, August 6, 2023 7:55 AM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Bo York; Oliver Sternicki; PB Wells Integrity Subject:NOT OPERABLE: Producer 03-25A (PTD #1930230) Hole in Production Tubing Mr. Regg,  Slickline replaced the GLVs on 07/14 but the well failed another TIFL. A TTP was set on 07/27 and failed a MIT‐T. A leak  detect log was performed on 08/06 and found a hole in the producƟon tubing ~ 2170’ MD. The well is now classified as  NOT OPERABLE and will remain secured with the TTP unƟl the well barriers are restored.  Please respond with any quesƟons.  Andy Ogg  Hilcorp Alaska LLC  Field Well Integrity  andrew.ogg@hilcorp.com  P: (907) 659‐5102  M: (307)399‐3816   From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>   Sent: Sunday, July 9, 2023 7:04 AM  To: Regg, James B (CED) <jim.regg@alaska.gov>  Cc: chris.wallace@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells  Integrity <PBWellsIntegrity@hilcorp.com>  Subject: UNDER EVALUATION: Producer 03‐25A (PTD #1930230) IAP over MOASP / Failed TIFL  Mr. Regg,  Producer 03‐25A (PTD #1930230) was reported to have IA casing pressure above MOASP aŌer the well was shut‐in on  07/07/23. A subsequent cold TIFL failed which indicates a failure of a well barrier. The well is now classified as UNDER  EVALUATION and is on the 28 day clock for diagnosƟcs.  Plan forward:   1.DHD: Warm TIFL when FS2 is back up and well is online 2.SL (pending): Replace SO 3.DHD (pending): TIFL 4.Well Integrity: AddiƟonal diagnosƟcs as needed Please respond with any quesƟons.  Andy Ogg  Hilcorp Alaska LLC  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. PBU 03-25APTD 1930230 2 Field Well Integrity  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, please immediately 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 considers appropriate.     1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Sunday, July 9, 2023 7:04 AM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Bo York; Oliver Sternicki; PB Wells Integrity Subject:UNDER EVALUATION: Producer 03-25A (PTD #1930230) IAP over MOASP / Failed TIFL Attachments:03-25A.pdf; TIOChart.jpg Mr. Regg,    Producer 03‐25A (PTD #1930230) was reported to have IA casing pressure above MOASP aŌer the well was shut‐in on  07/07/23. A subsequent cold TIFL failed which indicates a failure of a well barrier. The well is now classified as UNDER  EVALUATION and is on the 28 day clock for diagnosƟcs.    Plan forward:   1. DHD: Warm TIFL when FS2 is back up and well is online  2. SL  (pending): Replace SO  3. DHD (pending): TIFL  4. Well Integrity: AddiƟonal diagnosƟcs as needed    Please respond with any quesƟons.    Andy Ogg  Hilcorp Alaska LLC  Field Well Integrity  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, please immediately 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 considers appropriate.      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.   MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 16, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 03-25A PRUDHOE BAY UNIT 03-25A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/16/2022 03-25A 50-029-21021-01-00 193-023-0 N SPT 8447 1930230 2112 583 2778 2692 2655 2 2 2 2 OTHER P Guy Cook 6/1/2022 2 year MIT-T per CO 736. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 03-25A Inspection Date: Tubing OA Packer Depth 589 716 726 731IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220601102351 BBL Pumped:2.9 BBL Returned:2.9 Thursday, June 16, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 :HOOLV2LOSURGXFHU,$FHPHQWVTXHH]H MEU James B. Regg Digitally signed by James B. Regg Date: 2022.06.16 14:42:41 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 16, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 03-25A PRUDHOE BAY UNIT 03-25A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/16/2022 03-25A 50-029-21021-01-00 193-023-0 N SPT 8447 1930230 2112 597 2778 2749 2730 2 2 2 2 OTHER P Guy Cook 6/1/2022 2 year CMIT-TxIA per CO 736. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 03-25A Inspection Date: Tubing OA Packer Depth 594 2770 2716 2695IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220601102839 BBL Pumped:6.8 BBL Returned:6.7 Thursday, June 16, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 :HOOLV2LOSURGXFHU,$ FHPHQWVTXHH]H MEU CMIT-TxIA p CO 736. James B. Regg Digitally signed by James B. Regg Date: 2022.06.16 13:45:18 -08'00' MEMORANDUM TO: Jim Regg , zoto P.I. Supervisor GI FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 23, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. 03-25A PRUDHOE BAY UNIT 03-25A Src: Inspector Well Name PRUDHOE BAY UNIT 03-25A API Well Number 50-029-21021-01-00 Inspector Name: Guy Cook Insp Num: mitGDC200621175847 Permit Number: 193-023-0 Inspection Date: 6/21/2020 i Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well -_- - _ -- J - - I - . % g -- - � 03-25A Type In N TVD 1 8447 Tubin 636 2701 2583 ' I 2536 - I� PTD 1930230 � Type Test SPT 'Test psi 2500 IA 62 65 66 - 66 BBL Pumped 3BBL Returned: 3 OA _I 0 p 0 0 Interval Other (describe in notes) P/F Pass r - Notes: Sundry 318-180. Conservation Order 736 requires this well to be tested every two years with a MIT -T and CMIT TxIA. This report is for the MIT -T. Testing was performed with a Little Red Services pump truck and calibrated gauges. The target test pressure was 2500 psi. I used the footage off of the well schematic for the packer depth, although the IA is cemented to 8144'. Thursday, July 23, 2020 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE: Thursday, July 23, 2020 !��lo �i�5l�t,-Z,v P.I. Supervisor I SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. 03-25A FROM: Guy Cook PRUDHOE BAY UNIT 03-25A Petroleum Inspector Src: Inspector I Well Name PRUDHOE BAY UNIT 03-25A Insp Num: mitGDC200621182411 Rel Insp Num: NON -CONFIDENTIAL API Well Number 50-029-21021-01-00 Inspector Name: Guy Cook Permit Number: 193-023-0 Inspection Date: 6/21/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 03-25A Type Inj N TVD 8447 'Tubing 69 2692 2614 2582 —— PTD I 1930230 ITj'p8 TCSt� SPT Test p51 2500 I IA 73 2718. 2640 2608' BBL Pumped: 18.5 BBL Returned: 9 OA 0 0 0 0�— Other describe in notes -- �� Pass Interval ( ) P/F Notes: Sundry318-180. Conservation O�der736 requires this well to be tested every two years with a MIT -T and CMIT TxIA. This report is for the CMIT- TxIA. Testing was performed with a Little Red Services pump truck and calibrated gauges. The target test pressure was 2500 psi. I used the t o ge off of the well schematic for the packer depth. The IA is cemented to 8144'. The IA had been filled with 38 bb(s of crude before I was on site. I was informed they had used 12 bbls to fill the IA before I arrived. Upon arrival they were bleeding what they thought was a small gas cap on the [A to a bleed tank. Obviously they did not get the IA fluid packed, but taking into consideration the pressure trends during the test I felt the well passed. Thursday, July 23, 2020 Page 1 of 1 Brooks, Phoebe L (CED) t19 ®2 30 From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent. Thursday, July 23, 2020 9:01 AM To: Brooks, Phoebe L (CED) Subject: RE: [EXTERNAL] Directional survey for PBU 03-25A PTD #1930230 Attachments: 03-25A Directional Survey.xlsx Oh my goodness... sorry for missing the obvious Attached. -Andy From: Brooks, Phoebe L (CED) [mailto:phoebe.brooks@alaska.gov] Sent: Thursday, July 23, 2020 8:57 AM To: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Subject: RE: [EXTERNAL] Directional survey for PBU 03-25A PTD #1930230 Yes (in the subject line) for PBU 03-25A PTD #1930230. Thank you! Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity hilcorp com> Sent: Thursday, July 23, 2020 8:56 AM To: Brooks, Phoebe L (CED) <phoebe.brooks Ca alaska.gov> Subject: RE: [EXTERNAL] Directional survey for PBU 03-25A PTD #1930230 Hi Phoebe, I'm assuming you want the directional survey? -Andy From: Brooks, Phoebe L (CED) [mailto:phoebe.brooks@alaska.gov] Sent: Wednesday, July 22, 2020 3:51 PM To: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity(rahilcorp.com> Subject: [EXTERNAL] Directional survey for PBU 03-25A PTD #1930230 Hi Andy/Ryan, Would you be able to send me the most recent survey for PBU 03-25A? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE, This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska gov. 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, please immediately 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 considers appropriate. 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, please immediately 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 considers appropriate. Wellbore 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A KIMA.7_M 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A' 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A 03-25A Meas Dept ND Depth SS Depth 0 0 -55 60 60 5 67 67 12 82 82 27 98 98 43 115 115 60 132 132 77 149 149 94 166 183 200 217 234 251 268 285 302 319 336 353 370 387 404 421 438 455 472 489 506 523 539 556 573 590 607 623 640 656 673 689 706 722 739 756 772 789 166 183 200 217 234 251 268 285 302 319 336 353 370 387 404 421 438 455 472 489 506 523 539 556 573 590 607 623 640 656 673 689 706 722 739 756 772 789 111 128 145 162 179 196 213 230 247 264 281 298 315 332 349 366 383 400 417 434 451 468 484 501 518 535 552 568 585 601 618 634 651 667 684 701 717 734 Inclination Azimuth 0 0 359.13 4.44 6.07 350.16 329.35 314.62 303.01 292.08 277.03 266.95 0.26 0.21 0.18 0.2 0.2 0.19 0.2 0.2 0.21 0.21 0.22 0.22 0.2 0.2 0.2 0.18 0.18 0.18 0.18 0.17 0.16 0.15 0.12 0.08 0.05 0.04 0.05 0.1 0.15 0.19 0.22 0.24 0.26 0.27 0.28 0.28 0.27 0.25 0.23 0.25 0.27 0.27 0.3 0.33 0.33 251.55 238.4 226.83 214.58 204.01 191.06 177.45 165.23 159.99 154.35 152.97 F1691*11 145.37 139.76 145.09 178.31 252.73 277.16 276.97 272.15 268 266.48 261.4 256.61 246.53 236.56 224.31 209.71 189.5 175.34 170.02 169.44 169.03 167.83 164.22 Dog Leg Asp X Asp Y 0 713,241.27 5,937,053.15 0 713,241.27 5,937,053.30 0.83 713,241.27 5,937,053.34 0.2 713,241.25 5,937,053.37 0.35 713,241.27 5,937,053.41 0.43 713,241.24 5,937,053.48 0.3 713,241.21 5,937,053.52 0.24 713,241.17 5,937,053.55 0.22 713,241.12 5,937,053.59 0.32 713,241.06 5,937,053.59 0.22 713,241.00 5,937,053.59 0.35 713,240.94 5,937,053.58 0.3 713,240.88 5,937,053.55 0.28 713,240.83 5,937,053.51 0.25 713,240.79 5,937,053.47 0.22 713,240.76 5,937,053.40 0.28 713,240.73 5,937,053.36 0.25 713,240.75 5,937,053.32 0.22 713,240.76 5,937,053.25 0.1 713,240.78 5,937,053.21 0.12 713,240.80 5,937,053.18 0.06 713,240.82 5,937,053.10 0.07 713,240.84 5,937,053.07 0.19 713,240.85 5,937,053.03 0.24 713,240.88 5,937,053.03 0.18 713,240.89 5,937,053.00 0.16 713,240.89 5,937,053.00 0.32 713,240.88 5,937,053.00 0.34 713,240.86 5,937,053.00 0.3 713,240.82 5,937,052.99 0.25 713,240.77 5,937,052.99 0.2 713,240.71 5,937,052.99 0.13 713,240.65 5,937,052.99 0.18 713,240.57 5,937,052.99 0.14 713,240.50 5,937,052.95 0.29 713,240.42 5,937,052.95 0.29 713,240.35 5,937,052.87 0.36 713,240.29 5,937,052.83 0.42 713,240.26 5,937,052.76 0.52 713,240.23 5,937,052.72 0.38 713,240.23 5,937,052.65 0.19 713,240.25 5,937,052.58 0.02 713,240.26 5,937,052.50 0.18 713,240.28 5,937,052.39 0.18 713,240.30 5,937,052.32 0.12 713,240.33 5,937,052.21 03-25A 806 806 751 0.35 162.12 0.14 713,240.36 5,937,052.14 03-25A 823 823 768 0.34 161.5 0.06 713,240.39 5,937,052.03 03-25A 839 839 785 0.35 162.2 0.06 713,240.41 5,937,051.96 03-25A 856 856 801 0.35 164.38 0.08 713,240.45 5,937,051.85 03-25A 873 873 818 0.37 163.02 0.13 713,240.49 5,937,051.74 03-25A 890 890 835 0.38 175.37 0.48 713,240.51 5,937,051.63 03-25A 907 907 852 0.44 186.18 0.58 713,240.53 5,937,051.52 03-25A 924 924 869 0.46 184.51 0.14 713,240.51 5,937,051.37 03-25A 941 941 886 0.49 . 184.31 0.18 713,240.50 5,937,051.26 03-25A 958 958 903 0.52 183.9 0.18 713,240.50 5,937,051.12 03-25A 975 975 920 0.54 183.5 0.12 713,240.49 5,937,050.93 03-25A 992 992 937 0.55 184.96 0.1 713,240.48 5,937,050.79 03-25A 1,009 1,009 954 0.55 183.49 0.08 713,240.48 5,937,050.60 03-25A 1,026 1,026 971 0.57 179.58 0.25 713,240.49 5,937,050.46 03-25A 1,043 1,043 989 0.58 175.4 0.25 713,240.50 5,937,050.28 03-25A 1,060 1,060 1,006 0.55 171.86 0.27 713,240.53 5,937,050.09 03-25A 1,077 1,077 1,023 0.51 173.66 0.26 713,240.55 5,937,049.95 03-25A 1,095 1,095 1,040 0.45 174.56 0.36 713,240.56 5,937,049.80 03-25A 1,112 1,112 1,057 0.43 168.59 0.29 713,240.59 5,937,049.69 03-25A 1,129 1,129 1,074 0.4 162.89 0.3 713,240.62 5,937,049.55 03-25A 1,146 1,146 1,091 0.23 142.19 1.19 713,240.66 5,937,049.47 03-25A 1,163 1,163 1,108 0.15 134.35 0.49 713,240.70 5,937,049.44 03-25A 1,180 1,180 1,125 0.15 135.25 0.01 713,240.73 5,937,049.40 03-25A 1,197 1,197 1,142 0.09 121.32 0.39 713,240.77 5,937,049.40 03-25A 1,214 1,214 1,159 0.08 76.98 0.38 713,240.78 5,937,049.41 03-25A 1,231 1,231 1,176 0.06 64.16 0.15 713,240.81 5,937,049.41 03-25A 1,248 1,248 1,193 0.02 37.37 0.25 713,240.82 5,937,049.41 03-25A 1,265 1,265 1,211 0.02 294.3 0.18 713,240.82 5,937,049.41 03-25A 1,283 1,283 1,228 0.05 264.58 0.2 713,240.81 5,937,049.41 03-25A 1,300 1,300 1,245 0.08 240.91 0.23 713,240.78 5,937,049.41 03-25A 1,317 1,317 1,262 0.11 242.52 0.17 713,240.76 5,937,049.40 03-25A 1,334 1,334 1,279 0.14 257.31 0.25 713,240.72 5,937,049.37 03-25A 1,351 1,351 1,296 0.17 268.12 0.25 713,240.67 5,937,049.37 03-25A 1,368 1,368 1,313 0.25 268.26 0.47 713,240.61 5,937,049.36 03-25A 1,385 1,385 1,330 0.45 280.16 1.25 713,240.51 5,937,049.40 03-25A 1,402 1,402 1,347 0.75 287.27 1.81 713,240.34 5,937,049.39 03-25A 1,419 1,419 1,364 1.03 290.11 1.68 713,240.07 5,937,049.50 03-25A 1,436 1,436 1,381 1.38 291.65 2.09 713,239.75 5,937,049.63 03-25A 1,452 1,452 1,398 1.63 292.52 1.5 713,239.34 5,937,049.77 03-25A 1,469 1,469 1,414 2 292.98 2.21 713,238.83 5,937,049.97 03-25A 1,486 1,486 1,431 2.18 292.75 1.06 713,238.26 5,937,050.18 03-25A 1,503 1,503 1,448 2.32 293.51 0.83 713,237.64 5,937,050.45 03-25A 1,520 1,520 1,465 2.45 292.89 0.78 713,236.98 5,937,050.69 03-25A 1,537 1,537 1,482 2.68 293.28 1.35 713,236.27 5,937,050.96 03-25A 1,554 1,554 1,499 2.95 293.14 1.59 713,235.49 5,937,051.31 03-25A 1,571 1,571 1,516 3.08 293.27 0.77 713,234.66 5,937,051.61 03-25A 1,588 1,588 1,533 3.29 294.04 1.27 713,233.80 5,937,051.95 03-25A 1,605 1,605 1,550 3.38 294.1 0.53 713,232.88 5,937,052.33 03-25A 1,622 1,622 1,567 3.46 294.83 0.53 713,231.94 5,937,052.74 03-25A 1,639 1,639 1,584 3.5 295.65 0.38 713,231.00 5,937,053.16 03-25A 1,656 1,656 1,601 3.53 295.61 0.18 713,230.04 5,937,053.57 03.25A 1,673 1,673 1,618 3.51 296.47 0.33 713,229.09 5,937,054.02 03-25A 1,690 1,690 1,635 3.52 297.28 0.3 713,228.15 5,937,054.47 03-25A 1,707 1,707 1,652 3.53 297.15 0.07 713,227.20 5,937,054.92 03-25A 1,724 1,724 1,669 3.58 295.88 0.55 713,226.25 5,937,055.37 03-25A 1,741 1,741 1,686 3.7 293.17 1.23 713,225.26 5,937,055.78 03-25A 1,758 1,758 1,703 3.91 290.01 1.74 713,224.20 5,937,056.15 03-25A 1,775 1,775 1,720 4.26 286.65 2.49 713,223.04 5,937,056.52 03-25A 1,792 1,792 1,737 4.65 283.79 2.65 713,221.76 5,937,056.81 03-25A 1,808 1,808 1,753 5.04 281.29 2.75 713,220.41 5,937,057.07 03-25A 1,825 1,825 1,770 5.5 280.07 2.79 713,218.88 5,937,057.32 03-25A 1,842 1,842 1,787 5.92 279.35 2.5 713,217.20 5,937,057.56 03-25A 1,859 1,858 1,804 6.21 279.55 1.71 713,215.42 5,937,057.81 03-25A 1,876 1,875 1,820 6.31 279.83 0.62 713,213.58 5,937,058.05 03-25A 1,893 1,892 1,837 6.48 281.44 1.45 713,211.71 5,937,058.36 03-25A 1,910 1,909 1,854 6.83 285.08 3.22 713,209.78 5,937,058.74 03-25A 1,927 1,926 1,871 7.34 289.03 4.15 713,207.76 5,937,059.31 03-25A 1,944 1,943 1,888 7.7 291.75 2.98 713,205.65 5,937,060.06 03-25A 1,961 1,960 1,905 7.85 293.05 1.36 713,203.51 5,937,060.87 03-25A 1,978 1,977 1,922 8.05 295.32 2.19 713,201.34 5,937,061.76 03-25A 1,995 1,994 1,939 8.22 297.05 1.75 713,199.14 5,937,062.76 03-25A 2,012 2,010 1,955 8.53 298.91 2.42 713,196.93 5,937,063.87 03-25A 2,029 2,027 1,972 8.82 300.55 2.25 713,194.67 5,937,065.05 03-25A 2,046 2,044 1,989 9.07 301.94 1.93 713,192.37 5,937,066.38 03-25A 2,063 2,061 2,006 9.39 303.67 2.5 713,190.04 5,937,067.78 03-25A 2,080 2,077 2,023 9.54 304.47 1.17 713,187.68 5,937,069.29 03-25A 2,097 2,094 2,039 9.84 305.77 2.18 713,185.29 5,937,070.87 03-25A 2,114 2,111 2,056 10.17 307.02 2.34 713,182.89 5,937,072.56 03-25A 2,142 2,138 2,083 11.16 308.91 3.8 713,178.77 5,937,075.55 03-25A 2,179 2,174 2,119 12.36 310.11 3.34 713,172.89 5,937,080.15 03-25A 2,218 2,212 2,157 14.06 311.12 4.4 713,165.97 5,937,085.77 03-25A 2,257 2,250 2,195 15.6 311.45 3.92 713,158.22 5,937,092.18 03-25A 2,296 2,287 2,232 17.56 311.13 5.03 713,149.65 5,937,099.30 03-25A 2,335 2,324 2,270 19.26 311.08 4.33 713,140.09 5,937,107.16 03-25A 2,374 2,361 2,306 20.81 311.43 3.97 713,129.78 5,937,115.73 03-25A 2,413 2,397 2,342 22.28 311.69 3.79 713,118.83 5,937,124.90 03-25A 2,452 2,433 2,378 23.78 312.43 3.95 713,107.31 5,937,134.72 03-25A 2,491 2,468 2,413 24.45 312.99 1.83 713,095.37 5,937,145.11 03-25A 2,530 2,504 2,449 24.79 313.55 1.04 713,083.07 5,937,156.04 03-25A 2,570 2,540 2,485 25.04 313.72 0.66 713,070.72 5,937,167.19 03-25A 2,609 2,576 2,521 25.26 313.75 0.56 713,058.34 5,937,178.37 03-25A 2,648 2,611 2,556 25.49 312.93 1.07 713,045.76 5,937,189.59 03-25A 2,688 2,647 2,592 25.64 310.7 2.47 713,032.76 5,937,200.57 03-25A 2,727 2,682 2,627 26.05 308.51 2.64 713,019.22 5,937,211.18 03-25A 2,766 2,717 2,662 27.31 305.98 4.31 713,004.87 5,937,221.43 03-25A 2,806 2,752 2,697 28.56 303.85 4.06 712,989.46 5,937,231.54 03-25A 2,845 2,787 2,732 29.35 300.98 4.06 712,973.08 5,937,241.29 03-25A 2,884 2,821 2,766 29.84 297.94 4.02 712,955.92 5,937,250.36 03-25A 2,924 2,855 2,800 30.65 296.18 3.04 712,937.97 5,937,258.90 03-25A 2,963 2,888 2,833 32.02 294.2 4.36 712,919.24 5,937,267.05 03-25A 3,002 2,921 2,866 33.6 291.69 5.38 712,899.70 5,937,274.66 03-25A 3,041 2,953 2,898 34.88 290.86 3.52 712,879.21 5,937,281.99 03-25A 3,079 2,985 2,930 36.13 290.46 3.27 712,857.84 5,937,289.37 03-25A 3,118 3,016 2,961 37.15 290.31 2.64 712,835.95 5,937,296.81 03-25A 3,157 3,046 2,991 38.08 290.71 2.48 712,813.60 5,937,304.45 03-25A 3,196 3,077 3,022 38.76 291.3 1.99 712,790.86 5,937,312.45 03-25A 3,235 3,107 3,052 39.16 292.04 1.57 712,767.84 5,937,320.85 03-25A 3,273 3,137 3,082 39.75 292.6 1.78 712,744.86 5,937,329.54 03-25A 3,312 3,166 3,112 40.8 292.62 2.7 712,721.42 5,937,338.51 03-25A 3,351 3,196 3,141 42.61 292.27 4.68 712,697.17 5,937,347.75 03-25A 3,390 3,224 3,169 44.18 291.91 4.11 712,672.27 5,937,357.04 03-25A 3,429 3,251 3,196 45.25 291.98 2.76 712,646.70 5,937,366.50 03-25A 3,468 3,279 3,224 45.7 291.99 1.15 712,620.65 5,937,376.16 03-25A 3,506 3,306 3,251 46.06 291.99 0.93 712,594.56 5,937,385.86 03-25A 3,545 3,332 3,277 46.09 292 0.08 712,568.44 5,937,395.56 03-25A 3,584 3,359 3,304 46.19 291.95 0.27 712,542.24 5,937,405.29 03-25A 3,623 3,386 3,331 46.33 291.98 0.36 712,515.87 5,937,415.06 03-25A 3,661 3,413 3,358 46.46 291.95 0.34 712,489.59 5,937,424.79 03-25A 3,699 3,439 3,384 46.46 291.9 0.1 712,463.95 5,937,434.29 03-25A 3,738 3,466 3,411 46.59 291.89 0.33 712,437.46 5,937,444.08 03-25A 3,777 3,492 3,437 46.45 291.9 0.36 712,411.25 5,937,453.75 03-25A 3,814 3,518 3,463 46.59 291.94 0.38 712,385.53 5,937,463.27 03-25A 3,852 3,544 3,489 46.49 291.96 0.27 712,359.93 5,937,472.73 03-25A 3,890 3,570 3,515 46.33 291.98 0.42 712,334.07 5,937,482.33 03-25A 3,928 3,597 3,542 46.47 292 0.37 712,308.03 5,937,492.00 03-25A 3,967 3,623 3,568 46.45 292.02 0.06 712,281.93 5,937,501.73 03-25A 4,005 3,650 3,595 46.24 292.1 0.57 712,255.90 5,937,511.44 03-25A 4,044 3,676 3,621 46.02 292.23 0.62 712,230.00 5,937,521.14 03-25A 4,082 3,703 3,648 45.9 292.33 0.36 712,204.21 5,937,530.85 03-25A 4,120 3,730 3,675 45.86 292.57 0.46 712,178.46 5,937,540.64 03-25A 4,159 3,756 3,701 45.83 292.68 0.22 712,152.89 5,937,550.46 03-25A 4,197 3,783 3,728 46.05 292.72 0.58 712,127.17 5,937,560.39 03-25A 4,235 3,810 3,755 46.09 292.64 0.18 712,101.30 5,937,570.36 03-25A 4,274 3,836 3,781 46.34 292.6 0.66 712,075.52 5,937,580.21 03-25A 4,312 3,863 3,808 46.28 292.61 0.16 712,049.60 5,937,590.18 03-25A 4,350 3,889 3,834 46.07 292.59 0.55 712,023.73 5,937,600.11 03-25A 4,389 3,916 3,861 46.2 292.58 0.34 711,997.98 5,937,609.96 03-25A 4,427 3,942 3,887 46.15 292.56 0.14 711,972.18 5,937,619.86 03-25A 4,466 3,969 3,914 46.01 292.55 0.36 711,946.18 5,937,629.78 03-25A 4,504 3,996 3,941 45.82 292.55 0.5 711,920.49 5,937,639.60 03-25A 4,542 4,022 3,968 45.93 292.51 0.3 711,894.74 5,937,649.46 03-25A 4,580 4,049 3,994 46.03 292.53 0.27 711,869.38 5,937,659.15 03-25A 4,618 4,075 4,020 45.82 292.56 0.56 711,844.09 5,937,668.80 03-25A 4,656 4,101 4,046 45.85 292.56 0.08 711,818.72 5,937,678.52 03-25A 4,693 4,128 4,073 45.81 292.53 0.12 711,793.41 5,937,688.18 03-25A 4,730 4,153 4,098 45.55 292.46 0.72 711,768.96 5,937,697.52 03-25A 4,768 4,180 4,125 45.57 292.31 0.29 711,743.77 5,937,707.07 03-25A 4,805 4,206 4,151 45.92 292.31 0.93 711,718.44 5,937,716.64 03-25A 4,843 4,232 4,177 46.13 292.28 0.56 711,693.11 5,937,726.19 03-25A 4,881 4,258 4,203 45.72 292.25 1.09 711,667.88 5,937,735.69 03-25A 4,918 4,285 4,230 45.37 292.31 0.93 711,642.63 5,937,745.24 03-25A 4,956 4,311 4,256 45.2 292.36 0.46 711,617.68 5,937,754.64 03-25A 4,994 4,338 4,283 44.96 292.45 0.66 711,592.62 5,937,764.16 03-25A 5,031 4,364 4,309 44.84 292.45 0.32 711,567.84 5,937,773.60 03-25A 5,069 4,391 4,336 44.75 292.41 0.25 711,543.04 5,937,783.01 03-25A 5,107 4,418 4,363 44.89 292.35 0.39 711,518.27 5,937,792.42 03-25A 5,144 4,444 4,390 45.14 292.28 0.67 711,493.32 5,937,801.83 03-25A 5,182 4,471 4,416 45.22 292.2 0.26 711,468.39 5,937,811.24 03-25A 5,220 4,498 4,443 45.19 292.14 0.14 711,443.25 5,937,820.64 03-25A 5,257 4,524 4,469 45.25 292.14 0.16 711,418.26 5,937,830.01 03-25A 5,295 4,551 4,496 45.28 292.14 0.08 711,393.11 5,937,839.41 03-25A 5,332 4,577 4,522 45.14 292.15 0.38 711,368.46 5,937,848.64 03-25A 5,369 4,603 4,548 45.21 292.15 0.19 711,343.79 5,937,857.87 03-25A 5,406 4,629 4,574 45.26 292.23 0.21 711,319.37 5,937,867.04 03-25A 5,443 4,655 4,600 45.32 292.27 0.18 711,295.07 5,937,876.21 03-25A 5,479 4,680 4,625 45.33 292.41 0.27 711,270.65 5,937,885.44 03-25A 5,517 4,707 4,652 45.58 292.49 0.69 711,245.83 5,937,894.89 03-25A 5,554 4,733 4,678 45.58 292.62 0.25 711,220.97 5,937,904.37 03-25A 5,591 4,759 4,704 45.78 292.66 0.54 711,196.09 5,937,913.93 03-25A 5,628 4,785 4,730 45.91 292.72 0.37 711,171.21 5,937,923.52 03-25A 5,665 4,810 4,755 46.25 292.74 0.92 711,146.29 5,937,933.15 03-25A 5,703 4,836 4,781 46.54 292.85 0.81 711,121.11 5,937,942.92 03-25A 5,740 4,861 4,806 46.87 292.94 0.91 711,095.93 5,937,952.72 03-25A 5,777 4,887 4,832 47.02 293.15 0.58 711,070.74 5,937,962.60 03-25A 5,814 4,912 4,857 47.36 293.24 0.93 711,045.38 5,937,972.62 03-25A 5,851 4,937 4,882 47.38 293.22 0.07 711,019.85 5,937,982.74 03-25A 5,889 4,962 4,907 47.67 293.21 0.78 710,994.36 5,937,992.83 03-25A 5,926 4,987 4,932 48.12 293.25 1.21 710,968.74 5,938,002.99 03-25A 5,963 5,012 4,957 48.44 293.2 0.87 710,942.98 5,938,013.18 03-25A 6,000 5,037 4,982 48.61 293.28 0.48 710,917.03 5,938,023.47 03-25A 6,037 5,061 5,006 48.36 293.19 0.7 710,891.17 5,938,033.70 03-25A 6,074 5,086 5,031 48.45 293.16 0.25 710,865.27 5,938,043.96 03-25A 6,111 5,110 5,055 48.52 293.15 0.19 710,839.87 5,938,053.98 03-25A 6,147 5,134 5,079 48.68 293.21 0.46 710,814.38 5,938,064.03 03-25A 6,184 5,158 5,104 48.57 293.27 0.33 710,788.83 5,938,074.15 03-25A 6,221 5,183 5,128 48.44 293.3 0.36 710,763.40 5,938,084.28 03-25A 6,258 5,208 5,153 48.73 293.32 0.77 710,737.23 5,938,094.68 03-25A 6,296 5,232 5,177 48.89 293.35 0.43 710,711.05 5,938,105.12 03-25A 6,333 5,257 5,202 48.94 293.55 0.42 710,684.85 5,938,115.62 03-25A 6,370 5,281 5,226 49.1 294.44 1.86 710,658.89 5,938,126.29 03-25A 6,408 5,306 5,251 49.27 295.91 3 710,632.91 5,938,137.64 03-25A 6,445 5,330 5,275 48.66 297.6 3.79 710,607.45 5,938,149.57 03-25A 6,482 5,355 5,300 48.79 299.63 4.1 710,582.47 5,938,162.31 03-25A 6,519 5,379 5,324 49.22 301.74 4.44 710,558.00 5,938,175.90 03-25A 6,557 5,403 5,348 50.14 304.37 5.92 710,533.77 5,938,190.71 03-25A 6,594 5,427 5,372 51.42 305.89 4.65 710,509.59 5,938,206.74 03-25A 6,631 5,450 5,395 52.74 307.54 5 710,485.68 5,938,223.53 03-25A 6,668 5,472 5,417 53.54 308.65 3.21 710,461.69 5,938,241.25 03-25A 6,705 5,494 5,439 53.94 308.82 1.14 710,437.82 5,938,259.33 03-25A 6,743 5,516 5,461 54 308.84 0.17 710,413.72 5,938,277.62 03-25A 6,780 5,538 5,483 54.13 308.91 0.38 710,389.70 5,938,295.88 03-25A 6,817 5,560 5,505 54.24 309.02 0.38 710,365.85 5,938,314.07 03-25A 6,854 5,581 5,526 54.66 309.05 1.15 710,342.15 5,938,332.20 03-25A 6,890 5,602 5,547 55.23 309.03 1.56 710,318.43 5,938,350.36 03-25A 6,927 5,623 5,568 55.4 309.14 0.52 710,294.47 5,938,368.73 03-25A 6,963 5,643 5,588 55.77 309.32 1.1 710,270.86 5,938,386.93 03-25A 6,999 5,664 5,609 55.69 309.48 0.43 710,247.15 5,938,405.31 03-25A 7,036 5,684 5,629 56.19 309.55 1.39 710,223.49 5,938,423.72 03-25A 7,072 5,704 5,649 56.6 309.65 1.14 710,199.32 5,938,442.60 03-25A 7,109 5,724 5,669 57.01 309.77 1.15 710,175.15 5,938,461.52 03-25A 7,146 5,744 5,689 57.62 309.74 1.67 710,150.89 5,938,480.58 03-25A 7,183 5,764 5,709 57.83 309.67 0.59 710,126.38 5,938,499.78 03-25A 7,220 5,783 5,729 57.77 309.78 0.3 710,101.76 5,938,519.08 03-25A 7,256 5,803 5,748 57.97 309.87 0.58 710,077.35 5,938,538.29 03-25A 7,293 5,822 5,767 58.06 309.91 0.26 710,052.96 5,938,557.53 03-25A 7,330 5,842 5,787 57.98 309.95 0.24 710,028.45 5,938,576.91 03-25A 7,366 5,861 5,806 58.39 309.99 1.12 710,004.02 5,938,596.22 03-25A 7,403 5,880 5,825 58.71 310.1 0.91 709,979.52 5,938,615.68 03-25A 7,440 5,900 5,845 58.63 310.21 0.33 709,954.86 5,938;635.31 03-25A 7,477 5,919 5,864 58.55 310.29 0.29 709,930.36 5,938,654.88 03-25A 7,513 5,938 5,883 58.76 310.3 0.57 709,905.85 5,938,674.48 03-25A 7,550 5,957 5,902 58.73 310.35 0.14 709,881.42 5,938,694.09 03-25A 7,586 5,976 5,921 58.23 310.47 1.41 709,857.38 5,938,713.37 03-25A 7,622 5,995 5,940 58.33 310.59 0.4 709,833.49 5,938,732.66 03-25A 7,658 6,013 5,959 58.74 310.81 1.25 709,809.60 5,938,752.06 03-25A 7,695 6,032 5,977 59.04 311.02 0.96 709,785.59 5,938,771.72 03-25A 7,731 6,051 5,996 59.35 311.28 1.06 709,761.74 5,938,791.41 03-25A 7,767 6,069 6,014 59.7 311.47 1.07 709,737.81 5,938,811.33 03-25A 7,804 6,088 6,033 60.08 311.72 1.18 709,713.28 5,938,831.88 03-25A 7,840 6,105 6,050 60.51 311.91 1.28 709,689.36 5,938,852.09 03-25A 7,876 6,123 6,068 60.71 312.05 0.65 709,665.45 5,938,872.40 03-25A 7,913 6,141 6,086 61.02 312.2 0.9 709,640.55 5,938,893.68 03-25A 7,952 6,160 6,105 61.03 312.4 0.45 709,614.91 5,938,915.70 03-25A 7,991 6,179 6,124 60.91 312.57 0.49 709,589.38 5,938,937.81 03-25A 8,029 6,198 6,143 60.74 312.65 0.47 709,563.84 5,938,959.98 03-25A 8,068 6,217 6,162 60.41 312.76 0.89 709,538.48 5,938,982.13 03-25A 8,107 6,236 6,181 58.88 313.06 4.02 709,513.45 5,939,004.09 03-25A 8,145 6,257 6,202 57.01 313.3 4.88 709,489.02 5,939,025.75 03-25A 8,184 6,278 6,223 55.44 313.13 4.06 709,464.85 5,939,047.20 03-25A 8,223 6,301 6,246 53.94 312.92 3.91 709,441.25 5,939,068.00 03-25A 8,261 6,324 6,269 52.4 312.87 3.99 709,418.02 5,939,088.37 03-25A 8,299 6,347 6,292 51.24 312.57 3.09 709,395.38 5,939,108.14 03-25A 8,337 6,372 6,317 49.3 312.62 5.11 709,373.32 5,939,127.30 03-25A 8,375 6,397 6,342 48.13 312.69 3.09 709,351.81 5,939,146.03 03-25A 8,413 6,422 6,367 46.87 312.49 3.34 709,330.68 5,939,164.38 03-25A 8,451 6,448 6,393 45.94 312.12 2.55 709,309.85 5,939,182.29 03-25A 8,489 6,475 6,420 45.79 311.87 0.62 709,289.15 5,939,199.87 03-25A 8,527 6,501 6,446 45.91 311.8 0.34 709,268.49 5,939,217.35 03-25A 8,564 6,527 6,472 45.76 311.63 0.52 709,247.95 5,939,234.65 03-25A 8,593 6,547 6,492 45.65 311.49 0.52 709,232.37 5,939,247.69 03-25A 8,616 6,563 6,508 45.72 311.44 0.34 709,219.67 5,939,258.29 03-25A 8,639 6,579 6,524 45.67 311.39 0.27 709,207.05 5,939,268.78 03-25A 8,662 6,595 6,540 45.82 311.37 .0.65 709,194.34 5,939,279.37 03-25A 8,685 6,611 6,556 45.48 311.32 1.48 709,181.65 5,939,289.90 03-25A 8,708 6,627 6,573 45.44 311.36 0.21 709,169.06 5,939,300.35 03-25A 8,731 6,644 6,589 45.57 311.36 0.57 709,156.45 5,939,310.84 03-25A 8,754 6,660 6,605 45.64 311.29 0.37 709,143.85 5,939,321.33 03-25A 8,777 6,676 6,621 45.53 311.03 0.93 709,131.13 5,939,331.81 03-25A 8,800 6,692 6,637 45.17 309.96 3.69 709,118.48 5,939,342.01 03-25A 8,823 6,708 6,653 45.05 308.49 4.58 709,105.64 5,939,351.90 03-25A 8,850 6,727 6,672 45.15 307.15 3.52 709,090.12 5,939,363.26 03-25A 8,879 6,748 6,693 45.28 305.13 4.88 709,072.88 5,939,375.12 03-25A 8,909 6,769 6,714 45.72 303.56 4.06 709,055.12 5,939,386.53 03-25A 8,938 6,789 6,734 46.15 302.28 3.42 709,036.88 5,939,397.60 03-25A 8,968 6,810 6,755 46.16 300.06 5.42 709,018.32 5,939,408.14 03-25A 8,997 6,830 6,775 46.43 298.51 3.96 708,999.67 5,939,417.91 03-25A 9,026 6,850 6,795 46.78 297.53 2.72 708,980.67 5,939,427.34 03-25A 9,055 6,870 6,815 46.91 296.72 2.09 708,961.61 5,939,436.44 03-25A 9,084 6,890 6,835 46.66 296.38 1.21 708,942.37 5,939,445.36 03-25A 9,113 6,910 6,855 46.13 296.24 1.86 708,923.25 5,939,454.17 03-25A 9,142 6,930 6,875 45.82 296.03 1.19 708,904.30 5,939,462.79 03-25A 9,171 6,950 6,895 45.95 295.44 1.53 708,885.34 5,939,471.28 03-25A 9,200 6,970 6,915 46.15 294.42 2.62 708,866.14 5,939,479.57 03-25A 9,229 6,990 6,935 46.11 293.54 2.19 708,846.79 5,939,487.53 03-25A 9,258 7,010 6,955 46.03 293.03 1.3 708,827.46 5,939,495.19 03-25A 9,287 7,031 6,976 45.84 292.48 1.5 708,807.90 5,939,502.74 03-25A 9,316 7,051 6,996 45.7 292.01 1.26 708,788.48 5,939,510.08 03-25A 9,345 7,071 7,016 45.7 291.86 0.37 708,769.02 5,939,517.27 03-25A 9,375 7,091 7,036 45.77 291.88 0.24 708,749.45 5,939,524.52 03-25A 9,404 7,112 7,057 45.78 292.07 0.47 708,729.94 5,939,531.75 03-25A 9,433 7,132 7,077 45.93 292.21 0.62 708,710.46 5,939,539.04 03-25A 9,462 7,152 7,097 45.93 292.41 0.5 708,691.00 5,939,546.38 03-25A 9,490 7,172 7,117 45.86 292.53 0.38 708,671.58 5,939,553.78 03-25A 9,519 7,192 7,137 45.97 292.64 0.47 708,652.31 5,939,561.16 03-25A 9,548 7,212 7,157 45.99 292.59 0.14 708,632.87 5,939,568.60 03-25A 9,577 7,232 7,177 45.97 292.54 0.14 708,613.53 5,939,576.01 03-25A 9,606 7,252 7,197 46.01 292.46 0.24 708,594.03 5,939,583.46 03-25A 9,635 7,273 7,218 45.9 292.4 0.4 708,574.40 5,939,590.93 03-25A 9,665 7,293 7,238 45.73 292.28 0.65 708,554.75 5,939,598.33 03-25A 9,693 7,313 7,258 45.62. 292.25 0.39 708,535.57 5,939,605.57 03-25A 9,722 7,333 7,278 45.52 292.27 0.36 708,516.49 5,939,612.76 03-25A 9,750 7,353 7,298 45.39 292.31 0.47 708,497.47 5,939,619.96 03-25A 9,779 7,373 7,318 45.32 292.36 0.27 708,478.45 5,939,627.16 03-25A 9,807 7,393 7,338 45.45 292.32 0.46 708,459.36 5,939,634.36 03-25A 9,836 7,413 7,358 45.29 292.27 0.57 708,440.38 5,939,641.53 03-25A 9,865 7,433 7,379 45.19 292.26 0.35 708,421.45 5,939,648.65 03-25A 9,893 7,454 7,399 44.99 292.21 0.71 708,402.57 5,939,655.75 03-25A 9,922 7,474 7,419 45.12 291.95 0.78 708,383.54 5,939,662.84 03-25A 9,950 7,494 7,439 45.42 291.56 1.43 708,364.54 5,939,669.82 03-25A 9,979 7,514 7,459 45.62 291.31 0.94 708,345.36 5,939,676.72 03-25A 10,007 7,534 7,479 45.6 290.79 1.3 708,326.05 5,939,683.55 03-25A 10,038 7,555 7,500 45.65 289.71 2.56 708,305.59 5,939,690.45 03-25A 10,068 7,576 7,521 45.61 288.9 1.91 708,284.89 5,939,697.06 03-25A 10,098 7,598 7,543 45.42 288.71 0.77 708,264.28 5,939,703.41 03-25A 10,128 7,619 7,564 45.35 288.69 0.24 708,243.72 5,939,709.72 03-25A 10,159 7,640 7,585 45.31 288.68 0.13 708,223.21 5,939,716.04 03-25A 10,189 7,661 7,606 45.38 288.5 0.48 708,202.53 5,939,722.35 03-25A 10,219 7,682 7,627 45.68 288.2 1.22 708,181.94 5,939,728.52 03-25A 10,249 7,704 7,649 45.73 287.96 0.59 708,161.11 5,939,734.68 03-25A 10,280 7,725 7,670 45.71 287.85 0.27 708,140.39 5,939,740.74 03-25A 10,310 7,746 7,691 45.6 287.82 0.37 708,119.63 5,939,746.79 03-25A 10,340 7,767 7,712 45.52 287.81 0.27 708,098.88 5,939,752.81 03-25A 10,370 7,788 7,733 45.39 287.77 0.44 708,078.28 5,939,758.80 03-25A 10,400 7,809 7,754 45.14 287.65 0.89 708,058.07 5,939,764.61 03-25A 10,430 7,830 7,775 45.09 287.69 0.19 708,037.79 5,939,770.46 03-25A 10,459 7,851 7,796 45.05 287.61 0.23 708,017.56 5,939,776.23 03-25A 10,489 7,872 7,817 45.46 287.43 1.45 707,997.36 5,939,782.01 03-25A 10,519 7,893 7,838 45.85 287.37 1.31 707,976.82 5,939,787.82 03-25A 10,548 7,913 7,858 45.93 287.34 0.28 707,956.33 5,939,793.58 03-25A 10,578 7,934 7,879 45.86 287.27 0.29 707,935.71 5,939,799.35 03-25A 10,608 7,955 7,900 45.79 287.2 0.29 707,915.23 5,939,805.08 03-25A 10,637 7,975 7,920 45.71 287.11 0.35 707,894.80 5,939,810.74 03-25A 10,667 7,996 7,941 45.71 287.06 0.12 707,874.17 5,939,816.47 03-25A 10,697 8,017 7,962 45.94 287 0.79 707,853.70 5,939,822.10 03-25A 10,726 8,037 7,982 45.85 286.97 0.32 707,833.37 5,939,827.69 03-25A 10,756 8,058 8,003 45.7 287 0.51 707,813.04 5,939,833.28 03-25A 10,786 8,079 8,024 45.71 287.09 0.22 707,792.41 5,939,838.97 03-25A 10,816 8,100 8,045 45.79 287.11 0.27 707,771.76 5,939,844.70 03-25A 10,846 8,120 8,065 46.05 287.07 0.87 707,751.05 5,939,850.43 03-25A 10,875 8,141 8,086 46.31 287 0.89 707,730.31 5,939,856.15 03-25A 10,905 8,162 8,107 46.39 287.12 0.39 707,709.42 5,939,861.91 03-25A 10,935 8,182 8,127 46.59 287.25 0.74 707,688.60 5,939,867.71 03-25A 10,965 8,203 8,148 46.45 287.37 0.55 707,667.73 5,939,873.58 03-25A 10,995 8,223 8,168 46.63 287.37 0.6 707,646.76 5,939,879.48 03-25A 11,025 8,244 8,189 46.7 287.5 0.39 707,625.85 5,939,885.42 03-25A 11,054 8,264 8,209 46.57 287.57 0.48 707,605.47 5,939,891.23 03-25A 11,083 8,284 8,229 46.64 287.52 0.27 707,584.97 5,939,897.08 03-25A 11,113 8,304 8,249 46.85 287.43 0.75 707,564.40 5,939,902.92 03-25A 11,142 8,324 8,269 46.84 . 287.43 0.04 707,543.83 5,939,908.72 03-25A 11,172 8,345 8,290 46.98 287.4 0.48 707,522.83 5,939,914.70 03-25A 11,204 8,366 8,311 47.04 287.47 0.25 707,500.52 5,939,921.00 03-25A 11,233 8,386 8,331 47.04 287.56 0.23 707,479.97 5,939,926.85 03-25A 11,262 8,406 8,351 46.7 287.68 1.19 707,459.37 5,939,932.76 03-25A 11,291 8,426 8,371 46.28 287.81 1.47 707,439.00 5,939,938.64 03-25A 11,321 8,447 8,392 45.85 288.03 1.57 707,418.77 5,939,944.57 03-25A 11,350 8,467 8,412 45.48 288.43 1.6 707,398.71 5,939,950.53 03-25A 11,379 8,488 8,433 45 288.9 1.99 707,378.79 5,939,956.65 03-25A 11,409 8,509 8,454 44.53 289.65 2.38 707,358.87 5,939,962.99 03-25A 11,447 8,536 8,482 44.01 290.59 2.17 707,333.38 5,939,971.51 03-25A 11,487 8,565 8,510 43.63 291.07 1.26 707,307.28 5,939,980.61 03-25A 11,527 8,594 8,539 43.18 290.99 1.13 707,281.33 5,939,989.74 03-25A 11,567 8,624 8,569 42.7 290.99 1.2 707,255.63 5,939,998.81 03-25A 11,608 8,653 8,599 41.79 290.84 2.27 707,230.06 5,940,007.74 03-25A 11,648 8,683 8,628 41.32 290.85 1.18 707,205.03 5,940,016.50 03-25A 11,688 8,714 8,659 41.06 290.88 0.65 707,179.99 5,940,025.22 03-25A 11,727 8,743 8,688 40.89 291 0.48 707,155.72 5,940,033.74 03-25A 11,767 8,773 8,718 40.66 291.05 0.59 707,131.33 5,940,042.34 03-25A 11,806 8,803 8,748 40.42 291.02 0.61 707,107.26 5,940,050.79 03-25A 11,846 8,833 8,778 40.13 290.93 0.75 707,083.16 5,940,059.28 03-25A 11,885 8,863 8,808 39.85 290.95 0.71 707,059.35 5,940,067.64 03-25A 11,924 8,894 8,839 39.5 291.05 0.9 707,035.56 5,940,075.99 03-25A 11,964 8,924 8,869 39.22 291.07 0.71 707,012.02 5,940,084.31 03-25A 12,003 8,955 8,900 39.05 291.07 0.43 706,988.66 5,940,092.53 03-25A 12,042 8,985 8,930 38.76 291.12 0.75 706,965.77 5,940,100.66 03-25A 12,077 9,012 8,957 38.52 291.27 0.74 706,945.18 5,940,107.96 03-25A 12,111 9,039 8,984 38.26 291.39 0.78 706,924.87 5,940,115.24 03-25A 12,144 9,065 9,010 38.46 291.43 0.62 706,905.81 5,940,122.12 03-25A 12,169 9,085 9,030 38.53 291.39 0.29 706,891.01 5,940,127.42 03-25A 12,187 9,099 9,044 38.59 291.4 0.33 706,880.31 5,940,131.26 03-25A 12,204 9,112 9,057 38.43 291.54 1.11 706,870.67 5,940,134.77 03-25A 12,221 9,125 9,070 38.28 291.61 0.94 706,860.96 5,940,138.28 03-25A 12,237 9,138 9,083 38.19 291.54 0.6 706,851.24 5,940,141.82 03-25A 12,250 9,148 9,093 38.09 291.49 0.85 706,844.07 5,940,144.40 03-25A 12,250 9,148 9,093 38.08 291.49 1.95 706,843.77 5,940,144.51 03-25A 12,250 9,148 9,093 38.08 291.49 0 706,843.76 5,940,144.50 03-25A 12,250 9,148 9,093 38.09 291.49 103.13 706,843.75 5,940,144.50 03-25A 12,395 9,262 9,207 38.09 291.49 0 706,759.73 5,940,174.90 STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shuLfq�pvy�11�JG /� Suspend ❑ Perforate 0 Other Stimulate ❑ After Casing ❑ Change ApproOed'PltTgra7fi v Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development D Exploratory ❑ 5. Permit to Drill Number. 193-023 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 1 Stm igraphic ❑ Service ❑ 1 e. API Number: 50-029-21021-01-00 7. Property Designation (Lease Number): ADL 028328 8. Well Name and Number: PBU 03.25A 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 12395 feet Plugs measured 10802, 11844 feet clue vertical 9262 feet Junk measured 11784, 11823, 12010 feet Effective Depth: measured 11802 feet Packer measured 11321 feet true vertical 8800 feet Packer true vertical 8447 feet Casing: Length: Size: MD: TVO: Burst: Collapse: Structural Conductor 80 20" 26-126 26-126 Surface 2507 13-3/8" 26-2533 26-2507 5380 2670 Intermediate 8767 9-518" 24-8791 24-6686 6870 4760 Production Liner 3728 7" 8667-12395 6599-9262 8160 7020 Perforation Depth: Measured depth: 11476 -11838 feet True vertical depth: 8557-8828 feet Tubing (size, grace, measured and true vertical depth) 6-117'17# x 4-1/2" 12.6# 13Cr80 22-11377 22-8486 Packers and SSSV (type, measured and 4-112" Baker SABL-3 Packer 11321 8447 true vertical depth) No SSSV Installed 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. 863 27942 83 965 863 Subsequent to operation: 964 45214 338 1306 910 14. Attachments: (reeured r 20 MC 25mo 25071, a 25283) 15. Well Class after work. Daily Report of WeII Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work. Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Summers, Matthew Contact Name: Summers, Matthew Authorized Title: Production Engineer Contact Email: Matthew.SummerstiMbp.cem Authorized Signature: - Date: 316 134 Contact Phone: +1 9075645066 Form 10404 Remsed 0412017 �%115y `Submit Onginal Only MROMS�MM e 8 =0i� Daily Report of Well Operations PBU 03-25A ACTIVITYDATE SUMMARY 4/19/2019 ***WELL FLOWING ON ARRIVAL*** (adpert) RIG UP HES ELINE UNIT 4863 ***CONT. ON 04/20/2019 WSR*** ***CONT. FROM 04/19/2019 WSR*** (adpert) LRS PERFORM L8 k RIH W/ 2-7/8" X 15' MAXFORCE PERF GUN PERFORATE FROM 11732'- 11747' WITH 2.875" 6 SPF 60 PHASE HSC W/ MAXFORCE CHARGES. CCL TO TOP SHOT = 13.5', CCL STOP AT 11718.5'. CORRELATE TO SLB PPROF DATED 10 -MAY -02. 2' CORRECTION FROM REFERENCE LOG (PERFORATED: 11730'- 11745') 4/20/2019 ***JOB COMPLETE, WELL LEFT S/I**` TTS= Cw WELLHEAD= FMC ACTUATOR= BAKER OKB. ELEV = 62' REF ELE%f = 5493' BF. R3F/ = 30.52' KOP= 2100' Mu Angle = 61-@7952- Datum MD= 11883' Oat: ND= 8800' SS 17- 113-3/8- CSG, 72#,L-80, 12 12.34T Minimum ID = 3.726" @ 11371' 4-112" PARKER SWN NIPPLE TOC NIA PER SCMT (07/25/18) 5-12" TBG, 17#,13 -CR -80 0.0232 bpf, D = 4.892- 17- BAKER TEBACK SLV,D=7.500' { 7" X 9-5/8" BAKER H PKR/LNR HGR ID = 6.937" —� 9-5/8" CSG, 47#, L-80, D = 8.681" { 7" LNR 29#, NT -80S, 0.0371 bpf, D = 6.184' X0T07"29#13CFF80LNR(THRIADCHANGEI a 03-25A SA`I=`"NOTER 40' 7" X 5-12" XO, D = 4.892" 8744' 6825' 879V 11217' 1123W -11244' PEF FORATION SL A"RY REF LOG: BHCS ON 0323/93 ANGLE AT TOP PERF: 44° Q 11476' Note: Refer to Production DB for historSal perf data SIZE SPF 141E2VAL Opn/Sgz SHOT SQZ 2-7/8" 6 11476-11496 O 07108!16 3161 2-718' 6 11500-11520 O 07/08/16 T-2 3-3/8' 4 11695-11710 S 06122/93 5056 2-7/6' 6 11730 - 11745 O 04/20/19 20 2-12" 6 11747 - 11777 O 0727/18 57 2-7/8" 6 11780- 11790 O 08/26117 07/03/16 3-3/8" 4 11820-11838 S 12/18193 LR 3-3/8" 4 11828 - 11838 C 03/08/01 "5 3-318" 6 11870 - 11874 S 0622/93 DW 3-3/8" 4 11882 - 11886 S 1211&93 8565 3-3/8" 6 11886 - 11890 S 0622193 T-2 3-3/8" 4 12066 - 12076 S 02128/01 1 FISH: -22' OF 2-7/8" SLTD LNN/SCRN, 5 WFD GAS LFT MANpifl.S ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3161 3050 38 LR DDNE T-2 16 0726116 2 6030 5056 48 LR SO T-2 20 0726118 3 7167 5755 57 LR DMY T-2 0 07/03/16 4 7870 6120 61 LR DW T-2 0 04/12/94 "5 8337 6371 49 LR DW T-2 0 03/31/93 '6 8565 6528 46 LR Dk4Y T-2 0 01/14/01 'STAR 5 & #6 = B6ANO C9ARi4T MUED I- 11794' CTD ,CBP 1 B0WEN 11823' 315-F12117101 8625 5-12" X 41/2" XO, ID = 3.958" MLLOUT WNDOW (03-25A) 8791' - 8841- BI02 SABL-3 D = 3.875" 11371' 1-14-12" PARKER SWN NIP, D=3.725" 1 DATE REV BY COK*Awrs DATE I REV BY C0RNAENTS 12105)83 ORIGINAL COMPLETION 031141191 AW/JMD CORRECT® IA T0C(0725118) 03131193 RIG SIDETRACK 05/01/19 NXW/J AOPBiFS (0420N9) 07/11118 KFNYJMD RLL RUG, SET PLUG & CMT RET, TBG PLI CH 0726118 JCF/JfvD CMTANMLUSIMLLED RET &CBFVSET FISH 07/3&18 CJWJMD GLV (90 (072&18) 07/30/18 BTWJMD AWERFS (0727118) 11374' ELMD TT LOGGED OQ 6/93 11802' KrERVV LL 363-700 HEX 11844" H7"PP0SISET PLUG 1(07128/11) PRUDHOE BAY t1NR WELL: 03-25A PERMT N1: 1930230 AR Hb: 50-029-21021-01 T10N, R15E, 1014' FSL & 28' FEL BP Exploration (Alaska) 193023 • RECEIV29 25 1 WELL LOG TANS ITT LS MAY 11 2018 AOGCCPROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Natural Resources Technician II 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2-1 900 Benson Blvd. Anchorage, AK 99508 GANCPDC@USAANC.hou.xwh.BP.com and ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite CNOW UN J 14 Anchorage, AK 99518 c Fax: (907) 245-8952 1) LeakPointTM Survey 05-Apr-18 03-25A Color Log/CD 50-029-21021-01 2) Signed : / V Date : C°11/(63 (B Print Name: M. 1 PROACTIVE DIAGNOSTIC SERVICES, INC. 130 W.INTERNATIONAL AIRPORT RDC UITE S ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGEtMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Wchives\MasterTem IateFiles\Tem lates\Distribution\TransmittalSheets\BP Transmit docx P P _ ti OF Tit 44)1 \ Iy/�:s?, THE ST* Alaska Oil and Gas fALA KA ;t 0 Conservation Commission St>�=_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 leiOff; 7- t P Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jaime Bronga Wells Interventions Engineer SCANNED BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-25A Permit to Drill Number: 193-023 Sundry Number: 318-180 Dear Mr. Bronga: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of May, 2018. BpM t� ,M AY Q 8 2018 R STATE OF ALASKA • ry 6 ALASKA OIL AND GAS CONSERVATION C SION APR L 6 APPLICATION FOR SUNDRY APPR ALS 20 AAC 25.280 S/ / 11/ 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well IZI • ACIGCR,❑ Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program J Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other IA Squeeze • Z 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 193-023 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-21021-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No O PBU 03-25A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028328 • PRUDHOE BAY.PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): 11371, Junk(MD): 12395 ' 9262 • L 11371 8482 11802,11839,11844 11823,12010 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 26-106 26-106 1490 470 Surface 2507 13-3/8" 26-2532 25-2506 5380 2670 Intermediate 8767 9-5/8" 24-8791 24-6686 6870 4760 Production Liner 3728 7" 8667-12395 6599-9262 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11476-11838 8557-8828 5-1/2"17#x 4-1/2"12.6# 13Cr80 22-11377 Packers and SSSV Type: 4-1/2"Baker SABL-3 Packer Packers and SSSV MD(ft)and TVD(ft): 11321/8447 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary m Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development m Service 0 14.Estimated Date for Commencing Operations: May 10,2018 15. Well Status after proposed work: Oil Q WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Bronga,Jaime be deviated from without prior written approval, Contact Email: Jaime.Brongaabp.com Authorized Name: Bronga,Jaime Contact Phone: 9075644151 Authorized Title: Well Interventions Engineer r Authorized Signature: ; , '" Date: 2� /• COMMISSION USE LY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31,1_ Ito Plug Integrity 0 BOP Test El Mechanical Integrity Test Location Clearance 0 Other: .....T.--r7 c/ d -c / ✓1 ct, 1-1,,1`7(ia_) Pee re�po�-f- o r1 Ccrtilckt- $1v{�3r5 . ReV/cw rr,5vlf5 of cA') Vii A106,cC •1- d Lokv 7--c /vi tci n,t �cr-1, t`/��5 a 5 - )- i Post Initial Injection MIT Req'd? Yes 0 No ,/ Spacing Exception Required? Yes 0 No 12/ Subsequent Form Required: /0 - 1_0 ,rf, '' APPROVED BYTHE u Approved by: COMMISSIONER COMMISSION Date: r ie �( ��� i'7-L 5�'4118 � AY � 1018 ORIGINAL y �� $ �" Submit Form an Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicat bp • 0 . Well: 03-25A 03-25A Cement Job Intervention Engineer Jaime Bronga 907-564-4151 Production Engineer Matthew Summers 907-564-5066 Reservoir Engineer Brandon France 907-564-4046 History 03-25A is a not operable Ivishak producer shut in since April 2018 due to a production casing leak at the liner tieback while screening the well for a coiled tubing drilling sidetrack. By repairing this well with an IA cement squeeze, it is estimated that an incremental 360 mbo can be produced over the next several years. Without an IA remedial squeeze, this well has no utility in the foreseeable future. Formation Depths: jc 4Clt' rNr wet' Mf been 4eoit/ -4.UG4 Top: 5779'md, 4828' TVDss k Oho( Cvitee l i, f"41.0 W 10 UG4 BTM: 9057'md, 6816' TVDss LAec '', q 7" estimated TOC: 11,000' md, 8226' TVD with 30% washout qu.A f,� ` f cur ' m 4 - • 11 9-5/8" estimated TOC: below kick out depth 7 ! CtKeet qt..Ince �,.1 60t Me Objective z f /hCFfsrr . (fit 4014 w4*ercPt- aid Return the well to operable status and drill the sidetrack. 60A r��c�f, .�,e, S (�`tT� ! i ACrPgf'� Expected Start Date: May 1, 2018 Ghy u►ell touoric qt(04 �`ppy� ��lr �r � i Rhd Aga- j;.4fiCtki 6 Oft _p i to 4 a cr 74) Post-Job Evaluation /,?t( -t, sawack ''1 Pr- (eAK mutt it ,,,ei, This well is a gas lifted producer; an AA will not be applied for. The following BP internal criteria to evaluate t e integrity of the non-rig workover will be applied: • CMIT-TxIA Nr IT I . 0 • SCMT /4° 9' • MIT-T Long-Term Integrity Monitoring • Record WHPs daily (includes pressure monitoring of the Inner Annulus to be cemented to -8164'MD) • 2 year (biennial) CMIT-TxIAs and MIT-Ts Integrity Screening 4/5/18: LDL identified leak at 9-5/8" x 7" liner hanger at 8674'md 4/6/18: CMIT-TxIA to 2500psi failed with a LLR of lgpm 3/10/18: MIT-T to 2551 psi passed 10/13/17: TIFL passed 1983: OA shoe is cemented. TIO Plot 4 0,00 -240 3 800 • 3 600 a -220 3.400 200 3.200 3.0410 -180 TIO Plot 2.800 2 600 160 —0 Tbg IA 2.400 -140 OA 2.200 00A 2,000 -120 9, 000A 1 Boo re-r' A-4 Lax Z On 1 600 ''"""1*** 'F'mmr; -100 X Bleed 1,400 - -* Operable 1.200 .-L• Not Oper ow • Under Eval Temperature 600 400 -20 200 11. 116Z7:2 „ 14 97'13/14 1019414 0112015 04/2315 07/2515 10/26115 01,27/16 04.2016 07131/16 11C1,16 02,0271'-35136/17 050717 11 03,1' r,2 09 Procedure Slickline 1. Dummy GLVs. MIT-T. 2. Pull PXN from 11371'md. Eline 3. Set CBP at -11260'md. MIT-T. 4. Punch across the collar at -11239'md. 5. Set Cement Retainer at -11219'md. MIT-T. Coiled Tubing 6. Sting into cement retainer and circulate the IA to diesel. 7. Cirulate -67 bbls of Class G cement into the IA to get the TOC in the IA up to -8164'md. Cement design parameters are below. 8. WOC for 500psi compressive strength. 9. Mill out retainer and CBP. Push to TD. Slickline 10. SCMT to confirm TOC. re rtrw ito c 11. Set PXN plug. 12. CMIT-TxIA to 2500psi. 13. MIT-T to 2500psi. 14. Set live design. 15. Pull PXN. DHD 16. Update AKIMs for biennial MIT-Ts and CMIT-Tx1As Operations 17. Put well on Production. Proposed Cement Blend Parameters 2 • • Blend: Cement Type/Weight: Class G 15.8ppg. Batch Mixed. Field Blend to be +/- 0.1 ppg Slurry Temperature: Between 80 and 110 deg F API Fluid Loss: 40-200 cc Compressive Strength: 2000psi in 48 hrs Thickening Time: Minimum 6.5 hrs Activity Time (hrs) Shearing time, quality control, PJSM 1 Cement Displacement 1.5 Cement Contamination 2 Safety 1 Min Required Thickening Time 5.5 Ramp: Time Temp Pressure 0:00 90 0 1:00 180 4000 2:00 190 4000 3:00 200 4000 4:00 200 4000 7:00 200 4000 15:00 200 3500 3 'FREE= CNV FMC IIRTY WELLHEAD= ____________ • 03-25A 3-2 5A ACTUATOR= BAKER C NOTES. -0K141ELEV= 62' REF BEV= 54.93' BF_ELEV= 30.52' 40' —17"X 5-1/2"XO,D=4.892" KOP= 2100' Max Angle 610 @ 7952' 2184' H5-1/2"CAM BAL-O SSSV NP,1::4.562" Datum MD 11883' CI Datum TVD= 8800'SS 7"TBG,26#,13-CR-80,0.0383 bpf,D=6.276" —{ 40' GAS LFT MAMDRB S 2 ST MD TVD DEV TYPE VLV LATCH PODATE 13-3/8'CSG,72#,L-80, D=12.347" — 2538' 1 3161 3050 38 LR DONE T-2 16 10/10/17 2 6030 5056 48 LR DOME T-2 16 10/10/17 3 7167 5755 57 LR SO T-2 26 10/10/17 Minimum ID =3.725" 11371' El 4 7870 6120 61 LR DMY T-2 0 04/12/94 4-1l2" PARKER SWN NIPPLE 5 8337 6371 49 LR DMY T-2 0 03/31/93 6 8565 6528 46 LR DMY T-2 0 01/14/01 5-1/2"TBG,17#,13-CR-80 NSCC, H 8625' 0.0232 bpf,D=4.892" / 8625" H5-1/2"X 4-1/2"XO,D=3.958" 7"BAKER TEBACK SLV,D=7.500" —I 8667' 7"X 9-5/8"BAKER H PKR/LNR HGR,D=6.937" H 8674' MLLOUT WINDOW(03-25A) 8791'-8841' 9-5/8"CSG,47#, L-80,D=8.681" H 8791' 7"LNR,29#,NT-80S, 0.0371 bpf,D=6.184" H 11217' XO TO 7"29#13 CR-80 LNR(THREAD CHANGE) —I 11217' 11280' —,4-1/2"PARKER St/VS NP,D=3.813" R 11/4, 11326' 7"X 4-1/2"BKR SABL-3 '. V/ PERM PKR,D=3.875" V/ 11355' H4-1/2"PARKER SWS NP,D=1813" 4-1/2"TBG,12.6#,13-CR-80 NSCT,0.0152 bpf,D=3.958' - 11383'_ 11371' H4-1/2"PARKER SWN NP,D=3.725" •• 11371' —14-1/2"PXN PLUG(03/09/18) PERFORATION SUMMARY REF LOG: BHCS ON 03/23/93 11383' —{4-1/2"WLEG,D=3.958" ANGLE AT TOP PERF:44"©11476' , 11374' HELM)TT LOGGED 04/26/93 Note:Refer to R-oduction DB for historiSal pert data SIZE SPF IVTERVAL Opn/Sgz SHOT _ SOZ 11802'—NIERWELL 363-700 HEX 2-7/8" 6 11476-11496 0 07/08/16 $ PLUG(08/26/17) 2-7/8" 6 11500-11520 0 07/08/16 % 11839' —{EST TOC(7/28/11) 3-3/8" 4 11695-11710 S 06/22/93 2-7/8" 6 11780-11790 O 08/26/17 6‘‘‘ 11844' 7"POSISETPLUG ij3-3/8" 4 11820-11838 S 12/18/93 i‘‘r 07/28111) 3-3/8" 4 11828-11838 C 03/08/01 3-3/8" 6 11870-11874 S 06/22/93 3-3/8" 4 11882-11886 S 12/18/93 3-3/8" 6 11886-11890 S 06/22/93 3-3/8" 4 12066-12076 S 02/28/01 �l\1�FISH:-22'OF 2-7/8"SLID LNR/SCRN,5 WFD SPEAR GRAPPLES(-1/2"X4"), 1 BOWEN 11823' 1§1;41;\� SPIRAL GRAPPLE(2.673"X5")(06/20/13) \%%%% \ FISH-TEL ARM(4"X 2"X 3/8")-12/17/01 - ? Nt%11` J \jk6 7"LNR,29#,13-CR-80,0.0371 bpf,D=6.184" H 12395' DATE REV BY COM ENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/05/83 ORIGNAL COMPLETION 10/12/17 RCB/JMD GLV C/O(10/10/17) WELL: 03-25A 03/31/93 RIG SIDETRACK 10/12/17 JLS/JMD GLV TABLE CLEAN UP PERNMT No: 1930230 12/17/11 LEC/PJC SET LINER SCREEN(10/25/11) 03/12/18 JMG/JMD SET PXN RUG(03/09/18) API No: 50-029-21021-01 06/24/13 TJWJMD PULLED XN LOCK/SET FISH(01 04/26/18 JNUJMD ADDED REF&BF&MO VW DOW SEC 9,T1 ON,R15E,1014'FSL&28'FEL 07/12/16 CJS/JMD ADPERFS(07/08/16) 08/28/17 MS/JMD SET HIX PLUG&ADPff2FS BP Exploration(Alaska) . , • IA Cement Job Schema. 483.11-840* RC ACTUA TOR* BAKER C 03-25A SAFETY MTES; ckS ELE1(* 62' BF 8-E1= KOP* 2100' ) 1114 At*/- 61 a 71812 /% . , . 1 4 ' H7-x 5-62-xo,63*4.892-1 016441143= 11162/ Illalail 1-1/2-CAM 041-0 usv 44,4571-669 Daum WO= 8900 SS [7: .* 266,13.04-80.0,0303 bat 41*0,276" -4 ,41Y GAS LFT NANCFELS L ST, M) No De/ DIE V Of LATCH TYAIT DATE 1 13-3/V CUT,r2g,L-M, 6.i 2,34r 216V1* Fai 7la 1 3161 3060 38 Lit COME 1-2 16 10110117 " 2 6030 5066 48 Lit DOME T-2 16 10/10011 Ihtininium 03=3:725-cp 11371' C3 3 7761 6785 67 LR St) T-2 28 10110/17 4 71370 6120 61 IR CAN T-2 0 04/12/941 4-1/2"PARKER SWN NO5PLE , ,-- 5,8337 6371 40 LR C11.1Y T-2 0 03131/13 t 6 6565 0528 48 1 LII CAW T,2 0 0E14001, i'." Tyx2 6-1/2-160,174,13-01,430 MCC, 8625* ---„ \L' sow 5-irr X 4-VT AO,0*3,950- I' nui,i,„ ,,iii,..it,„„,6.4 jai H.,_ise_ .3- , , ' ' A 31402/MP SA r Ir x9-5itr Kt:RH nalq.Nrt fcri o d mr B04° mi.,. '-- ;,,,,, 134LLOUT1614C4743103.25,4111-541"CSO.478. L-80.0=&Ger H , , " Li:LW,284„NT-005. 04371 6p1.13=6.1 ar 1121r f; % • 11260' 4-iir PAR/MEWS RP, XC)To r 210 1311140 LrEt(61FIEADOANSE) 11217' 4 ,, t e'( (.)--- . 1 .. r 4) x4rk ir4.1,KR, *3.$75" I 0 Jo O :44 1 tA 1.4 C , NI.40' MkIll`! r1686. H4-12-WEER IMO 161),10=axis. 1 i t,., Milj 4412.7661244. ,13-04-60 WM,04152 bvir,ID 003.256' --id. 11383.,j v, mmihm 11371' ,i-iii-Poi- **666410,U325 1 • IRO 141.. 02.FM PLUG 0, , la)1 PEffC4161106 SUGARY 'Z'lk. 1161 REF LOGBIAS M01723493 i4 r 1 -- f-r-'1,71-oktc,4)*.3 160-1 ANGLE 67!MFG*:44'0 114717 s % 1 ' ahorno,t 4.•0 ..-E We Wel'to Rode/40n 03 for 1161/0801 pert 6661 Ilk SiE SW IN1131VAL Opraqz *CT SOZ nor 441u 363-708 FOX I 2-118' 6 11478-11496 0 01111616 VTo IRO)(0026/17) J 2-718' 0 11600-11620 0 0710616 .40,..." 11639. 1ST TOC 1710/111 8.38. 4 1105-11710 S 06122163 2-718' 8 11780-11760 0 06126117 4.64 11s44. r.iv.:,:-i Fula , • 3-341' 4 11420-11636 S 12/1693 ./,..;?.,'-' (01,021111) 3-30" 4 11428-11836 0 06(001 3-10. 6 11470-11V4 S 0672M „ 3-316" 4 11882-11806 S 12/1643 3.30" 6 11686-11890 S 06/72.003 3-346" 4 12066-12076 S 02126001 I It* —... 446 4 8 FOR-22"OF 2.706-SLTO L/6880124 51AFD, ,-4,64.,/s GR&PFIES i-112-X4-1, 1 BOWEN 11823' *4401411444% SPRAL(0,14PPLE -2 073-XV)10012013) #1,1114440,440, *---- -------------- - - NR1414416ilit RSH-Ta A114(4-xr xsr).12117/01 7 Nt144 kt 4* to ti, Slot. , No, 4,7j_LN11,m_204 13-0480,0.0371 bpi,it)=6 1.4.. 123W _ DATE REV BY COIAIENTS '' 0A1E 10/BY 006666/16 PRL10117€PAY tial 12/65/83 01133644L 031411.E710/4 10112117 16.2361661 MN MI(18110/17) WELL. 03-25A ..... 0313063 NG SIDETR4,0C 10112r17 .1LS/AID ON TASLEOSAN IP P13W Nia. 1930230 12117(11 LIKYRIC SET 1/4ER WPM,/(10*25/11) 03112/18 Ja#344)SET PXN RAZ(03rOtai a) ARM,' 50028-2102801 06/24/13 TittlieRkLEDX14100SET F8341("1 $ ) SIMS,T1014,RISE,1014 FSL&26 Fa. 07/12J16 CA"..643 ACFEFFS(07#016/16) 06121617 6166.6.4) SET 1-EX FLUG&Aortifs 4- * W?lat&Milos(Mask* 5 • III Future P&A Plan: 943 L ASE x 11 00.41' 21tXr 0i,• r ^ 14410,14 Ar.fr 1 /55/1 '0/e J{..,.,,._. Or ft x a**0*ti* 1 . *4„r LA P CRwo,Is,meo o we,1 .enarJ I r f i” _ t 1t t 4 ' VIA,,,LA. .,.1111'1, 15A . a 4 " a l l tW 1/ rto7 03 Ttz 01 iru1 ID 0 3. 4;` 113/1" # 1 11111111111 r° . e seer _— ;. r X 0A**0 i1 ooPlBlie�nrtx4*3 erre j WSW V& L.$6.0*1.60' H r 2 a _,. -- . -P xolo .m._....,_ m Isart 4 .i ` ati`" a bt3At,1s*Ott(PlM413*7. f 61v [ � ," 11371 -ion ! 1 .A .A'7 `+61*.11 [ It *�wo .fa zror . U48-1 0 &Oslo ", : /J In , 341r f 4 1 11#13 1 9 s,_««;';tom„'1; '” arirr�" " �, 3 4 1 1 0 ? s� '11 " E r 3 ks,., . 11 w $3• ' 4 1 11 C 1.3* I $ a f tAilio 1104 $ a r • 4 1 1t :,1; $ 3.3, 4 1 a z2 t1 j $ s S40. 4 I 1 " mommool 14,1414 i*411i*1114, [7:7 0400711A1-2 ora11 113) 171174,41411147* X 3"X 12/11¢ 1 r7 41044,14444 11 14461* 41 Y 1Ed6 x 4A :C 1 f TAAI 0094 IP RAW 444 711 1 .k `49' *1 &1111 * 4 111111111 VIII If �$,11>9 X, 114' A 1 Y' 1 r 6 • • Loepp, Victoria T (DOA) From: Bronga,Jaime <Jaime.Bronga@bp.com> Sent: Wednesday, May 02, 2018 2:20 PM To: Loepp,Victoria T (DOA) Subject: RE: PBU 03-25A(PTD 193-023, Sundry 318-180)IA Squeeze Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, The incremental 360 mbo is from from fixing the PC leak and putting the existing wellbore back on production. It does not include any potential sidetracking incremental. Jaime From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, May 02, 2018 1:35 PM To: Bronga, Jaime Subject: RE: PBU 03-25A(PTD 193-023, Sundry 318-180) IA Squeeze Thanx for the information. Is the incremental 360 mbo from fixing the PC leak and putting the well back on production or from the sidetrack? From: Bronga,Jaime<Jaime.Bronga@bp.com> Sent:Wednesday, May 02, 2018 11:35 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: PBU 03-25A(PTD 193-023,Sundry 318-180) IA Squeeze Hi Victoria, The TOC of the 9-5/8" in 03-25 was 9900'md with 30%Washout.03-25A was kicked out of the 9-5/8" PC at 8750'md so 03-25A is above the TOC. KO depth for the proposed sidetrack is^'11700'md.There is not a schematic prepared for the proposed CTD sidetrack. After this well is operable the screening will continue and a sidetrack sundry will be submitted. Here is the TIO plot.The IA pressure was from gas lift.This well is a gas lifted producer which was online and flowing until April when a drilling screening discovered the PC leak. 1 tDe — — - --- -24D 3.634 a 27.' r 4M k 340 7:DD il4 Pict DDD .t so 2.826 2 633 - 6 Tbp IA 200 —II—OA VM OOA 2 DCO A - i • 000A t.bxl —on moit .: Bleed 1.t00 1 I - • Opctably DJ - Nal Opac 3670 • Uncle!E val BtU Tent pettily to 403 1 25 'y't. 5'I5' 10,51a DS.r'S -54.7i315 G775" 132615 u``-'2:.1 3C24,15 0733 1€ 11G1 6'2i32.. $ ()VA.!? ce,r17 '1 :"'7 52551x' From: Loepp, Victoria T(DOA) [mailto:victoria.loepp©alaska.gov] Sent: Wednesday, May 02, 2018 11:19 AM To: Bronga, Jaime Subject: PBU 03-25A(PTD 193-023, Sundry 318-180) IA Squeeze Jaime, A few questions: What is the estimated TOC of the 9-5/8" and how was it determined? What is the KO depth for the proposed sidetrack? Do you have a schematic of the proposed CTD sidetrack? Could you provide a colored TIO plot? Where is the pressure in the IA coming from? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeop(a alaska.clov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 2 • • C1.31 E a, (`r r` In N 6uQ a > F co cov O H 0 t @ 3 t N p g m F co w -0 co 6. (V N > O a ro o 0 0 N o a1 C >, _ @ N ro L N Q 0 , r- r- n r- r- n N v E a m 0 v u a >` on cr 6D o) m a 4- -a ° N O co 3 W g -, a a Q a s to C Z Q — ,- N 00 !r O N 00 4-, L C N u -0 CO O u N 0 'v O C i }, u }' ro O 110000000 0 0 0 (0 u v U a w J J J J J J J J J OD 0 } W W W W W W W W LL. N U w F- LL LL LL LL LL LL LL LL LL 4., CU a a) -0 or F J J J J J J J J J °- _0 > yam., N CO Q Q Q Q Q Q Q Q Q a) C Y- O c:n ciZ Z Z Z Z Z Z Z Z u co v O v •,^„ LL LL LL LL LL LL LL. LL LL C -0 C > > C N v u M 0 z E v > ;° O c o ro ° - c .g a H > u aui +- K N C (9 Q O O ttl U > Q cu 0. 0 C a LL Yn 011 U O o .45 a a re R' CC N N 0 'L� dy G } a w SOS U 5 .. F V cc, S/7 O ai i' co C t° 1u o t as — .1 wt0S r- � as to w > u r O. J 0 J J J J 0 0 J � a cc a) � 3 0 W 3 C vorlypip c:11 39.91 2' mZmmmmmmm oI XIII IIZ cry -10610000 0 0 0 a) cc WrCeetYCLCere W _... • +o 0 a a a a a a a a a m o �. o. a V o0 w.:, h o r� rn rn co og 7 0 X n O O MO C " O t0 N N 00 _ 0 0 0 0 0 0 0 0 0 0 CI) 0 0 0 0 0 0 0 0 0 •� �y O C . 0 0 0 0 0 0 0 E W 't4 p u -i d a O D a Iva F-� 0 U 0 No m m m co W v CD Q in 0000 `- 0000 a w 000000000 co H a m m O v .- 0 0 0 0 0 0 Q LO n 0 0 0 0 0 0 0 0 0 •o• M v 00 0> o r r` ate. -a 00 COOCO CO CO Co 0000 N 0 CD0 !' > N N I- 0 m N N N N N N N N N N E N C C O C) 0 0 0 0 0 0 0 0 0 @ C 0 0 0 0 0 0 0 0 0 4, a+ a) W c C in to to NN tQ to in o in -a m Z rn E u to E O 03 u v a o W w 3 0 a 0U ° C) 'Q Z d 61 `i Q Q N N y Z• O N co « aJ C L`I N W a.+ UD M Z to m •-. 1_ N r' a+ E 0! @x' K Ca sIf' `O N J LL O Z 5. O M .,- E @ N u J ,..t ur w J0703p 0 c Z IA 0, 0 Q O ra - co u, a OCA a � 1- at —0. m • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: SC7'/7IYp lc 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 193-023 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number 50-029-21021-01-00 7. Property Designation(Lease Number): ADL 0028328 8. Well Name and Number PBU 03-25A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 12395 feet Plugs measured See Attachment feet true vertical 9262 feet Junk measured 11823/12010 feet OCT 0 2 2017 Effective Depth: measured 11802 feet Packer measured 11321 feet aaa��� �. true vertical 8800 feet Packer true vertical 8446.72 feet AOS ..( Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 27-107 27-107 1490 470 Surface 2507 13-3/8"72#L-80 26-2533 26-2507 4930 2670 Intermediate 8761 9-5/8"47#N-80 24-8785 24-6682 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feetsatitiED Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 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: 140 0 8344 1875 251 Subsequent to operation: 0 25066 1126 675 294 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 2 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Chamansingh,Ann Marie Contact Name: Chamansingh,Ann Marie Authorized Title: Petroleum Engineer Contact Email: AnnMarie.Chamansingh@bp.co Authorized Signature: �i +nA... Date: "r' Contact Phone: +1 9075644070 Form 10-404 Revised 04/2017 VIl/• t ' /b!(p/ L� fj �JUYlili7 tV � ,' i - 3 251Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED OCT 022017 RE: BP Exploration (Alaska), Inc. ROGCC Report of Sundry Well Operations Summary September 21, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of Plug and Addition of Perforations for Well 03-25A, PTD # 193-023. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Plugs Attachment PBU 03-25A SW Name Date MD Description 03-25A 08/27/2017 11802 HEX Plug 03-25A 07/28/2011 11839 SAND PLUG 03-25A 07/26/2011 11844 7" Posiset Plug • • Cu .o• 0000000 Cu t` N- O N N r 00 O CO Is O O T' (NI a) • N Ns C` UD CO N- () 60) 00 CD CO CO Tr tt C) ig V CD oD r r N N- m Nr CO 03 00 N- N- 00 ▪ Cs N N C10 CO Ns • O CO N- CC) CC) CO 00 CC) CO CO N 07 U) Nt rN0003O) C000 C3 I I 1 1 1 1 1 1 H N- CO d' Off) N N CC) COO N N N CO 00 N 00 CD it CD co 1.0 N O ti 0 Ul N '- N M (N rO N 0 r r O r C.) 4-11 Q CV Q N N- CDvCOrNCnN a) N N N CO N () CD C M M O O co c) C00 � oo � 0 .Tr _i 0L . C' C 4t U U r r •� y cm Co - CD Off) CCOO T- (.) V - N N N _N I O)O O CO UD Ns C'0 C10 [O C 00 U0 Ns UD r r C[) N- J N 00 N r 00 N W Q _0 15 U W LjW as U 0 u_ Ctr a Z Z Z Z W W W m m m Z Z UO fn Z J J F- F- F- • • a) Cn Ca • Cn 0 . O) O O c) O CD • N- 00 M O) A- co co CD C0O co CO x- 0 00 CO O CO CO CO (b CO CO CO CO 0) a 0 CO CO N CD CO N- O O CD N y 't 0 �f CO CA O 0 N CY) O CO af� 4OCMCh [ncDN ‘- 4mC`7 0 d II) I� N- CO N N CC) CO O O O W 0 0 CnN- N- CO CO O o0 co co O O > O o0 Co co CO CO 00 CO CO CO CO - 0) 0 2 W c Z LU UJ 0 W 1- a w g g Y 0 O > m 0 0 W Y Y 2 Y CO 0 0 O CO O CO t7 CD CO O CO N J U V W L W O N �— Cy) (N M (') N- O CO Cy) N- J J J Q Q CO W CY o E• L V to N- N- co co CD co co co co N U_ _< U_ J W W 0 ? o Z Z Z O p OJ J O J d = 2 2 Z 0 0 i_ 0 W W W W c 0 < 2 2 2 0 ccoo a N co co CU la • 0. = 0 . CO0CC) 00CCO (00N000O C0 o 0 N- n (0N coo cooccN-o 00oc00oCO N ▪ m Lco) Q. a) Ne m _ F- O1 — a J a 2 2 2 0 cn m m co co d a. 0 0 LL_ LL N LL (/) Cl) U) (/) (/) Cl) (/) Cl) 0- 0- C5aaaaaaaaa d QQcnQmmmmmmmm a O t m CL W J D W 0 a) a m W Q O O N N- N- N- N- N- N- N- N- N- 0 C7 0 O 0 0 0 0 0 0 0 0 0 0 0 W LL J J Z u- oc N c N- N N N N N N N N N Z CL 0 < W W co co co N N N N N N N N N CO D a C! 0 0 W w C. N. N. CO CO CO OD CO o0 CO CO CO 00 z 0 0 0 J J D Ce d 0 m 0 2 tr J J 0 0 W W m m LL CL co co a a) E Q Q Q Q « «Q Q Q Q Q Cn CC) C1) CC) CC) In CC) Cn Cn Cn 0 CC) 3 N N N N N N N N N N N N 0 0 0 0 0 0 0 0 0 0 0 0 < < m m u.. L� co 0 w , • • Packers and SSV's Attachment PBU 03-25A SW Name Type MD TVD Depscription 03-25A PACKER 8668.47 6599.87 7" Baker H Packer 03-25A TBG PACKER 11320.56 8446.72 4-1/2" Baker SABL-3 Packer • ! 2 a z � w U_ cc d- 0 (n 0 a0 0 a a_ O O O co 0 J w0 W ci w mZ O a ¢ a0 0 = CD z o a C� p } X w u: 0 I� z Ja o H = V u) 0 M oco zo c, I- 2 2 2 a H w a H cfl a M v N = D = w < a0 H z z 0 0 0 co- Q Cl) p 0 * = H J 0 a Hots U) = 0 � -J O a' F W D W> = J W' J cn H ' w CD . - vi w H , U p ce Li- W O Z i- p 0 w H W J Z w M W W 0 H 0- w w 0 m m W > < -1w a m 0 0 w 0 < U) 0 2 -laa W W WI— 1- H u) a, p H O = U) W W a U Q W Z O W 0 w 000' Q N ++ a aH p � ZQ -- JF, --31- W2 - H5ZJ = m0 a E i Q O W J Z w a W W p W w M Z N J J w E N v � m0 - O Ow < mm = rip z Uz z pp_ Q; a ? "= 2 � pm0 z p _' QH2 n 0 X • U - z NH 0 < (n o (Jn O w cJnvZ � , � �H X •a p p u) _ . U 0 O N E � F_ Li_ pp � * � � p � O � � N � _1O li ' O O H Z p O OT- (n Z TS W ? U Z N Q Eo N- UMW W — Q (V TS J WQO � ap au' a t m J Q< C p m W - z = ip - - , _, -H U N p W w N N 2 O 0 _10 "- C CLQ Uo mHH 0 O a > � Z .- := pci wo . LiImw (CLAr._ a2J o. cn �, wC� o 2WDam W NU aM � O � UONZ D re ct a � w EoD < Z 2UQN2Ow < II J w (nUp = Ii co Z > � I�LW WQNZ F- uS 25 a = UOI�i. 0OOOr § o1HWr Z 0 0N � ao0wOWOo HwHww23 0 ca ca W0aa;w0Uc( owpw 0w Z1n1.nZa =' JppS ZwpDD = QW NZH � II ao � 0 > H NI- O Q w I-- Q 0 � aoo2HmF2H i 2 � zZZLUZ � � aUw < F- 0w J OUzwO -' (/) 1- 7=--, RHU- zzW0Q ¢p � mQOQDUWZuia i 5 0 u. a (n z 0 0 H W < : W - -0 U z < O J a Z Z W Q m J H d 0 0 U U J ; = W CC J = F J 0 W = H U Wp00w (nwpQ � HaYppcLQ (n � z � a a _JWOQp a� . 0 (..„ . z , ,,- w0 wQ z w : ? 0 > 2 = W 0 = Q w w a W . 'al Er : : price : i ? 5cn0 _i : : UQmaa0OOU < O 0 : 0 w H Qr- r- F r- > 0 0 0 0 co Hv n in m N H co ao co N 0 co Q VVELLHEA0= • FMC 'ACTUATOR= BAKER C SAFETY NOTES: OKB.ELEV= 62' 03-25A BF.ELEV= KOP= 2100' Max Angle= 61 @ 7952' J 40' Hr X 5-112"XO,D=4.892" Datum MD= 11883' ../(3 Datum ND= 8800'SS 2184' 5-1/2"CAM BA SSSV NP,D=4.562" 7"TBG,26#,13-CR-80,0.0383 bpf,ID=6.276" H 40' K GAS LET MANDRELS ST MD ND DEV TYPE VLV LATCH PDRT CATE 13-3/8"CSG,72#,L-80, D=12.34T — 2538' li 1 3161 3050 38 LR T-2 2 6030 5056 48 LR T-2 3 7167 5755 57 LR T-2 Minimum ID =3.726" @ 11371' L 4 7870 6120 61 LR 1-2 4-1/2" PARKER SWN NIPPLE 5 8337 6371 49 LR T-2 6 8565 6528 46 LR 1-2 5-1/2"TBG,17#,13-CR-80 NSCC, —1 8625' 0.0232 bpf,D=4.892" / 8625' H5-1/2"X 4-1/2"XO,D=3.958" 7 BAKER TACK SLV,D=7.500" 8667' 1 0 7"X 9-5/8"BAKER H PKR/LNR HGR D=6.937" H 8674' 1i MLLOUT WINDOW(03-25A) 1 9-5/8"CSG,47#, L-80,D=8.681" 1--f 8791' -I—Ah 7"LNR,29#,NT-80S, 0.0371 bpf,13=6.184" 1121T XO TO 7"29#13 CR-80 LNR(THREAD CHANGE) --1 11217' 11280' H4-1/2"PARKER SWS NP,D=3-813" .. 11326' —7"X 4-1/2"BKR SABL-3 /. 1/0" PERM PKR D=3.875" 4-1/2"TBG,12.6#, 13-CR-80 NSCT,0.0152 bpf,D=3-958' H 11383' Nr/P- 11355' H4-1/2"PARKER SWS NP,13=3-813" 1 11371' --I4-112"PARKER SWN NP,11).3.725" PERFORATION SIJIJ RY RIF LOG: BRCS ON 03/23/93 11383' --14-112"VVLEG,ID=3.958" ANGLE AT TOP PERF:44°@ 11476' * 11374' —{E JVI3 TT LOGGED 04/26/93 Note:Refer to Production DB for historSaI pert data , SIZE SPF INTERVAL Opn/Sqz SHOT SO7 11802' —V'/TERWEL.L 363-700 HEX 2-7/8" 6 11476-11496 0 07/08/16 S PLUG(08/26/17) 2-7/8" 6 11500-11520 0 07/08/16 11839' --I EST TOC(7/28/11) 33/8" 4 11695-11710 S 06/22/93 2-7/8" 6 11780-11790 0 08/26/17 � i 11844' —7"POSISET PLUG 3318" 4 11820-11838 S 12118193 i ►•/ (07/28/11) 3-3/8" 4 11828-11838 C 03/08/01 3-3/8" 6 11870-11874 S 06/22/93 3-3/8" 4 11882-11886 S 12/18/93 3-3/8" 6 11886-11890 S 06/22/93 _ 3-3/8" 4 12066- 12076 S 02/28/01 A FISH:-22'OF 2-7/8"SLID LNWSCRN,5 WFD SPEAR GRAPPLES(-1/2"X4"), 1 BOEN — 11823' �4444\ W SPIRAL GRAPPLE(2.673"X5")(06/20/13) 144\4\ FSH-TEL ARM(4"X 2"X 318")-12/17/01 ? ;,; \;g. 7"LNR 29#, 13-CR-80,0.0371 bpf,D=6.184" --I 12395' DATE REV BY COMMENTS DATE REV BY COM4E3TS PRUDHOE BAY UNT 12/05/83 ORIGINAL COMPLETION 12/17/11, LECJPJC SET LINER SCREEN(10/25/11) WELL: 03-25A 03/31/93 RIG SIDETRACK 06/24/13 TJt-VJMD PULLED XN LOCK/SET FISH(06/18-: FERMI No: 1930230 07/29/11 11W/PJC SET FOSISET PLUG(07/28/11) 07/12/16 CJS/JMD ADPERFS(07/08/16) AFI No: 50-029-21021-01 11/06/11 LEG PJC SLID LNR/ROCK SCRN(10/2E 08/28/17 MS/JMD SET HEX PLUG&ADPERFS SEC 9,T1ON,R15E, 1014'FSL&28'FEL 11/06/11 LEC/PJC FISH-TEL ARM(02/17/01) 12/17/11 LEC/PJC SFTY NOTE UPDATE(10/25/11) BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 I Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 193-023 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21021-01-00 7. Property Designation(Lease Number): ADL 0028328 8. Well Name and Number: PBU 03-25A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RECEIVED 11.Present Well Condition Summary: AUG0 8 tt C Total Depth: measured 12395 feet Plugs measured 11839/11844 feet G 2016 true vertical 9262 feet Junk measured 11823/12010 feet Effective Depth: measured 11839 feet Packer measured 11321 feet ,OGCC true vertical 8828 feet Packer true vertical 8447 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 27-107 27-107 1490 470 Surface 2507 13-3/8"72#L-80 26-2533 26-2507 4930 2670 Intermediate 8761 9-5/8"47#N-80 24-8785 24-6682 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See AttAment See Attachment true vertical depth) '""""+► 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED JAN 3 1 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 320 455 9617 1854 368 Subsequent to operation: 171 2822 8740 1826 318 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signatureiff Phone +1 907 564 4424 Date 8/4/16 i Form 10-404 Revised 5/2015 O 1�� i d / I RBDMS I, " AUG 1 1 2016 Submit Original Only • • CD c,• 0 0 CD 0 0 0 0 N N CO O O I`- O O V' N (D O N N- N- to ON-- U NOOc) 00000 L O M N- (D CO 'Cr V M • - D) a0 r N N- W CO CO CON- N- CO N- N N CO CO O O CO N- LU (0 O CO (D CO CO N CO LC) r N CO 00 D) CO CO C11 1 1 1 I 1 1 1 f'- LO N CO N- CO O) N- N (n CO N N N (t) CO N M LO CO CO4.0 CO C Q� M 11) N CD O N" a Ln M M CO MN- CN N CO r Co V 0 CU _4. Q O _� N CO • co N N ) CO • a O COO co 0) 0 °O ' J Z c M co * U U N ,rj N- N- Z M N N N - (N d N N- v (0 03 O O ) LU N- co co in co Lo LO J N CO N CO N W 0 W W U a u_ 0 o c Z Z Z Z c W W W m m m O DZH Z_ z_ > UCnJJHHH • • a) N maoco mo (0 C') (o Lri a> I- aooOLa 4 NCO � COco (c p LnLoOa0MMaMaoO p mm mm a0 00 00 M 6) O r a) c0 O Co N- O O CO N t r CD CO CA O CD N CO a) C. f-- 4 a7 M CA Cfl N = d' M 0 O Lo ti r r LO O LO Lo N c0 00 ONO aO aa0 ap M O p CO a) a) a) a) a) a) a) a) M rn 0 w a 0 0 W Z w 0 W 0 a y 3gY v ° 0 ca O O co w Y Y z O O O c0 CO aO V C0 a0 O O J U 0 W W O N r N M M f M CO O J -J J ¢ ¢ u.) W CY = O- LC) N- cO 00 d0 CO M o0 OO O < < < J 111 Z NC� C7 C) N z z z o 0 a p ¢ ¢ ¢ H E sot- o w w w aO z V � � � � 0 co co co cn co as QN a M F = C s CO O LC) O CO CO O N CO a) (0 O = a N- O 63 N N CO N- a) a) a) CO _ fin00 Ln CO a0 co a0 c0 a) co co O • CV W W r r r = = = = = r r � aCD O2 - - - = H 0 a J a 2 2 O cn co co co co 0) O U O u. L_ N N u u. U) C/) U) (n C/) % 0_ 0_ 0 0 m m m a. d d d O < < w (X W m m m m m a0 0 a) a a) I- M p CO CO M M V V r r r N— 0 0 c O O M (4) 60j 0 0 0 0 0 w Z O N N r r N N N N N Z W ¢ w 2 c0 00 N rM CO O CO O Cfl J N ti O N N N N N N N Z a 0 OW W a w o CO r m O O WJ J J = [Y a J J Q 0 W W ¢ < a cn LL IL W cn a a� E Q Q Q Q Q Q Q ¢ Q ¢ Q z Lo Lo Ln Ln Ln Lo Ln Ln Lo Ln Ln (V N CV N N N N N CV N N W (n O W N (r ti CO CO CO CO CO CO M CO CO CO CO CO a a a 8 J O 0 w a 0 0 0 0 0 0 0 0 0 0 0 < ¢ CD co W Li Cn Cn a (Y s • Packers and SSV's Attachment PBU 03-25A SW Name Type MD TVD Depscription 03-25A PACKER 8668.47 6599.87 7" Baker H Packer 03-25A TBG PACKER 11320.56 8446.72 4-1/2" Baker SABL-3 Packer . . . _ . 0 0 r 0- ±. N: E I ® / o � e \ d © CO E a 2 m LLJ CL ! 0 \ = / 0 2E 2 o R 0 o ƒ2 0 C z J @ W I 2 RU2 \ C/) \ ƒ ƒ 0 0 \ CC f00 0 / . ƒ W Z -I I J ± I - $ « m Os < w z / \ 0 w ± 2 � 2 z z / 6 ^ / D / >, OQ / � Ill (J) z 0 / � I 12 m R 7 2 -r 1 / ƒ ƒ q = 2 \ ƒ b » o 0 m / 0 Z o m < \ c ` - O / \ O 21 ± 27 ¥ , H I p0- ± - R3 / ± k o / m - cu ƒ \ $ = « a7 / 0co02 CL 2 p / \ / I / q / < / $ \ / / / f ƒ � / / < 00c 111 Doff / WWU - OLU � \ 2 2A ± ± L ± - 2 L � p /-- ƒ / O ƒ / -Z / � < \ 21@ ± 2 ± W / I22 ?u- 1Z00W / w2 ƒ / \ m < / / \ f 0 /wk / \ 7 \ - � 1iff � � kk \E /i » i i 2 Io2 % / 3i a w I— (0 e CD I- 'CS \ / ‘- 5 ~ 9 c0 G « w 0 < W LLHEAD= FMC 411 ACTUATOR= BAKER C 03-25A 3-25A SAFETY NOTES: I OKB.ELEV= 62' BF.ELEV= KOP= 2100' Max Angie= 61 @ 7952' J 40' H7"X 5-112"XO,D=4.892' Datum MD= 11883' /I\ 2184' H5-1/2"CAM BAL-O SSSV NP,8800'SS D=4.562" Datum TVD 7^TBG,26#,13-CR-80,0.0383 bpf,ID=6.276" —I 40' GAS LFT MANDRELS 0 ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-80, D12.34r= — 2538' 1 3161 3050 38 LR T-2 2 6030 5056 48 LR T-2 3 7167 5755 57 LR T-2 Minimum ID =3.726" @ 11371' DI 4 7870 6120 61 LR T-2 4-1/2" PARKER SWN NIPPLE 5 8337 63718 49 LR T-2 6 8565 6528 46 LR 1-2 5-1/2"TBG,17#,13-CR-80 NSCC, — 8625' 0.0232 bpf,D=4.892" 8625' —15-1/2"X 4-1/2"XO,D=3.958" 7"BAKER TACK SLV,D=7.500" -- 8667' ----- 7"X 9-5/8'BAKER H PKR/LNR HGR,D=6.937" —r 8674' MLLOUT WNDOW(03-25A) [9-5/8"CSG,47#, L-80,D=8.681 1— 8791' 7'LNR,29#,NT-80S, 0.0371 bpi,D=6.184^ 11217' I XO TO r 29#13 CR-80 LNR(THREAD CHANGE) —{ 11217' 11280' H4-1/2^PARKER SWS NP,D=3.813' 1 Ilk 11326' —7"X 4-1/2"BKR SABL-3 /. VP PERM PKR,ID=3.875" [ 4-1/2'TBG,12.6#, 13-CR-80 NSCT,0.0152 bpf,0=3-958" —I 11383' VP 11355' 1—4-1f2"PARKER SWS NP,D-3.813" 11371' H4-112"PARKER SWN NP,D=3.725" PERFORATION SUMMARY REF LOG: BHCS ON 03/23/93 11383' —14-1/2"WLEG,D=3.958" A NGLE AT TOP PERF:44°@ 11476' 11374' H ELMD TT LOGGED 04126/93 Nate:Refer to Roduction DB for historiSaI perf data SCE SPF INTERVAL Opn/Sqz SHOT SQZ , 2-7/8" 6 11476-11496 0 07/08/16 2-7/8' 6 11500-11520 0 07/08/16 ` 11839' —IESi TOC(7/28/11) 3-3/8" 4 11695-11710 S 06/22/93 3-3/8" 4 11820-11838 S 12/18/93 41" 11844' —7"POSISET PLUG 3-3/8" 4 11828-11838 0 03/08/01 ��i�� (07/28/11) 3-3/8" 6 11870-11874 S 06/22/93 3-3/8" 4 11882-11886 S 12/18/93 3-3/8" 6 11886-11890 S 06/22/93 33/8" 4 12066-12076 S 02/28/01 . ,4 FISH:-22'OF 2-718"SLTD LNR/SCRN,5 WFD SPEAR GRAPPLES(-1/YX4'), 1 BOWFIN 11823' t44`%� SPRAL GRAPPLE(-2.673"X5")(06/20/13) N`;1�, FISH-TEL ARM(4"X 2"X 318")-12/17/01 —{ ? �;` Ntk 7"LNR,29#,13-CR-80,0.0371 bpf,D=6.184" H 12395' DATE REV BY COMMENTS DATE REV BY COMIVENTS FRUDHOE BAY UNIT 12/05/83 ORIGINAL COM'LETK)N 12/17/11 LEC/PJC SET LPER SCREEN!(10125/11) WELL: 03-25A 03/31/93 RIG SIDETRACK 06/24/13 TJH'JMD FULLED XN LOCK/SET FISH(06/18•; F13;14T No:'1930230 07/29/11 TTW/PJC SET FOSISET PLUG(07/28/11) 07/12/16 CJS/JMD ADPERFS(07/08/16) AR No: 50-029-21021-01 11/06111 LEG PJC SLID LNR/ROCK SCRN(10/25/11) SEC 9,T1ON,R15E,1014'FSL 8 28'FEL 11/06/11 LEC/PJC FISH-TEL ARM(02/17/01) 12/17/11 LEC/PJC SFTY NOTE UPDATE(10/25/11-) BP Exploration(Alaska) ►3-023 RECEIVE. • 2-(90t 1 MAU MAR 2 3 2015 PRINT DISTRIBUTION LIST BAKER HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 DATA LOGGED 3 2.4/2016 WELL NAME 03-25A 900 E. Benson Blvd. K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska --- LOG DATE February 18,2016 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE March 22,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF-THIN I S #OF COPIES #OF COPIES #OF COPIES 4 4 4 4 4 4 4 1 BP North Slope. 0 I 0 I 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 I 1 0 0 Attn:Ricky Elgarico ATO 3-344 SCANNED v U;'r / 0 2 Q q 16 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 1 1 I 1 I 0 1 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 I 1 I 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 I 1 I 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 *5*Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 I 0 I 0 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: 0 4 4 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 .:: ,'..u:. . x -:: ^.. ian „•. , ...,._i .:":? ..z.'b'sF'o -?t n ;4.' ?R. r %.aT"3.+w°:a°aP.^baw^ ;•:fY` ^a+P'aw kr ... e bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 1 December 30, 2011 ma ., a Mr. Tom Maunder © 3 ' Alaska Oil and Gas Conservation Commission b ps ` ? �' 333 West 7 Avenue Anchorage, Alaska 99501 s? =k Subject: Corrosion Inhibitor Treatments of DS -03 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -03 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, QED 1. ` 2 , Z1-11L Mehreen Vazir BPXA, Well Integrity Coordinator . . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10404) DS -03 10/26/11 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTD # API It cement pumped cement off date inhibitor sealant date ft bbls ft gal 03 -01 1750750 50029200930000 Sealed conductor NA NA NA NA NA 03 -02 1760240 50029202030000 Sealed conductor NA NA NA NA NA 03 -03 1760390 50029202110000 Sealed conductor NA NA NA NA NA 03-04 1760510 50029202180000 Sealed conductor NA NA NA NA NA 03 -05 1760570 50029202220000 Sealed conductor NA NA NA NA NA 03 -06 1760600 50029202240000 Sealed conductor NA NA NA NA NA 03 -07A 2040430 50029202200100 Sealed conductor NA NA NA NA NA 03-08 1760730 50029202310000 Sealed conductor NA NA NA NA NA 03-09 1790220 50029203620000 Sealed conductor NA NA NA NA NA 03-10 1790210 50029203610000 Sealed conductor NA NA NA NA NA 03 -11 1790470 50029203830000 Sealed conductor NA NA NA NA NA 03 -12 1790580 50029203920000 Sealed conductor NA NA NA NA NA 03-13 1790710 50029203990000 Sealed conductor NA NA NA NA NA 03 -14B 2090020 50029204070200 Sealed conductor NA NA NA NA NA 03 -15A 1930150 50029204140100 Sealed conductor NA NA NA NA NA 03 -16A 1970330 50029204150100 Sealed conductor NA NA NA NA NA 03 -17 1791020 50029204200000 Sealed conductor NA NA NA NA NA 03-18A 1930420 50029204210100 Sealed conductor NA NA NA NA NA 03 -19 1830920 50029209710000 0.3 NA 0.3 NA 1.7 7/31/2010 03 -20A 1930470 50029209800100 6.2 NA 6.2 NA 40.8 8/2/2010 03 -21 1831120 50029209900000 6.6 NA 6.6 NA 49.3 8/3/2010 03 -22 1831230 50029210000000 0.0 NA 0 NA 7.7 10/26/2011 03 -23 1831270 50029210040000 >25 21.0 0.8 7/15/2011 5.1 7/18/2011 03 -24A 1980060 50029210150100 1.3 NA 1.3 NA 8.5 9/16/2010 ---- 03-25A 1930230 50029210210100 >25 12.0 2.25 7/1212011 13.6 7/17/2011 03 -26 1831510 50029210270000 0.2 NA 0.2 NA 0.85 8/2/2010 03 -27 1840620 50029211090000 23.5 5.0 0.4 7/12/2011 3.4 7/17/2011 03 -28 1840720 50029211140000 55.0 17.0 0.4 7/122011 3.4 7/17/2011 03 -29 1840790 50029211180000 6.0 NA 6 NA 20.4 8/3/2010 03-30 1840830 50029211220000 4.4 NA 4.4 NA 22.5 8/3/2010 03-31 1840920 50029211290000 10.0 NA 10 NA 113.9 8/3/2010 03-32B 2090050 50029211410200 1.5 NA 1.5 NA 8.5 7/30/2010 03-33B 2050180 50029211420200 7.8 NA 7.8 NA 57.0 7/30/2010 03-346 2000110 50029211320200 02 NA 0.2 NA 9.4 10/26/2011 03 -35 1910800 50029221840000 5.8 NA 5.8 NA 39.1 7/28/2010 03-36A 2070200 50029223400100 1.5 NA 1.5 NA 3.4 7/28/2010 03 -37 2091390 50029234210000 2.5 NA 2.5 NA 16.2 8/2/2010 STATE OF ALASKA + ALASKAAND GAS CONSERVATION COMMISSICIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 0 Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ .. 193 -0230 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 - 6612 50- 029 - 21021 -01 -00 8. Property Designation (Lease Number) : ,, 9. Well Name and Number: ADLO- 028328 - 03 -25A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12395 feet Plugs (measured) 11839 (TOC) feet true vertical 9262.1 feet Junk (measured) None feet Effective Depth measured 12356 feet Packer (measured) 8674 11326 feet true vertical 9231.4 feet (true vertical) 6604 8450 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 34 - 116 34 - 116 Surface 2502' 13 -3/8" 72# L -80 32 - 2538 32 - 2511 4930 2670 Production 8761' 9 -5/8" 47# L -80 30 - 8791 30 - 6686 6870 4760 Liner 3728' 7" 29# 13CR80 8667 - 12395 6599 - 9262 8160 7020 Liner 4 2011 Liner *^� ""' �� Perforation depth: Measured depth: SEE ATTACHED - _ .z. _ True Vertical depth: _ _ _ - - Tubing: (size, grade, measured and true vertical depth) 7" 26# 13Cr80 28 - 40 28 - 40 5 -1/2" 17# 13Cr80 40 - 8625 40 - 6570 4 -1/2" 12.6# 13Cr80 8625 - 11383 6570 - 8490 Packers and SSSV (type, measured and true vertical depth) 7" Baker H Packer 8674 6604 4 -1/2" Baker SABL -3 Packer Ec p.. V 8450 12. Stimulation or cement squeeze summary: AUG 2 2 201) Intervals treated (measured): A#>a 4N1 & Gas Cary. Commission Treatment descriptions including volumes used and final pressure: Anc. srago 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 690 13,546 7,500 333 \ Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory0 Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . lE Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na e J• : LastuA j Title Petrotechnical Data Technologist Signatu = MAW � Phone 564 -4091 Date 8/22/2011 1. Form 10 -404 Revised 10/2010 RBDMS AUG 2 3 ZO ��� r / s•u.!/ Submit Original Only 03 -25A 193 -023 • PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03 -25A 4/26/93 PER 11,695. 11,710. 8,718.99 8,730.31 03 -25A 6/17/93 APF 11,870. 11,874. 8,851.97 8,855.04 03 -25A 6/17/93 APF 11,886. 11,890. 8,864.25 8,867.32 03 -25A 6/17/93 SQZ 11,870. 11,890. 8,851.97 8,867.32 03 -25A 6/22/93 SQZ 11,695. 11,890. 8,718.99 8,867.32 03 -25A 6/27/93 APF 11,820. 11,838. 8,813.75 8,827.48 03 -25A 6/27/93 APF 11,882. 11,886. 8,861.18 8,864.25 03 -25A 6/27/93 SQZ 11,820. 11,838. 8,813.75 8,827.48 03 -25A 6/27/93 SQZ 11,882. 11,886. 8,861.18 8,864.25 03 -25A 12/18/93 SQZ 11,870. 11,874. 8,851.97 8,855.04 03 -25A 12/18/93 SQZ 11,820. 11,828. 8,813.75 8,819.85 03 -25A 12/26/93 APF 12,066. 12,076. 9,003.77 9,011.59 • 03 -25A 12/26/93 RPF 11,882. 11,888. 8,861.18 8,865.78 1 03 -25A 2/4/94 RPF 11,828. 11,836. 8,819.85 8,825.96 03 -25A 7/7/94 RPF 11,828. 11,838. 8,819.85 8,827.48 03 -25A 7/21/99 MIS 11,846. 12,395. 8,833.6 9,262.1 03 -25A 12/10/99 MIR 11,846. 12,395. 8,833.6 9,262.1 03 -25A 7/26/11 BPS 4/ 11,844. 12,076. 8,832.07 9,011.59 03 -25A 7/28/11 SPS G e & J * tS.t, ' eiV 11,839. 11,844. 8,828.25 8,832.07 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 • • 03 -25A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/26/2011: ** *WELL SHUT IN ON ARRIVAL * ** (Eline set posiset plug /dump cement) ;INITIAL T /I /O= 1500/1550/0 RIGGING UP ELINE UNIT TO SET POSISET PLUG & DUMP CEMENT j F ** *JOB CONTINUED ON 27-JULY-11" t i 7/27/201 1 i JOB CONTINUED FROM 26- JULY -11 ( Eline set posiset plug /dump cement) ;SET 7" POSISET PLUG TOP @ 11844' `MADE AN ATTEMPT TO DUMP BAILER FULL OF CEMENT ON POSISET PLUG W/ NO SUCCESS (VISUAL INSPECTION YIELDED PARTIALLY SOLIDIFIED ;CEMENT ON BOTTOM OF BAILER) DUMPED FIRST BAILER FULL OF CEMENT ON TOP OF 7" POSISET PLUG @ 11844', EXPECTED TOP OF CEMENT OF FIRST BAILER RUN= 11841.5' 1 ** *JOB CONTINUED ON 27- JULY -11 ** 7/28/2011 i JOB CONTINUED FROM 27- JULY -11 ( ELINE CEMENT DUMP BAIL) VISUAL VERIFICATION OF CEMENT DUMPED RIH WITH MH22 /CCL/CDB OAL =43' OAW =260# FISHING NECK SIZE = 1.38" AT ;SURFACE VISUAL CONFORMATION BAILER DID NOT DUMP ;RIH WITH MH22 /CCL /CDB OAL =43' OAW =260# FISHING NECK SIZE = 1.38" AT ;SURFACE VISUAL CONFORMATION BAILER DID NOT DUMP MADE FINAL DUMP BAILER OF CEMENT ON TOP OF POSISET SET PLUG (EXPECTED CEMENT TOP @ 11839') ;VISUAL INDICATION AT SURFACE OF CEMENT DUMPED FINIAL T /I /O= 1700/1550/0 ;WELL LEFT SHUT IN SWAB, SSV CLOSED AND OTG I ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL FLUIDS PUMPED GALS 8 CLASS H 16.2 PPG CEMENT 8 TOTAL TREE = CM/ WELLHEAD = FMC • SA• NOTES: LAST TD RUN ON 3/6101; 3 -3/8" ACTUATOR = BAKER C 03-25A DG TO 11990' SLM. TEL ARM LOST IN HOLE KB. ELEV = 62' 2117/01 (4" X 2" X 3/8 ") BF. ELEV = ) Ma = xA ngle = 61 @ 7952' / ( 40' H7" X 5-1/2" XO, 10 = 4.892" I Datum MD = 11883' I 2184' 1 - 112" CAM BAL -O SSSV NIP, ID = 4.562" Datum TV D = 8800' SS 17" TBG, 26 #,13- CR -80, 0.0383 bpf, ID = 6.276" 1-1 40' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 113-3/8" CSG, 72 #,L -80, ID = 12.347" H 2538' 1--A 1 3161 3050 38 LR T -2 2 6030 5056 48 LR T -2 3 7167 5755 57 LR T -2 Minimum ID = 3.725" @ 11371' L 4 7870 6120 61 LR T -2 4 -1/2" PARKER SWN NIPPLE 5 8337 6371 49 LR T -2 6 8565 6528 46 LR T -2 5 -1/2" TBG,17 #,13 -CR -80 NSCC, --1 8625' 0.0232 bpf, ID = 4.892" / I 8625' H5-1/2" X 4-1/2' XO, ID = 3.958" 1 17" BAKER TIEBACK SLV , ID = 7.500" I I 8667' 17" X 9 -5/8" BAKER H PKR/LNR HGR, ID = 6.937" H 8674' C 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8791' 1- -A • 7" LNR, 29 #, NT -80S, 0.0371 bpf, ID = 6.184" 1-1 11217' XO TO 7" 29# 13 CR -80 LNR (THREAD CHANGE) H 11280' H4-1/2" PARKER SWS NIP, ID = 3.813" I Illi 11326' I 7" X 4 -1/2" BKR SABL -3 i . 1 PERM PKR, ID = 3.875" `1'i 11355' I- -14 - 1/2" PARKER SWS NIP, ID = 3.813" 1 I 11371' 1 PARKER SWN NIP, ID = 3.725" I 11383' I - 14 - 1/2" WLEG, ID = 3.958" ( I4 -1/2" TBG,12.6 #, 13 -CR -80 NSCT, 0.0152 bpf, ID = 3.958" 1-1 11383' I 11374' H ELMD TT LOGGED 04/26/93 I PERFORATION SUMMARY REF LOG: BHCS ON 03/23/93 ` 11839' HEST TOC (7/28/11) 1 ANGLE AT TOP PERF: 45 @ 11695' i• 11844' I-1 7" POSISET PLUG Note: Refer to Production DB for historiSal perf data � SEE SPF INTERVAL Opn /Sqz DATE .‘ ( 07/28111) 3 -3/8" 4 11695 - 11710 S 06/22/93 3 -3/8" 4 11820 - 11838 S 12/18/93 3 -3/8" 4 11828 - 11838 0 03/08/01 3 -3/8" 6 11870 - 11874 S 06/22/93 3 -3/8" 4 11882 - 11886 S 12/18/93 3-3/8" 6 11886 - 11890 S 06/22/93 4 14.04 3 -3/8" 4 12066 - 12076 S 02/28/01 . 1 1` 1%4 ► 17" LNR, 29 #, 13- CR -80, 0.0371 bpf, ID = 6.184" I--1 12395' ) � b ' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/05/83 ORIGINAL COMPLETION WELL: 03 -25A 03/31/93 RIG SIDETRACK PERMIT No: '1930230 01/17/01 SIS -QAA CONVERTED TO CANVAS API No: 50- 029 - 21021 -01 '02/19/01 SIS -MD FINAL SEC 9, T10N, R15E, 1132.4 FEL 963.04 FNL 04/02/01 CH/KAK CORRECTIONS 07/29/11 TTW/ PJC SET POSISET PLUG (07/28/11) BP Exploration (Alaska) 04/18/11 Scbkeakerger /10.5719 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Site 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 C Well Job # Log Description Date BL Color CD', 01 -16 BCRD -00092 PRODUCTION PROFILE (7 q y Cr) L 03/11/11 1 /y. 1 14 -12 BBKA -00091 PRODUCTION PROFILE / ' , pl 03/05/11 1 t 1 _ Z -02A BJOH -00013 INJECTION PROFILE 0 ]",C (.0— (G. /3 03/14/11 1 / 1 13 -09 BDAD -00038 LDL 1) =C /X61- 03/19/11 1 / 1 L5-36 BJOH -00014 PRODUCTION PROFILE - (0 03/16/11 1 /• i 1 03-25A B-00042 PRODUCTION PROFILE • n 03/18/11 1 / 1 03-255 BG4H GSH -00042 PRODUCTION PROFILE / ' ! / C� " -, 03/18111 1 1 Z -112 8L65-00021 MEM PROD PROFILE 03/01/11 1 1 1 F -35 BG4H -00037 RST 's(- O / 02/23/11 1 Q ( 1 J-17C BAUJ -00061 MCNL ....t)11 fj a D 02/09111 1 a 1 • • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 ,,I)ttl ' 1' ` LUG I • RECEIVED APR 19 2011 kiderNe STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _X (SQZ) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 62 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4262' FNL, 27' FEL, Sec. 10, T10N, R15E, UM (asp's 713242, 5937053) 03-25A At top of productive interval 9. Permit number / approval number 1138' FNL, 669' FEL, Sec. 9, T10N, R15E, UM (asp's 707231, 5940014) 193-023 At effective depth 10. APl number 50-029-21021-01 At total depth 11. Field / Pool 963' FNL, 1132' FEL, Sec. 9, T1 ON, R15E, UM (asp's 706760, 5940175) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12395 feet Plugs (measured) Tagged PBTD @ 11990' MD on 3/6/2001. true vertical 9262 feet Effective depth: measured 11990 feet Junk (measured) true vertical 8945 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 1 16' 20" 2020# Poleset 116' 116' Surface 2476' 13-3/8" 2575 Sx CS III & 400 Sx cs il 2538' 2511' Production 8729' 9-5/8" 500 sx C~ass G & 305 Sx CS ~ 8791' 6812' Liner 3728' 7" 253 cuft Class G 12395' 9262' RECEIVED Perforation depth: measured 11828' - 11838'. ~AR 28 2001 true vertical 8820' - 8827'. Alaska 0il & Gas Cons. C0rnmissio~ T. bing/size, grade, and measured depth) 7", 26#, ~3cR-.o ~bg. 40' M.; 5-,/.", ~7#, ~3c.-~0 ~g ~ .~25' M~; 4-,/2", ,2.6#, ~'tfl~% ,,~,~' ~. Packers & SSSV (type & measured depth) 7" X 4-1/2" BAKER SABL-3 PERMANENT PACKER @ 11326' MD. 5-1/2" CAMCO BAL-O SSSV @ 2184' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1393 11545 8632 - 821 Subsequent to operation 1348 8644 1980 - 317 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations __X Oil ~X Gas __ Suspended __ Service 17. I hereby cer~ that thee foregoing is~t~e and correct to the best of my knowledge. Danielr'e Ohms Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 03-25A DESCRIPTION OF WORK COMPLETED ACID WASH / CEMENT SQUEEZE FOR WSO & REPERFORATING OPERATIONS Date Event Summary 1/13/2001 - 1/15/2001: 1/18/2001: 1/30/2001: 2/01/2001: 2/02/2001: 2/04/2001 - 2/05/2001: 2/07/2001: 2/08/2001: RIH & tagged PBTD @ 12074' ELM corrected. Dummied off GLV's. TIFL passed. MITIA to 2500 psi for 30 min - bled to 2400 psi. A Cement Squeeze for WSO was performed as follows: MIRU CTU. PT'd equip. RIH w/ CT. Killed well w/Filtered 1% KCL Water. Tagged PBTD @ 12074' MD. Pumped a gelled sand slurry containing 3200 lbs of 20/40 mesh Carbolite Sand to place an isolation sand plug over the open perforations listed below: 12066' - 12076' MD (Zone 2) Reference Log: BHCS 3/23/1993. Made a top of sand tag of 12045'. Batch up more sand for another sand dump. Pumped (in 2 stages) an additional gelled sand slurry consisting of 3000 lbs of 20/40 mesh Carbolite Sand. Made a final TOS tag @ 11916'. Pumped Dead Crude down BS. Reciprocated an Acid Wash across the open perforations located below: 11828' - 11838' MD (Zone 4) 11882' - 11888' MD (Zone 3) Pumped: (a) 20 bbls of 12% HCl - 10% Xylene w/additives @ 1.6 bpm, followed by (b) 50 bbls of 2% Filtered KCL Water flush Pumped 47 bbls of 15.7 ppg LARC to squeeze off the perfs listed above. Placed 30 bbls of cement behind pipe @ a max sqz press of 3000 psi. Contaminated cement w/Biozan & jetted contaminated cement f/wellbore. Spotted TEA across perfs interval & POOH w/CT. FP'd well. Trapped 500 psi on well. RD. WOC. RIH & tagged TOC @ 11831' MD. Pulled DGLV's & installed live GLV's. MIRU CTU. PT'd equip. RIH & tagged fill @ 11924'. Attempted FCO. POOH w/CT. RIH & milled cement / sand interface & stringers to 12100'. Pumped Biozan w/KCL slugs. POOH. RD. Well ready for BOL & testing of Zone 2 perfs. 2/11/2001: 2/17/2001: 2/21/2001: 2/23/2001: IWell test: oil: 64 bbls, water = 2075 bwpd, FM Gas = 144 mscfd, & FTP = 270 psi. Ran PDS Mem Production Profile to 12010' MD. Dummied off GLV's. MITIA to 2500 psi - passed. Page 1 03-25A DESCRIPTION OF WORK COMPLETED ACID WASH / CEMENT SQUEEZE FOR WSO & REPERFORATING OPERATIONS Date Event Summary 2/25/2001: 2/26/2001: 2/27/2001: 2/28/2001: 3/01/2001: 3/03/2001: 3/05/2001: 3/06/2001: 3/08/2001: A 2nd Cement Squeeze (for Zone 2) for WSO was performed as follows: MIRU CTU. PT'd equip. RIH w/motor/Venturi Basket & milled f/12058' to 12075' MD. POOH. Made another Venturi Basket run. Tagged 12078' & jetted to hard BTM @ 12110'. POOH w/ Venturi basket. RIH w/cement nozzle. CTU experienced mechanical problems so POOH w/CT. RD CTU#5. Began CTU swap. MIRU CTU#8. PT'd BOPE. RIH & killed well w/2% KCL Water. Tagged BTM @ 12100'. Pumped Crude down BS. Performed injectivity test: 4 bpm @ 610 psi. Jetted 20 bbls of 12% HCI - 10% Xylene across the Zone 2 perfs (12066' - 12076' MD). Pumped 65 bbls of 16.3 ppg LARC. Attained a max squeeze press of 3100 psi for 30 min. Placed 16.5 bbls of cement behind pipe. Contaminated cement w/Biozan & jetted contaminated cement f/wellbore. POOH w/ CT. FP'd well. Trapped 550 psi on well. RD CTU. WOC. RIH &tagged TOC @ 11955'. PT'd sqzto 1200 psi - good test. Installed live GLV's. RIH & milled 3.7" donut pilot hole f/11955' - 12100'. Chased fill out w/Biozan. RIH & tagged PBTD @ 11990' SLM. MIRU ELU. PT'd equip. RIH w/perf guns & shot 10' of reperfs f/: 11828' - 11838' MD (Zone 4) Used 3-3/8" carriers & all shots @ 4 SPF, 1000 psi underbalanced, & random orientation. POOH w/guns - ASF. RD ELU. Placed well BOL @ 1742 hrs. Obtained a representative well test. Future plans call for a Zone 2 reperf. Page 2 RECEIVED MAR 28 2001 '~la~ka 011 & ~a,~ c0~s. Comrnissir~; 03/08/2001. 15:43 FAX 907 564 4264 BP EXPLORATION bp ~ UUJ. BP Exploration (Alaska) Inc. 900 Fast B~nson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 7, 2001 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7n Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Prudhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for March 5 - 12, 2001' Wel_._!l 03-27 03-28 06-18 13-27A 16-05Ai 16-21 NK-22 S-101 S-103 Work Planned REPERFOR~TION REPERFORATION REPERFORATION / HYDRAULIC FRACTURE TREATMENT REPERFORATION CT ACID WASH - GEL CEMENT SQUEEZE GSO CT ADD PERFORATION W/WORK PLATFORM CTD SIDETRACK (NABORS 3S) REPERFORATION ADD PERFORATION ADD PERFORATION INITIAL PERFORATION S-105 INITIAL PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufp¢@bp.com~ -~ /~ Sincerely, /~//~ PT;~nCi;aR:UAsfsistant, BPXA-~'~'~C~ , R~CEtVED Alaska Drilling & Wells kl/lt~ 0 8 2001 Alaska Oil & Gas Cons. Commission Anchorage 09:0SPM BP MILME POIMT GROUP P.2 BP Exploration Endicott Well Operations _s?d_a.y._ _: $1bkline: 4-10 E-line: 1-47 Other: Dummy off GLV~e a~l drift tubir{g to 3.625" Leak detection water flow log Monday 2/26 t. )[ 8iickiih- : 3.2s :line: 2-14 Pull SSSV; drift ~v!_th dumm'-Y w.h.[pstock Water flow log Tuesday $1ickline: Edine: Other: 3-25 Run static'l~ressure survey 3-39 gas-lift survey & FSPL 1-05~.2-12; 3-45! .4-10, S-01 & 5-02 MJ.T.'s w/AOGCC witness Wednesday 2/28 ISlickline: Other: ......... 1-25 Brush, Flush [ pull S$SV,-a~'ii~"tubing Thursday 3/01 ISlickline: 1-25 Caliper s~rvey tubi~~ & liner- .O..t_her: 2-~56 PFO .F.r. kd..a.¥ 3/02 IISlickline: 1-25 Static pleasure ~y. loth?r; ..... . Saturclay 3/04 Il SIbkline: 1-21 lOtb_e..r;_::: ........ 1-25 Calip;eksd~vey of tubing]. I njectivity test ON OR BEFO c:LORlXMFIL'M.DOC 2ERMIT 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 93-023 DATA G~e,ological Materials Inventory T DATA_PLUS 5647 407 DWOP SURVEY SURVEY SURVEY SURVEY SURVEY BHC/AC/GR BHPF CNL/GR CNL/GR COMP COMP DLL/GR/SP JWL/GR/CCL PERF PERF PERF PERF 8550-12376 DLL/AC/CN/GR COMP DATE:04/26/93 03/06-03/31/93 u~1"8800-11174 ANADRILL ~800-12349 SPERRY SUN 8800-12349 SPERRY SUN ,~0.00-12395 GCT SCHLUM. uR/8800-11174 ANADRILL ~/11400-12376 ~ 8796-12385 11250-12319 u~L~l1200-12245 ~LZ 11550-11990 11500-12196 u~11400-12344 TIE-N~ 11100-12248 ~L~1i3300-12248 L~11690-12075 11550-12164 11576-12198 PROD/PRE S/TEMP/G~/11610-11955 SSTVD ~8550-12385 USIT/GR v/L 11200-12280 Date: RUN 03/20/95 DATE_RECVD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 05/06/1993 06/15/1993 06/15/1993 08/31/1993 08/31/1993 06/15/1993 06/15/1993 06/15/1993 05/06/1993 05/06/1993 05/06/1993 05/10/1993 07/30/1993 03/18/1994 05/06/1993 05/10/1993 05/10/1993 07/30/1993 01/21/1994 08/06/1994 01/14/1994 05/06/1993 05/10/1993 Geological Materials Inventory JERMIT DATA T DATA_PLUS Date: 03/20/95 RUN DATE_RECVD Are dry ditch samples required? yes ~o~And received? ye~ Was the well cored? yes ~ Analysis & des~ived? yes no Are well tests required?/lyes. ~, Received? Well is in compliance Initial COMMENTS GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie RECEIVED FEB 6 1995 4Jaska Oil & Gas Cons. C0mmJss[0n Anchorage NO. 9284 Company: 2/27/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive. Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Mylar Disk ID,s. 1-11 PROD PROFILE 021 295 I I ....... D,S. 1-22A PERF RECORD 021 295 I 1 D.S, 4-38 LEAK DETECTION 020995 I 1 ..D.S. 04-40 PERFRECORD 021 095 I 1 D.S. 09-42 PERFRECORD 021 095 I 1 D,S, 9-49 PERF RECORD 020895 1 1 D.S. 11-04A DUAL BURSTTDT-P 0211 95 1 1 . D.S, 11-06 LEAK DETECTION 020995 I 1 D,S':' 11-16ST1' PERF RECORD 020395 I 1 D.S, 14-4 PERF RECORD 020795 I 1 D,S, 14-17 INJEC PROFILE 020795 1 1 D,S;;!. 15-07A** :~ ~ 95069 DUAL BURSTTDT-P 041194 1 D.S, 15-07A 95039 DUAL BURSTTDT-P 122794 1 D.S, 15-40 95022 MWDGR 120294 1 D,S. 15-40 95021 IMWDGR 113094 1 D.S!5'-07A 95068 PDCGR 1 001 94 1 I ;PLE~,~SE NOTE: THESE PRINTS REPLACE THE ONES SE~T 2/22/95: THE WELL NAME (D,S. 11-1'6) WAS INCORRECT ?"PLEASE NOTE: THIS TAPE REPLACES THE ONE SENT 12/21/94, IT WAS NOT DEPTH SHIFTED; THIS ONE IS,/ SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9228 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay 2/3/95 Floppy Well Job if Log Description Date BL RR Sepia RF Sepia Mylar Disk D.S. 5-11 94409 DUAL BURSTTDT-P 120294 1 , 'D.S. 1-22A DSI 011 395 I 1 D.S. 3-3 PROD PROFILE 01 0595 I 1 D.S. 3-8 PROD LOG 010695 1 1 D.S. 3-11 INJEC PROFILE 01 0595 I 1 , , D.S. 3-14 PERFRECORD 01 08951 I I , D.S. 3-22 PROD PROFILE 01 08 95 I 1 D.S. 3-25A PROD PROFILE 01 0995~ I 1 D.S. 3-24 PROD PROFILE 01 0795 I 1 D.S. 3-31 PROD PROFILE 01 11 95~ I 1 D.S. 4-41 LEAK DETECTION 011 095 I 1 D.S. 6-23 PROD PROFILE 0111 95 I 1 D.S. 7-13A PROD LOG 01 0695 I 1 D.S. 9-11 PROD PROFILE & JEWERLY LOG 01 0695 I 1 ,, D.S. 9-42 PROD PROFILE 011 095 I 1 D.S. 11-23A DUAL BURST TDT-P 01 21 95! I 1 D.S. 11-23A CNTG 01 2095 1 1 D.S. 13-3 !REPEATA PATCH SElllNG RECORD 01 0595 I 1 .D.S. 13-33 !INFLAT BRIDGE PLUG RECORD 01 0595 I 1 iD.S. 15-30 LEAK DETECTION 01 0995 I 1 ! D.S. 16-6 PROD PROFILE 01 08 95 I 1 /b.s. 16-15 PROD LOG 010795 I I SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9139 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 12/30/94 Field: Prudhoe Bay Floppy Well Log Description BL RR Sepia RF Sepia Mylar Disk DzS. 2-20 ~' ~ - 0 2- c/, CNTD (5-13-94) I ~ 6~'. 2-23 ST ~' 2--/?-. C3 DUAL BURST TDT-P (2-25-93) [.5~. '-~ ~ 1 ~3-25A ~ ~ - O ~ ~TH (4-23-93) 1 f ,, D.~4-2 ~O- O~.~ CNTD (3-20-93) 1 ~.S, 4-43 ~ ~ ~, ,~ CNTG (~-29-94) 1 O.S. 4-43 ~ / / ' ~ ~ ~ DUAL BURST TDT-P (3-29-94) ~ ~ i'~ ~ ~ ~ .~ 1 ~.s. ~-~4 ~ ~ ~ -OlD ~U~L BU~S~ ~-~ (~-~-~) ~ " O.S. 4-4~ ~ ~ U ,~ ~ ~ Z ~UnL BU~S~ TO~-P (4-~4-~4) ~; q-~ JAN 0 3 l~'f'15 ~ o.s. 4-4~ / I I- ~ I C~T~ (4-~4-~4) ~'qq~ ..~~ ..... ~ ~.S. 4-~Z ~ / - 0~7 :~UnL ~U~ST TOT-P (~-=0-~) '~ ~ ~ 0~ ~ ~as C~ns. ~,r,~s~,,,~ ~ ~.s. ~-=s ~-/1~ OUnL BURST T~T-P (~-~0-~)~/~q _ ~ ' -' ~.s. ~-~4 ~/~ /~ I ~UnL BU~S~ ~OT-~ ¢-=~-~) , ~ D.S. 5-35 ~ / - ~~ CNTD (1-31-93) ~'~~ff I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED JAN 0,~ 1995 :'~,iaska Oil & Gas Cons. CommissJl3rl Anchorage Page 2 /-.. STATE OF ALASKA ._... ALASKA~ -AND GAS CONSERVATION CO 41SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown , Stimulate Plugging ,, Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well 6. DatUm of elevation(DF or KB) Development X 62 RKB feet ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1014' NSL, 29' WEL, Sec. 10, T10N, R15E, UM 3-25A At top of productive interval 9. Permit number/approval number {;!. 93-23 At effective depth .... 10. APl number 50 - 029-21021-01 At total depth 11. Field/Pool 4487' NSL, 1004' WEL, Sec. 9, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12395 feet Plugs(measured) PBTD Tag @ 12198' M D (7/7/94) true vertical 9292 feet Effective depth: measured 12198 feet true vertical 9108 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 2020# Poleset 80' 80' Surface 2502' 13-3/8" 2575 sx CS III & 400 sx CS II 2538' 2538' Production 8763' 9-5/8" 500 sx CIG & 305 sx CS I 8791' 6683' Liner 3729' 7" 253 sx CIG 8666-12395' 6596-9292' Perforation depth: measured 11828-11838'; 11852-11888'; 12066-12076' true vertical 8820-8829'; 8862-8867'; 9005-9013' Tubing (size, grade, and measured depth) 7", 26#, 13 CR-80, NSCC Tbg @ 40' MD; 5-1/2", 17#, 13 CR-80, NSCC Tbg @ 8625' MD; 4-1/2", 12.6#, 13 CR-80 Tbg @ 11383' MD Packers and SSSV (type and measured depth) Baker SABL-3 pkr @ 11326' MD; Camco BaI-O SSSV @ 2184' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 503 1251 3318 -- 293 Subsequent to operation 881 3699 4134 -- 308 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X ,. Gas --. Suspended ...-- Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~;~.~-~~ '~ ~.~-~.~_...~ Title Sr. OAEngineer Date Form 10-404 Re~ 36/15/88 .c;! IRMIT IN 1311Pl IC:ATF: 11.qo/1R ~.c.: K7 .IWP 3-25A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/4/94: RIH & tagged PBTD at 12203' MD. 7/7/94: MIRU & PT equipment. RIH w/perforating gun & tagged PBTD at 12198' MD, then PU & shot 10' of reperforations as follows: Reperforated: 11828 - 11838' MD (Z4) Ref. Log: BHCS 3/23/93. Used a 3-3/8" carrier, & shot 4 spf, at 60/120 degree phasing, at balanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: August 3, 1994 ARCO Cased Hole Finals Karla Zuspan/ATO- 1529 (907) 265-6547 Distribution Transmittal #= 94068 Well Log Date Tool Type Contractor Number (M-D-Y) )~ '-/6 01-03 7-4-94 Leak Det I SCH -~'/' 5;._____~ 03-12 7-2-94 Inj Prof 1 SCH :~__.~ ? ~- 03-19 7-7-94 Prod Prof I SCH ~'~ - ~ 3 03-25A 7-7-94 Perf Record I SCH '7~ - ¢3 04-02 7-3-94 Leak Det 1 SCH ~? ~ *04-07 ST1 7-8-94 Perf Record 1 SCH 7'/-),?-- 05-01 7-9-94 Tubing Cutter 1 SCH '77---~ ~' 05-11 7-9-94 Perf Record 1 SCH '2 ~'-/,'o 06-11 7-2-94 Dual Burst TDT-P I SCH ~ 06-21 7-1-94 ' Pr°d Prof 1 SCH ?__~ ~~? 06-22A, , 7-4-94 Perf Record 1 SCH ~ ~'~r-c)- 07-02 7-4-94 Prod Log 1 SCH ~ 09-31A 7-8-94 G R/Collar 1 SCH ~ ~'-- ~'/' Ii'09-32 7-7-94 Dual Burst TDT-P 1 SCH r ~ ---Z-:'-~-i 15-01 7-2-94 Prod Prof I " SCH ;'~-- ,5-(3 16-02 7-5-94 Inj Pmf 1 SCH ~ 16-10 7-6-94 Inj Pmf 1 SCH I~~________~ 16-24 7-3-94 Perf Record I SCH ~ - c=, c_-; 17-07 7-5-94 Leak Det 1 "t SCH *The correct APl number for 04-07 ST1 is 50-029-20189-00. Number of Records: 19 / KaHa Zuspan Distribution: Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil Pleas y signing and returnin?J~'~,o),py ~'"'t~ns~~ % ARCO Alaska, In¢, Is a Subsidiary of AtlanlJcRIchfleldCompany ARCO Alaska, Inc. Date: Feb 16, 1994 P.O. Box 100360, . .lorage, AK Transmittal #: 94023 99510~ ~ Subject: ARCO Case__~d ~ From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution i Well !L°g DateNumber (M-D-Y) T°°l Type i RUn'scale C°ntract°r ~- 7~._~ ! PW2D1W i01-24-94 Staticpress/Templ 1,5" Sch ctb--i '~-- ~'Z. ~q--~ f 3-32 i 1-25-94 ~1 Bridge Plug ~'.i 1, 5" Sch ~q% ~4-46 ~ 2-6-94 USlT/Cement ~ 1,5" Sch " 4-46 ~- '~ ~ , ~ 9-9 ~ 1-26-94 Leak Detec~ 1, 1"&5" Sch ** 11- ~- ~ 11-17 ~ 2-5-94 Leak Det~ 1, 1"&5" Sch ~ t~ ~ 12-16A ~ 2-2-94 Pe~ R~o~ I 5" Sch ~14-2B ~- ~I~R 15-9A j 2~-94 Pe~ R~o~ 1, 5" Sch ~- ~ ~ 16-29A ~ 1-31-g4 Prod Log j 1, ~"&5" Sch * DSf 1-24ST the corr~t well name is 1-24A ~ ~~. ** DS~ 11-16ST1 the correct API~ is 50-029-21581-00 Number of Records:32 John E. DeGrey ARCO Alaska, Inc. Is a SubMdlary of All~nllcRIchflMdCompm~ ARCO Alaska, Inc. Date: Jan 19, 1994 P.O. Box 100360, Ar,~orage, AK Transmittal #: 94012 Subject: ARCO Cased Hole Finals From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Well Number Log Date (M-D-Y) Tool Type 1-33 01-05-94 CNL _*02~08. 01-09-94 01-04-94 01 -~3~94 01-08-94 CNL Perf Record t,~,~. ~ Prod Prof Run, Scale , 5II 1, 5" c. tu 1, 5" Contractor 02-22 03-10 3-15A , 5II Sch Sch Sch Sch Sch ! 5II ~*'3~-25~ 12-26-93 Pref Record 1,5" Sch 4-30ST 01-07-94 Prod Profile 4-32 12-26-93 Prod Profile 4-32 01-04-94 Leak Detect Dual Burst TDTP CNL Alpha Tubincj~ Bridge Plug Perf Record Leak Detect 01-07-94 6-01 6-02 1, 2"&5" Sch 1, 1"&5" Sch ~ 1, 5" : Sch ~;' 12-27-93 Sch Sch Sch 1, 5" Sch 1, 5" Sch 9-13 01-05-94 9-29 01-03-94 11-01A 12-28-93 11-12 14-01A 14-01A ***.14-4 15-22 15-22 16-09A 17-13 01-06-94 Sch 511 7,5" 2"&5" 1, 1"&5" 01-09-94 01-09-94 Compiet Record Perf Depth Cntl Prod Profile 12-27-93 12-27-93 Perf Record Perf Record Perf Record Patch Set Record 11 511 1 511 , 5II 1,5" ~0-9'~ ~ 01-06-94 q~- ~'~ 12-28-93 ,~ ~- F'~:~01-08-94 * 02-08 The correct max. depth is 9850.0 F & the correct min. ** 3-25A The correct APl# is 50-029-21021-01 *** 14-04 The correct APl# is 50-029-20320-00 Number of Records: 22 ';"JOhn E. DeGrey PBOE Document Control _ Central Files Phillips Chevron ANO-8 Geology BPX Exxon State of Alaska Mobil Distribution: , 5II 1,5" 1,5" Sch Sch Sch Sch Sch Sch Sch depth is 9550.0F Please acknowledge receipt by signing and returning a copy of transmittal. By: .~~~.~ ~"~~, Date: · RECEIVED · JAN211994 Alaska Oil & ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 01-04-94 REFERENCE: ARCO CASED HOLE FINALS ~C~lio ~ 1-03 11-23-93 -1-15 11-20-93 ~2-32 11-27-93 ? q_ ~-~3-16i 11-19-93 ~3-24 11-11-93 - ~-3-25A 11-22-93 ~3-36 11-13-93 ~4-1 lA 11-20-93 ~- 1 lA 11-20-93 4-22 11-17-93 4-30~ 11-13-93 5-06 11-27-93 5-12 11-27-93 5-26 11-27-93 5-31 11-28-93 _~ ~ ~-:~ 6-12A 11-12-93 I 6-18 11-17-93 ~ ~.~'~ 6-22A 11-16-93 9-03 11-20-93 13-28 11-16-93 W~-gl 14-02 11-15-93 9~-63 14-04 11-16-93 ~-f? 14-23 11-16-93 ~1 14-31 11-12-93 ~Z-~c 15-03 ~ 16-07 11-13-93 ~5-~9 16-20 11-13-93 l?~ 17-13 11-20-93 ~-~q I 18-23A 11-17-9~ 18-29A 11-23-93 Perf Record 10~O Flll) ~.D .Run Prod Profile fS~a ~[e~gl~e%l~i~un Inj ~o~le/~,~}~e~!~/~C' R~ ~ Detect/GR/~tl }Y4~ICC R~ ~od ~om~/~r~a ~/~~ Perf Record l/~O ~ {~ ~ R~ SBT/GR/CCL )~i~O-llq~ R~ GR/CCL ~i~ ilc.~ ~t~ R~ CNLr~'~'~ ~T~"~ ~ ~ ~ Perf Record ~i~'~; ~'c. ~i c., c ~ R~ Perf Record '~'3!: ~ q~.~ R~ Perf Record ~,~ t:; -- ~. ~ ~ ~- R~ Perf Record-.~ ~' ~'~ -~::~C R~ Perf Record ~,- ~ ~: .... ~..: ? ~i' R~ Packer Setting Rec R~ Perf Record ~ ;~i ~ ~ i~ C R~ D~I B~st TDT-P/~ R~ TBG Cutter ~ ~00 - 10t 00 R~ Packoff GLM ~ ~ ~,. R~ Perf Record ~~ 106l ~ R~ Perf Re~ord ~0~ ~ ~. R~ USIT~olor,~ ~- 'tau R~ Perf Record q~-qS~ R~ Please sign and return the attached cOpy as receipt of data. Have A Nice Day! John E. DeGrey ATO-1529 5" 5" 5" 5" 5" 5" 5" 5" ~, ~500- qS~O Sch Sch Sch Sch Sch Sch Sch Atlas Atlas Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA # PHILLIPS # ANO8 GEOLOGY # EXXON # MOBIL * The corrected API# for 18-29A is 50-029-22316-01 ,~--.,, STATE OF ALASKA ._ ALASKA: _ AND GAS CONSERVATION C(. ,,IlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 62 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1014' NSL, 29' WEL, Sec. 10, T10N, R15E, UM At top of productive interval 4141' NSL, 669' WEL, Sec. 9, T10N, R15E, UM At effective depth At total depth 4487' NSL, 1004' WEL, Sec. 9, T10N, R15E, UM 3-25A 9. Permit number/approval number 93-23 10. APl number 50 - 029-21021-01 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12395 feet 9292 feet Plugs(measured) PBTD Tag @ 12210' MD (2/4/94) Effective depth: measured 12210 feet true vertical 9117 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 2020# Poleset Surface 2502' 13-3/8" 2575 sx CS III & 400 sx CS II Production 8763' 9-5/8" 500 sx Cl G & 305 sx CS I Liner 3729' 7" 253 sx Cl G Measured depth 80' 2538' 8791' 8666'-12395' True vertical depth 80' 2538' 6683' 6596-9292' ECEIVED Perforation depth: measured 11828-11836'; 11882-11888'; 12066-12076' true vertical 8820-8827'; 8862-8867'; 9005-9013' , .:',.~.; ~_~, & C-,as Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, 13 CR-80, NSCC Tbg @ 8625' MD; 4-1/2", 12.6g, 13 OR-80 Tbg @ 11383' MD Packers and SSSV (type and measured depth) Baker SABL-3 pkr @ 11326' MD; Camco BaI-O SSSV @ 2184' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 1794 23026 Subsequent to operation 763 ~ 5494 4115 3020 Tubing Pressure 1077 256 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil_y,_ Gas Suspended__ Service. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404Ll~ev 06/15/88 · ~ .J ~.~ I0 AIm ,-.~. Ir-it I%AID Date ~'////' ~/~' SUBMIT IN DUPLICATE 3-25A DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF 12/10/93: RIH & tagged bottom fill at 12237' MD. 12/18/93: A CTU Acid Wash & Cement Squeeze for Gas Shutoff were performed as follows: MIRU CTU & PT equipment to 4000 psi. Loaded the wellbore w/Hot Seawater & RIH w/CT to reciprocate a pre-squeeze Acid Wash across the perforations located at: 11820 - 11838' MD (Z4) 11882 - 11886' MD (Z3) Ref. Log: BHCS 3/23/93. Pumped 25 bbls 12% HCl w/10% Xylene, followed by 25 bbls 6% HCl - 0.75% HF w/3% Acetic Acid, followed by 50 bbls 1% NH4Cl Water, followed by 89 bbls Inhibited Seawater down the CT. Pumped 160 bbls Hot Seawater down CT backside to reheat the wellbore, then switched to cement. Pumped 45 bbls of Latex Acid Resistive cement & placed 16 bbls of cement behind pipe at 3000 psi maximum squeeze pressure held for 1 hour. Contaminated cement w/biozan & jetted cement from wellbore down to 12200' MD. POOH w/CT. Rigged down. 12/20/93: RIH & tagged bottom at 12228' MD. 12/26/93: Reperforated: 11882 - 11888' MD (Z3) Ref. Log: BHCS 3/23/93. Added perforations: 12066 - 12076' MD (Z2) Ref. Log: BHCS 3/23/93. 2~4/94: Reperforated: 11828 - 11836' MD (Z4) Ref. Log: BHCS 3/23/93. Returned the well to production w/gaslift & obtained a valid production test. Note: Oil rate decreased by 1031 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 1753 BOPD, resulting in a net oil benefit of 722 BOPD. STATE OF ALASKA ALASKA~-"'I_ AND GAS CONSERVATION C( dlSSION REPORT SUNDRY WELL OPk ATIONS 1. Operations performed: Operation shutdown ..% fim,'.~late Plugging Pull tubing Alter casing tiepair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Perlorate ,X,,,,Other 6. Datum of elevation(DF or KB) 62' RKB feet /~ 4. Location of well at surface 1014' NSL, 29' WEL, Sec. 10, T10N, R15E, UM At top of productive interval 4141' NSL, 669' WELl Sec. 9, T10N, R15E, I. JM At effective depth 5. Type of Well L)evelopment ~X ,, Exploratory Stratigraphic ~ervice At total depth 4487' NSL, 1004' WEL, Sec. 9, T10N, R15E, UM 7. Unit or Property Prudhoe Bay Unit _ 8. Well number 3-25A 9. Permit number/approval number 93-23 10. APl number 50 - 029-21021-01 11. Field/Pool 12. Present well condition summary Total depth: measured true radical 12395 feet Plugs(measured 9292 feet Effective depth: measured 123.56 feet true vertica! 9261 fr~el Junk(measured Prudhoe Bay Oil Pool Casing Length Size Cemertted Measured depth True vertical depth Conductor 80' 20" 2020# Poieset 80' 80' Surface 2502' 13-3/8" 2575 sx CS Ill & 400 sx CS II 2538' 2538' Production 8763' 9-5.,'8" 500 sx CI 'G'& 305 sx CS I 8791' 6683' Liner 3729' 7" 253 sx CI 'G' 8666'--12395' 6596'-9292' Perforation depth: measured 11695-1 't 710' true vertical 8748-8759' T,¢bing. (size, grade, and measured depth) 5-1/2'', ,17#, 13CR-80,. 4-1/2", with 5-1/2" x 4-1/2" xover @ 8625' MD, 4-1/2",12.6fl,13CR~80, w/tail @ 11383' MI-) Packers and SSSV (type and measured depth~ Baker SABL-3 pkr ~ 113~6 MD, Camco BAL-O SSSV ~ 2184' MD 13. Stimulation or cement squeeze summary ~ S E P - 9 ]995 ;Alaska OJj & (]as Cons. 14. Intervals treated(measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation Oi!-Bb! G;as-N1cff Water-Bbl Casing Pressure 0 0 0 870 ¢"/~'~"' 26307 0 - Anchorage Tubing Pressure 0 1770 Status of well classification as: Oil X Gas Suspended__ Service 15. Attachments Copies of Logs and Surveys run ~ Daily Repod of Well Operations x...L_ Date ~/""7/~'.~ StJBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correcl to the best of my knowledge. Signed~~,,--6~/l~/8'~8 5 ~ Title FS-2SeniorEngir~eer ~ILY REPORT OF WELL OPER, ~ONS DS 3-25A Perforating. Operations: ARCO Alaska, Inc, perforated iDS 3-25A at a selected interval in the Sadleroehit Sand of the Prudhoe Bay Unit on 4/26/93. The interval perforated was the t~llo~ving: 11695' - 11710 ' Mil) (Nefercnce Log: AWS- BHCS dated 3/23/93). Completion fluid was in the wellbore during perforating operations. All wireline ~vork was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expec, ted surface pressure. A short summary of the work is given belo~v: Began perforating operations on 4/26/93. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. RIH, opened well to flow and perforated 11695'-117110' iMD at 4 SPF, POOH, and confirmed all shots fired. (re[': AWS-BHCS of 3/23/93). Rigged down and secured well. Alaska Oil & Gas Cons. Cornmissior' Anshorage RDC: 8t26/93 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA 12-20-92 2-25-93 2-27-93 4-19-93 4-9-93 3-19-93 3-23-93 4-18-93 2-23-93 2-26-93 3-7-93 3-13-93 4-6-93 4-15-93 3-7-93 4-1-93 12/6-~s/92 1/23-2/6/93 MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MW]) Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey 12/30-1/15/93 MWD Directional Survey 12-9-91 MWD Directional Survey 1-15-92 MWD Directional Survey 1/92 MWD Directional Survey 2-9-93 MWD Directional Survey 1-16-93 MWD Directional Survey 12-27-92 MWD Directional Survey 1-18-93 MWD Directional Survey 1-17-93 MWD Directional Survey 2-16-93 MWD Directional Survey 2-24-93 MWD Directional Survey 4-28-93 MWD Directional Survey 3-7-93 MWD Directional Survey 3-17-93 MWD Directional Survey 3-30-93 MWD Directional Survey Job#AKEI30010 Job#1209 Job#AKEI30016 Job#AKMW30020 Job#1188 Job#AKEI30009 Job//1192 Job#AKEI30012 Job#1202 Job# 1159 Job# 1175 Job# 1167 Job#AKMM911128 Job#AKMM911231 Job#AKMW30003 Job#AKMM921231 Job# 1168 Job# 1172 Job# 1185-450 Job#1185 Job# 1190 Job# 1195-450 Job#1205 Sperry BHI Ana Ana Sperry Sperry Teleco Sperry Teleco Sperry BHI Ana Ana Ana Teleco Teleco Teleco Sperry Sperry Sperry Ana Sperry Sperry Teleco Teleco Teleco Teleco Teleco Teleco Teleco BHI Please sign and return the attached copy as receipt of data. RECEIVED BY Have A Nice Day! Sonya Wnllnce ATO-1529 CHEVRON # CLINT CHAPMAN # EXXON MOBIL Trans# 93059 # PB WELL FILES # BPX # ST. OF AK. (2 COPIES) # LUCILLE JOHNSTON ********* SCHLUMB~,~R ~******~ ******************************** ************************ ~'AN)' PRUI)HOE BAY l)filI.I.I~ ELL NAM~ ~ 3-25A LOCATt~ 1 PRUDHOE BAY LOCATION 2 AI( MAGHETIC Ii, LIbaTION 30.17 DATE-' I~-HAR-93 WELL NUMBER 0 WELL ~AD LO~ATIDI, h LAT(H/-E) 0.00 AZI~J'I'H ~'Oll RCCARY TABLE TO TAliP,~ IS TIE IH POI~(TIP) : M~.ASUR~I) DEPTH 5~qJE UE~T DEPTH II, ICLINATIDH AZIMLITH I. ATITUDE(N/-S) DEPARTUP£ (E/-W) ~90.0(: 45.52 312.78 25~.00 -~47.(~ DEP(E/-W) 290.02 F'H~£ HO, 2 DS 3-25A )~.~SLRED :KT~9AL Vi~:TICAL Dh¥'TH DE~'TH ft ft ft 8600,00 0,0 6698,00 922i,17 421.2 6984,74 9313,61 ~,4 7048,96 940~.79 93,2 7113.9G 9471,78 ~5.0 7159,02 *~*** MINIMUM, CUR~T~ ~.T~OD TARGET STATION AZIKETH ~T!TLtD£ SECTION !NCLN< ft deg dca ft 45~5.t~ 45,52 4,8,87.34 A~,.2~. 292-40 2750,8~ 4~3,77 45,71 ~2,0~ 2776,03 ~020,54 45.94 2~2.*0 2801,56 5067.24 46,11 ~3,~ 2819,94 DEPARTL~:E Di~'I~C~MEN~, at E/'W ft ft '3947,00 4720,90 '41'~,~? 5Q~,13 -42&~.67 5085,41 -4322.~ 5!5i.ll -4385,64 5197,20 AZI~?.H de.: 3:)3,27 393,0~ DLE de<}/' lOOft 3,47 0,71 0,59 9502.4~ 9597.46 9687.67 9781.79 9875,57 30,7 7160,3~ ~.0 7246,36 ~,2 7310,54 92,1 7375,01 93,8 744O.87 ~89.29 45,85 292.2t 2828.51 5157,~ 46,08 292,26 2654,4i 5223,70 45,70 291.~') 2879,25 5269.46 45,46 ~'2,:5 ?:YO2,B7 5356,17 45,32 292.53 29~,24 2,50 0,22 0,51; 0,2,7 0,32 10061.59 10155.05 10247,15 10341.74 92.3 75,35,47 93,7 7570.78 93.5 7636.25 92.1 7700,67 ~.6 7766.65 5422,10 45,&8 £~[,:1 2953,75 5489,26 45,73 269.46 2977,04 5555.97 45,34 2~?,~; - 2999,01 %21,7~ 45,~9 2~.45 3020,13 5669.50 45,65 2E7,61 [.KU41,11 -4694,~ 55¢6,49 -475Z,~. 5612,24 -4820,55 %77,30 -4~2,&~ 5741,41 ~'1.74 -4947,33 ~7,28 1,2_,."' 0,55 0,74 0,68 10432,~, t0'i_.24,57 10~18.60 10709,94 10604.27 9(:,,8 7~0,40 92,0 7894,73 94,0 7960,12 91.3 8023,64 94,3 8069,12 5754,12 45.18 287.? 3~60,55 5819.81 46,!1 2~6,6~ 5887.26 45.77 266.52 3099,12 5~2,82 46,12 2~7,60 3118,38 6020.&5 45,~ 287.44 313B,82 -5009,02 S670,04 301,43 -5071,93 5933,7B 33:,27 -5136,~', 59991,17 301.10 -5199,43 6062,87 -5264,18 6128,93 30(..~1 0,56 1.14 0,38 0,22 11080,66 11174,0~ 91,7 8152,60. Bt,1 8213,62 95.6 8279,41 93,4 6066,~ 46,44 2e6,85 31~.~ 6151,37 ~,75 28.s.70 3177,01 ~,BO 46,~ 2~6<~ 3197.07 626E,75 ~,~:: 267.59 3217,2i -5327.42 6!93,25 -5389.3'9' 62F~,.11 30('.52 -5455,97 6323.68 -552(,..96 63.~9,95 0,71 0,3J AN,,6.D~R ILL 24011 'NABAR LOOP ANCHORAGE, ALASKA 99507 (907) 349-6575 March 25, 1993 Prudhoe Bay Unit P.O. Box 196612 Anchorage, AK 99519-6612 Attention: Doyon 16 Drilling Engineer I have compiled a summary of Anadrill's performance on DS 3-25 A, Doyon 16. SERVICES PROVIDED Anadrill's DSW Service, comprised of our directional package with Downhole Weight on Bit (DWOB) and Downhole Torque (DTOR), was picked up on 13-MAR-93. It was used to drill cement to the kick off point at 8796' and then to kick off the well and drill to the end of the build/turn section. Two additional bit runs were required to reach a total depth of 11237' on ,0-MAR-9.~. OPERATING STATISTICS Total operating time (over 200 gpm flowrate) was 109.8 hours over three MWD runs with a drilled footage of 2441 feet. There were 3 standby days and 7 operating days for this well. ,IOB PERFORMANCE Calculated formatioi~ strengths (FORS) and dimensionless torque (TD) generated by the DWOB/DTOR supported Mechanical Efficiency Log (MEL) progam indicated we were off of the plug and into formation after sliding 23 feet. At this point DWOB was increased with a corresponding increase in rate of penetration. At 9467' we appeared to be encountering magnetic interference, 180 feet after our first calculated survey. Drilling one more ,joint and then performing a roll test confirmed the presence of interference but due to the subtleness of the interference, we could not defnintively determine its source, so a trip was made at 9499' fora new bit and a new MWD tool and collar. Check shot surveys and roll tests showed no interference with the new tool, indicating a hot spot or ground loop within the original collar or tool as the source of the interference. Tile closest distance between the sidetrack and old well was estimated to be 65'. The closeness of the tool to the casino made it more difficult to diagnose the tool problem. The problem was caused by a power fluctuation which occun'ed when a MWD collar wire was smashed. A PDC bit (M94H) was used to drill the tangent section from 9499' to 10789'. Anadrill's DWOB measurenlents were used rather than surface measurelnents to maintain a constant 6 Klb downhole weight to maximize rate of penetration without damaging the bit. Torque pnd Drag Analysis The follwoing surface torque values were compared to the predicted torque values at tile depths indicated: Depth Predicted Torque Actual Torqum 9350 12.9 12.2 9880 1 3.8 15.5 10500 15.0 16.0 11 1181 16.2 15.0 The above data does show some slight differences between the actual and predicted torques for the well. These differences could be due to slight changes in the bottom hole assembly, variations in the borehole as compared to the planned trajectory or from differences in the predicted and actual downhole torque. The average error for the above comparisons was approximately 8~. Anadrill appreciates the opportunity to provide MWD services on the Prudhoe Bay Sidetrack Drilling ProJect and looks forward to continued participation. Sincerely, Manager Alaska Field Service Manager ANADRILL OF lglIV4L C1)~:'~4'f PRUDHOE BAY ~ILLII~: ~LL NA~ ~ 3-Z~A LDC_Y~TI~ I ~UMOE BAY LOC~TIO~ 2 Al( MAC, HETIC DECLIh~)TIO~ 30,17 ~TE: 19-MqF:-?3 WELL hUmBER WELL HEAD L.rCATIO~: LAT(H/-E) AZI~JTH, ~'0~ ROT~¥ T~LE TO T~ET IS TIE IN POI~I'(TIP): )EE.,tSUF:ED DEPTH TRUE UI~:T DEPTH INCLIh~TtON AZIPEFfH LATITUDE(N/-S) 312,78 -~.6/47,00 JU~ 1 5 1995 .Alaska 0/i & Gas Cons. t:;ommlssio~ Anchorage E~SLRE~ :VT~VAL V~:TICAL D~'TH D~F'TH ft ft ft 8800,00 0.0 9221,17 421,2 6984,74 9313,61 92,4 7048,96 9406,79 93,2 7113,90 9471,78 ES,0 7159.02 SURV~ CALCULATIOn*, TARGET STATION AZIKILTH LATITUD£ SECTION IHC~ N/-S ft deg dca ft 4595,I8 45,52 312,7e 25?0,00 ~87,34 46,25 292.40 2750,89 4953,77 45,71 25'2,02 2776.03 5(,)20.54 45,94 292.~0 2801,56 5067,24 46,11 253.3,,8 2819.94 DEF'ARTL~;:E DISPLACEMENT at £/-W ft ft -3947.00 4720.90 -4179.33 5020,13 -4233,87 5085.41 43~2,E6 5~St,ll -4365,64 5197,20 AZI~JTH de:: 333,27 .q.r) .:.,,3,06 deo/ lOOft 0,00 3,47 0,66.. 0,71 0,59 9502,48 9597,46 968~,.,/ 7781.79 9875,57 39,7 7183.35 95_..0 7246,36 92.2 7310,54 92,1 7375,01 ~3,8 74zK),87 ~89,27 45.88 292.E1 2828.51 5157,54 46,08 252,2~ 2854,4I 5223,70 45,70 2~1-e0 2879,~ ~8~.46 .46 ,_ :5 5356,17 45,32 292-53 ~,24 -4385.98 5218,94 302.82 -4449,18 5286,1! 332,68 -4510,5~ 5351.19 302.55 -4571,57 5415.87 3~2,42 -4633,33 5481,62 302.30 2,60 0,22 0.55 0,37 ~67,89 10061,59 10155,05 10247,15 10341,74 92,3 75,35,47 93,7 7570,78 93.5 7636,25 92,1 7700,67 9~,6 7766,65 5422,10 45,88 29~,11 2~53.75 5489,26 45.73 26?.46 2977,04 5555,97 45,~ 289,~; 29'99,01 5621,7~ 45.89 288.45 3020,13 5669.50 45,65 287,61 24~1,i1 -4694,56 5~6.49 -4757.%~. 5612.24 -4820,55 5677.3(, -4,~2.6~ 5741,41 -4947,[~ .~07,28 1,27 0,55 0,74 0,68. 10432,~. 10524.57 10618,60 10709,94 10804,27 9C.,8 7~..40 92,0 7894,73 94,0 7960,12 91,3 8023,64 94,3 8089,12 5754,12 45,16 287.? 5819,81 46,11 286,6~ 5887,26 45.77 2E6.52 3099,12 5?52,82 46,12 287,60 3118,38 ~20.65 45.95 287-44 3138.82 -5(,O9,02 5870.(~ 301,43 -5071,93 5933.78 -5136.,'4', 5%9,'.17 301.10 -51~.43 6062,87 -5264,!8 6128,93 30(:.81 0,56 1,14 0.38 0.93 0,22 1()895,97 10985,07 11080,66 11174,04 91.7 8!52,60 89,1 8213,82 ~,6 8279,41 ~,4 8343,3? ~386.75 46,44 286.85 3158,33 6151,37 ~.,75 2~.-70 31/7,01 6220,80 46.~ 286~ 3177,07 628,,,J 46,93 287-5~ 3217,2i -5327,42 6i93,2~ 3~,66 -5389.39 6256.11 30C.52 -5455,97 6323,68 3~3,37 -5520,96 6.~9,95 30C,23 0,71 0,36 0,18 0,68 '"~'-*',ERRY-SUN DRZLLTNG SERVTCE, ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING DATE OF SURVEY: 032393 PBU/3-25A ORIGINA ELECTRONIC MULTI-SHOT SURVEY 500292102101 JOB NUMBER' AK-ET-30016 NORTH SLOPE KELLY BUSHING ELEV. = 62.00 COMPUTATION DATE: 3/24/93 OPERATOR: ARCO ALASKA ]:NC FT. MEASD DEPTH TRUE SUB-SEA COURS COURSE DLS TOTAL VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST SECT. 88O0 9063 9156 9249 9342 6690.00 6628,00 45 30 N 47,20 W ,00 2590,00N 3947,00W 4708,23 6875,62 6813,62 45 30 N 70,42 W 6,28 2685.82N 4105.28W 4893.13 6940,81 6878,81 45 30 N 70.62 W ,15 2707,94N 4167.82W 4958.54 7005.82 6943,82 45 47 N 71,62 W .83 2729.46N 4230,74W 5023.99 7071,63 7009.63 44 5 N 72,52 W 1.95 2749,69N 4293.24W 5088.44 9455 9528 9621 9714 9807 7152,09 7090.09 45 5 N 72,52 W ,88 2773,52N 4368,92W 5166,17 7203,21 7141,21 46 0 N 71.52 W 1,57 2789,61N 4418,48W 5217.30 7267,98 7205,98 45 42 N 72.22 W .63 2810,38N 4481.90W 5282,81 7332.94 7270.94 45 42 N 71,22 N ,77 2831.25N 4545,09W 5348,19 7397.60 7335.60 46 12 N 71,82 W .71 2852,44N 4608.49W 5413,90 99OO 9993 10086 10179 1O272 7.461,67 7399,67 46 42 N 71.72 W .54 2873,52N 4672,51W 5480,10 7525,33 7463,33 46 54 N 71,52 W ,27 2894.90N 4736.84W 5546.71 7588,88 7526,88 46 54 N 71,82 W .24 2916,26N 4801.30W 5613.43 7652,19 7590.19 47 17 N 71,52 W .49 2937,68N 4865,97W 5680,36 7715.96 7653,96 46 5 N 71,12 W 1.33 2959,36N 4930.09W 5746.93 10365 10458 1O551 10644 10737 7780,74 7718,74 45 35 N 70.82 W ,59 2981.11N 4993.17W 5812.63 7846,38 7784,38 44 35 N 69,52 W 1,46 3003.45N 5055.13W 5877,64 7913.06 7851,06 43 47 N 68,12 W 1.36 3026.87N 5115.59W 5941.86 7980.24 7918,24 43 42 N 68,02 W .13 3050,89N 5175.24W 6005.67 8048.14 7986,14 42 30 N 68,62 W 1.36 3074,36N 5234.29W 6068.68 111O9 11202 11295 11388 11481 8320,86 8258,86 43 12 N 68.42 W .19 3167.00N 5469.70W 6319.45 8388,65 8326.65 43 12 N 68,52 W .07 3190.37N 5528.92W 6382.56 8456,28 8394,28 43 30 N 68,22 W .39 3213,90N 5588.27W 6445.86 8523,68 8461.68 43 35 N 68,12 W ,13 3237,73N 5647.75W 6509.43 8591.03 8529,03 43 35 N 67,92 W .15 3261.73N 5707.22W 6573,07 11574 11667 11760 11853 11946 8658,55 8596.55 43 17 N 68,22 W ,39 3285.62N 5766,55W 6636.53 8727,32 8665,32 41 17 N 69,72 W 2,41 3308,09N 5824,95W 6698.49 8797,46 8735,46 40 47 N 69,42 W ,58 3329,41N 5882,18W 6758.87 8868,23 8806,23 40 5 N 69.42 W ,75 3350,61N 5938,67W 6818.55 8939,73 8877,73 39 24 N 69.12' W .78 3371.66N 5994.29W 6877.38 12O39 12132 12225 12318 12349 9011.85 8949,85 38 54 N 69,22 W .54 3392,54N 6049.16W 6935.49 9084.58 9022,58 38 12 N 69,02 W ,76 3413,20N 6103.31W 6992,86 9157.66 9095,66 38 12 N 68,42 W ,40 3434,07N 6156.90W 7049,84 9231.14 9169,14 37 24 N 67.92 W .92 3455,26N 6209,82W 7106.38 9255.77 9193,77 37 24 N 67.92 W ,00 3462,34N 6227.26W 7125.07 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. RECEIVED HORIZONTAL DISPLACEMENT = 7125.07 FEET AT NORTH 60 DEG, 55 MIN, WEST AT MD = 12349 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 299,07 DEG. AUG 1 1993 Alaska 0il & Gas Cons. Commlssi011 Anchorage ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAG PRUDHOE BAY DRILLING PBU/3-25A 500292102101 NORTH SLOPE COMPUTATION DATE: 3/24/93 DATE OF SURVEY: 032393 · JOB NUMBER: AK-EI-30016 KELLY BUSHING ELEV. = 62.00 FT. OPERATOR: ARCO ALASKA INC MEASD DEPTH INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 88OO 9800 10800 11800 12349 6690.00 6628.00 2590.00 N 3947.00 W 2110.00 7392.75 7330.75 2850.86 N 4603.69 W 2407.25 8094,58 8032.58 3089,88 N 5273.92 W 2705.42 8827,74 8765.74 3338.59 N 5906.65 W 2972.26 9255,77 9193,77 3462.34 N 6227.26 W 3093.23 297.25 298.17 266.85 120.96 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. '~'""%ERRY-SUN DR'[LLING SERV]'CE, ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/3-25A 500292102101 NORTH SLOPE COMPUTATION DATE: 3/24 /93 DATE OF SURVEY: 032393 JOB NUMBER: AK-El-30016 KELLY BUSHING ELEV. = 62.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST D']'F MD-TVD VERTICAL FERENCE CORRECTION 8800 6690,00 6628.00 2590.00 N 3947.00 W 8902 6762.00 6700.00 2634.83 N 4003.75 W 9043 6862,00 6800,00 2680.97 N 4092,35 W 9186 6962.00 6900,00 2715.10 N 4188.16 W 2110.00 2140.11 30.11 2181.59 41.49 2224.23 42.64 9328 7062.00 7000.00 2746.89 N 4284.34 W 9469 7162,00 7100.00 2776.51 N 4378.41 W 9612 7262.00 7200,00 2808.50 N 4476.06 W 9755 7362.00 7300,00 2840.84 N 4573.29 W 9900 7462,00 7400.00 2873.63 N 4672.84 W 2266,59 42,36 2307.04 40,45 2350.43 43.39 2393.61 43,18 2438,48 44,86 10046 7'562.00 7500.00 2907.29 N 4774.01 10193 7662,00 7600.00 2941.05 N 4876.06 10338 7762.00 7700,00 2974.82 N 4975.09 10479 7862,00 7800,00 3008.84 N 5069.56 10618 7962.00 7900.00 3044,36 N 5159.08 2484.66 46.18 2531.47 46,81 2576,21 44.74 2617.93 41.72 2656,78 38.85 10755 8062.00 8000.00 3078.99 N 5246.12 10891 8162,00 8100.00 3112,40 N 5331.44 11028 8262.00 8200,00 3146.67 N 5418.30 11165 8362.00 8300,00 3181,20 N 5505.63 11302 8462,00 8400,00 3215,91 N 5593.31 2693.80 37.03 2729,44 35.63 2766.26 36.82 2803.44 37.18 2840.89 37,45 11440 8562.00 8500.00 3251.34 N 5681.60 W 2878,91 38.02 11578 8662.00 8600.00 3286.82 N 5769.57 W 2916,75 37,83 11713 8762,00 8700,00 3318.64 N 5853.48 W 2951,13 34.38 11844 8862,00 8800.00 3348,77 N 5933,76 W 2982.86 31,74 11974 8962.00 8900,00 3378,18 N 6011.38 W 3012.82 29,96 12103 9062.00 9000.00 3406.84 N 6086.72 W 3041,27 28.45 12230 9162.00 9100.00 3435.32 N 6160.08 W 3068.52 27,25 12349 9255,77 9193,77 3462.34 N 6227.26 W 3093,23 24.71 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ARCO Alaska. Inc. P.O.Box 100360 Anchorage. Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 1-28 ...... 6-18-93 3-25A ~?'~3 6-17-93 3-31 ~ V-~z 6-16-93 3-32 ~ ~/~I¢ 7 6-15-93 3-33 ~ ¥~ ~wo 6-16-93 4-8 ?i~ro 6-11-93 5-14 ??-~ 6-12-93 6-22A ~ ~.r~6-6-93 6-22A ~ 16-10-93 7-25 ~- Y ~. 6-6-93 9-44 f ~ ~ ~ z~6.6.93 11-18 f/,-I~z6-7-93 14-6 ~- ~o~6-8-93 14-8 ?~-/,7 6-10-93 14-13 t~']d 16-13-93 14-15tF~ 6-8-93 16-4A tz-I¢~ 6-9-93 16-17 ~' zz~6-14-93 16-31 ~ ~-~ { 6-7-93 17-4 ~ ~ ~ 6-14-93 AGI-5 5~- ~ ~-6-13-93 AGI-6 ~-d~ 6-14-93 AGI-7 _6-8-93 AGI-7 ~ ~-t6-15-93 AGI-7 6-17-93 Prod Profile Completion Record Plug Setting Record Plug Setting Record Plug Setting Record Perf Record TBG Cutter Record Leak Detect Leak Detect Perf Record Perf Record Production Log PITS/Leak Detect Leak Detect Inj Profile Completion 'Record Prod Profile Perf Record Production Log Completion Record Completion Record Completion Record Perf Record R~_m 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch R-n 1, 5" Sch Rim 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Run I 2" Sch R~m 1, 5" Sch Run 1, 5" Sch R!!n 1, 5" Sch Run 1, 5" Sch Rim 1, 5" Sch R~!n 1, 2"&5" Sch Run 1, 5" Sch R~_m 1, 5" Sch Run 1, 1"&5" Sch R~m 1, 2"&5" Sch R~m 1, 5" Sch Run 1, 5" Sch R~m 1, 5" Sch Rim 1, 5" Sch Run 1, 5" Sch R~m 1, 5" Sch Rim 1, 5" Sch AGI-8 ~ ~33/6-9-93 GR/CCL R~_m 1, 5" Sch AGI-9~ ~ l~g 6-9-93 ~~ R~m 1, 5" Sch AGI-9i -~ ~ 6-17-93 Pe~ Record R~ 1, 5" Sch ~ease si~ ~d. re t~~~che~~ R Sony, W~,c, APPROVED-~e e_ ~, AT0-1529 ~~ 93073 _ ~ ~ ~ ' ~ ~ ~ ~ ~ON ~. ~ STA~ OF ~~ ~ MOB~ '~/~. * ~e ~~t ~ ~ ~32 ~ ~21141~. = ~e c~ct ~H ~e for ~ l~ ~ ~2~ ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS * 1.1B~ 1~6.20_93 1-16 7 · ~6-25-93 1-22 tv ~? 6-29-93 1-30 i~' ~ ~ 6-29-93 3-25A ~~ 6-27-93 3-31 ~ ~~-23-93 3-33 ~-~/~ 6-29-93 3-36 ~'l~ 6-28-93 4-37 ~/~7 6-20-93 4-40 ~ !~ 1~6-20-93 5-3A ~3~f 6-18-93 5-26 ~q~ ~ 6-25-93 6-4 ?~- ~z~6-26-93 6-13 ~0-3o 6-25-93 9-49 ~ ~-~ 6-22-93 9-50 ~-~ 6-26-93 12-26e~ 6-22-93 13-17 ~~ 6-27-93 13-14 ?~-~ 6-28-93 13-20 ~ -~? 6-19-93 16-12 ~ 6-21-93 17-20 ~-~6-26-93 ~*~AGI-6 ~ ~-~? 4-25-93 AGI-8 ~-~6-19-93' *** AGI-10 41 ~$~ 6-18-93 *** AGI- 10-~6' 18-93 Prod Profile Run 1, 5" Sch Perf Record R~_~_n 1, 5" Sch Production Log R.n 1, 5" Sch Leak Detect Run 1, 5" Sch Perf Record R.n 1, 5" Sch Leak Detect Run 1, 2"&5" Sch Bridge Plug Setting R-n 1, 5" Sch Completion Record Run 1, 5" 8ch Perf Record R~_~_n 1, 5" Sch Dual Burst TDTP (Borax) R~n 1, 5" Sch Completion Record R-n 1, 5" Sch SBT/GR/CCL R~_~_n 1, 5" Atlas TDTP (Borax) Run 1, 5" Sch Production Log Run 1, 5" $ch Perf Record Run 1, 5" Sch Production Log Run 1, 1"&5" ~ch ~Production Log Run 1, 2"&5" Sch CNL Run 1, 5" Sch Leak Detect Run 1, 2" Sch Leak Detect R~_m 1, 2" Sch Plug Depth Record R~_m 1, 5" Sch Prod Profile Run 1, 1"&5" Sch Production Log Rim 1, 5" Sch .~ousticCBT · Rim 1, 5" Atlas Perf Record Run 1, 5" Sch CuR/CCL Rim 1, 5" Sch Perf Record Run 1, 5" Sch Please sign and return the attached .c~opy,_ as receipt of data. Have l Nice Day~/ · / /,/ Sonya Wallace APPROVED_ ATO- 1529 Trans# 03074 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA The correct name for this log is 1-LB. t ECEIVED # ~,~.LZ~ 'JUL. ~ 0 199~ # CLINT CHAPMAN ## EXXONMoBIL Alaska 011 & ~as Cons. Commission Anchorage This is a revised log, please discard previous copy received. The correct APl# for AGI-10 is 50-029-22353-00. STATE OF ALASKA ALASKA UlL AND GAS CONSERVATION CL,,,,~MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classilication of Service Well OIL []~ GAS I-I SUSPENDED !-1 ABANDONED 1"1 SERVICE D 12. Name of Operator 7.9;.e2rr~it Number i ARCO Alaska, inc. - ~'~'~ 3. Address 8. APl Numbe P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21021-01 4. Location of well al surface 9. Unit or Lease Name Well Number At Top Producing Interval 4141' NSL, 669' WEL, SEC. 9, TION, R15E, UM At TOtal Depth } i ~~~ Prodhoo Bag ?iold/Prudhoo Bay Pool 4487'NSL, lo04'WEL, SEC. 9, TION, R15E, UM ~,.:T,:':_~.,. 5. Elevation in leet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE =54.93' ! ADL 28328 12. Date Spudded 13, Da~e T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, il offshore 116. No. ol Completions 3/15,/93 3/22/93 4/'26/93~ N/A feet MSL I One 17. Tolal DePth (MD+TVD) 18. Plug Back Depth (MD+TVD; 19. Directional Survey J20. Depth where SSSV set ~21. Thickness of Permafrost 12395' MD/9292' TVD 12356' MD/ ~s [] N3 []! 2184' feet MD ! 1900' (Approx.) !22. Type Electric or Other Logs Run CAI../DLL/CN/GR/MRI 23.' CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BoTroM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.51/ H-40 36' 116' 30" 20201/Poleset 13-3/8" 72tt L-80 36' 2538' 17-1/2" 2575 SX CS !!!/400 SX CS II 9-5/8" 4711 L-80 33' 8796' 12-1/4" 500 SX "G"/305 SX CS I 7" 291t NT80S/13CR8 8667' 12395' 8-1/2" 253 CU fl class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter3-3/8" 4 spf 5-1/2"x 4-1/2" 11383' 11326' MD TVD '11695'-11710' 8748'-8759' 26. ACID, FRACTURE, CEMENT SQUi=t=71=. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 27. PRODUCTION TEST Date First Production IMelhod ol Operation (Flowing, gas Iii't, etc.) 5/2/93 I Gas Lift Date of Test Hours Tested PRODI.~TION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD. I Flow Tubing iCasing Pressure D, AL~TED =1~ iOIL-BBL GAS-MCF WATER-BBL DIL 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. .JUN 1 5 19°~ Anch0rag0 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate I 29; ' 30. GEOLOGIC MARKERS~ {MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time ol each phase. Sag River 11480' 8590' Shublik 11528' 8624' Top Sadlerochit 11622' 8694' RECEIVED A,/a$~'c~ .0jJ .& Gas Co~]$..C0mmJssi0r~ A~ch0ra.q0 31. LIST OF ATTACHMENTS ' 32. I hereby certify that the foregoing is true and Correct to the best of my knowledge Signed (~ ~ ~'~ YY~, ~j k ~,t le Drillina Enoineer Supervisor Date ~//'/7///7/'~ (/ ' q/ - _ ,,, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is cOmpleted for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: if no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: 3-25A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 03/06/93 12:01 SPUD: 03/14/93 05:30 RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 03/06/93 (1) TD: 0'( 0) 03/07/93 (2) TD: 0 PB:11780 03/08/93 (3) TD: 0 PB:l1780 03/09/93 (4) TD: 0 PB:l1780 03/10/93 (5) TD: 0 PB:l1780 CIRC OUT FREEZE PROT FLUID MW: 0.0 VIS: 0 MOVE RIG F/ WELL 3-15A TO 3-25A, TAKE ON SEAWATER, SPOT TANKS, R/U LUBRICATOR & PULL BPV, R/D LUB. CIRC OUT FREEZE PROTECTION FLUID POH W/ATLAS E-LINE MW: 9.8 KCl CIRC OUT FREEZE PROT. FLUID F/WELL, SET BPV, N/D TREE, N/U BOPE, M/U LNDG JT, TEST BOPE, RIG UP LUBRICATOR, PULLING TOOL WON'T LATCH INTO BPV, R/D LUB. M/U PULLING TOOL ON DRY ROD, WELL STABLE, PULL BPV, PULL ON TBG, MOVE 15' THEN APPEARS STUCK, TBG NOT CUT, CBU, R/U ATLAS, RIH TO 10850' W/JET CUTTER, JET CUTTER STUCK IN GLM @ 10808', FIRE CUTTER TO GET FREE, POH, RIH W/NEW CUTTER, RIH TO 10772', LOCATE CUTTER TO FIRE, NO MOVEMENT IN TBG, POH POH, L/D 5-1/2" TBG MW: 9.8 KCl W/L TOOL STUCK IN BVLN @ 2244', PULL OUT OF ROPE SOCKET, PULL E-LINE, R/U TO P/U 2-7/8" DP, & TRI-STATE TOOLS, CHG TOP RAMS, RIH W/OVERSHOT, WORK DOWN OVER FISH F/2200' TO 2316', POH W/ DP[, RECOVERED ATLAS TOOL STRING, RIH W/TBG CUTTER, MAKE CUT @ 2255', POH, CHG RAMS, M/U LNDG JT, PULL TBG FREE, R/U TO PULL TBG, L/D TBG HGR, L/D 5-1/2" TBG & CONTROL LINE R/U ATLAS TO CUT TBG MW: 9.8 KCl POH, L/D TBG & CONTROL LINE, R/D OTIS, SET WEAR RING, M/U O/S, RIH W/DP, LATCH ONTO TO FISH @ 2260', JAR ON TBG - NO MOVEMENT, POH W/OVERSHOT, RIH W/JET CUTTER, POH, R/D ATLAS, M/U OVERSHOT - RIH, LATCH ONTO FISH @ 2934', NO MOVEMENT, MAKE BLIND BACKOFF ON TBG, NO WT INCREASE, POH, RECOVERED 1 JT TBG, R/U ATLAS TO RIH & CUT TBG @ 9000' ATTEMPTING TO SPEAR INTO FISH MW: 9.8 KCl RIH W/TBG JET CUTTER, CUT TBG @ 9000', POH, M/U SPEAR, RIH, SPEAR INTO FISH @ 2990', PULL TBG FREE, POH, RECOVERED TBG, RELEASE SPEAR, L/D FISHING TOOLS, R/U TBG TONGS, POH, L/D TBG, M/U TRI-STATE SPEAR ASSEMB., RIH W/SPEAR, P/U DP, SLIP & CUT DRLG LINE, RIH, KELLY UP, CIRC & WASH DOWN TO 8999', TAG UP ON FILL IN HOLE, CBU, CMT FINES IN RETURNS, GAS @ SURFACE, SHUT WELL IN, CIRC TILL WELL STABLE, CIRC & WASH DOWN THRU FILL, ATTEMPTING TO SPEAR INTO TOP OF FISH @ 9013' RECEIVED 5 t995 Cons. Oommissiot~ Anchorag~ WELL : 3-25A OPERATION: RIG : DOYON 16 PAGE: 2 03/11/93 (6) TD: 0 PB:l1780 03/12/93 ( 7) TD: 0 PB: 8992 03/13/93 ( 8) TD: 0 PB: 8992 03/14/93 (9) TD: 0 PB: 8992 03/15/93 (10) TD: 9280' (9280) 03/16/93 (11) TD: 9645'( 365) 03/17/93 (12) TD:10420' ( 775) DISPLACE WELL TO MILLING FLUID MW: 9.6 KC1 CBU, POH W/NO FISH, SET SCREWS ON GRAPPLE SHEARED OFF, REBUILD ASSEMB. RIH W/BHA #4, RIH & TAG TOP OF 5-1/2" TBG @ 8996', KELLY UP, SPEAR FISH, JAR FISH, NO MOVEMENT OBSERVED, ROTATE OFF FISH, RELEASE SPEAR, POH, L/D TRI-STATE TOOLS, M/U BIDGE PLUG & RIH W/SETTING TOOL, SET @ 8992', TOP OF FISH @ 8995', DISPLACE WELLBORE TO MILLING FLUID MILLING @ 8825' MW: 9.8 KCl POH, L/D DP, P/U MILLMASTER, RIH TO 2542', TEST 9-5/8" CSG, RIH TO 8791', COMPLETE INITIAL CUT IN 9-5/8" CSG @ 8791' MILL F8791'-8817', CIRC HI-LO VIS SWEEP, MILL F/8817'-88~5' SQUEEZE KICKOFF PLUG MW: 9.8 KC1 CUT WINDOW F/8825'-8828', POH FOR 25 STD SHORT TRIP, PULLED TIGHT @ 7882', KELLY UP & CIRC, CONTINUE POH TO 6494', CBU, RIH TO BTM STUB @ 8828', CUT SECTION F/8828'-8841', CBU, POH, L/D MILLMASTER, RIH W/MULE SHOE, TAG FILL @ 8851', WAH TO 8941', POH 1 STD, REV CIRC OPEN HOLE, RIH TO 8941', PUMP 225 SX (10 BBLS) CMT, POH TO 7546', PERFORM HESITATION SQUEEZE, NOTE: EFC HAS BEEN RAISED DUE TO TUBING BEING CMTD IN GROUND PRIOR TO RIG MOVE ON. KO CMT PLU @ 8796' MW: 9.8 KC1 COMPLETE SQUEEZE, EST CMT TOP @ 8505', POH 18 STDS, PULL BOWL PROT. INSTALL TEST PLUG, C/O FLOW LINE & JET STACK, TEST BOPE, INSTALL BOWL PROT. RIH W/BHA #2, BREAK CIRC EVERY 1000', KELLY UP & WASH F/8340'-8537', DRLG CMT F.8537'-8796'-HARD CMT @ 8615', SHORT TRIP -10 STDS MW: 9.6 VIS: 63 BEGIN KO @ 8796'. CIRC WELL W/HI-LO VIS SWEEP, TRIP BACK TO 9-5/8" SHOE @ KICKOFF PT @ 8820· DRLG 8-1/2" HOLE MW: 9.7 VIS: 61 DRILL F/9280'-9499', OBSERVE DIRECTIONAL AZIMUTH ANOMOLIE, PERFORM DWD ROLL TEST, MAGNETIC HOT SPOT HAS DEVELOPED IN DWD COLLAR, PUMP HI-LO VIS SWEEP, DROP SINGLE SHOT, MIX & PUMP DRY JOB, POH F/DWD, CHG OUT DWD & BIT, RIH & FUNCTION TEST DWD-TEST PASSED, RIH W/BHA #3, BREAK CIRC EVERY 3000', P/U KELLY & PERFORM CHECK SHOT SURVEYS, DRIL F/9499' TO 9645' DRLG 8-1/2" HOLE MW: .9.6 VIS: 55 DRILL F/9645'-10028', CIRC HI-LO VIS SWEEP, POH F/14 STD SHT TRIP TO SHOE, HOLE TIGHT @ 9100' & 8975' RIH TO 9985' f · REAM F/9985'-10028', DRLG F/10028'-10420' ~ask~ Oil a Ga,?, ~ons. Gomm~SSi~n Anchora.qe WELL : 3-25A OPERATION: RIG : DOYON 16 PAGE: 3 03/18/93 (13) TD:10787' ( 367) 03/19/93 (14) TD:ll080' ( 293) 03/20/93 (15) TD:11237' ( 157) 03/21/93 (16) TD:ll600' ( 363) 03/22/93 (17) TD:12231' ( 631) POOH. MW: 9.6 VIS: 60 DRLG F/ 10427'-10676'. CBU. SHORT TRIP TO 10000' DRLG F/ 10676'-10787'. CBU. POOH. DRILLING 8-1/2" HOLE MW: 9.8 VIS: 66 CHG OUT BHA, ORIENT MWD TOOL & MOTOR, RIH W/HWDP, TEST MWD, RIH, FILL PIPE EVERY 3000', SLIP & CUT DRLG LINE, RIH TO 10757';, KELLY UP, WASH & REAM TO 10787', DRILL 8-1/2" HOEL F/10787'-11080' RIH W/NEW BHA MW: 9.8 VIS: 57 DRILL 8-1/2" OPEN HOLE F/11089'-11196', PUMP PROBLEM, POH INTO CSG @ 8791', REPAIR MUD PUMP, (CRACK IN POT), RIH, DRILL F/11196'-11237', PUMP PROBLEM, PUMP DRY JOB, POH FOR BIT & BHA CHG, REPAIR MUD PUMP ON TRIP, L/D MUD MOTOR & MWD, RIH DRILL 8-1/2" OPEN HOLE MW: 9.8 VIS: 55 SERVICE RIG, RIH, KELLY UP, TIGHT SPOT @ 11218', WASH & REAM TO BTM F/11218'-11232', REAM TO BTM (5'FILL) @ 11237', DRILL 8-1/2" OPEN HOLE SECTION W/LOCKED UP BHA F/11237' TO 11600', DRLG SADLEROCHIT @ REPORT TIME DRILL 8-1/2" OPEN HOLE MW: 9.8 VIS: 48 DRILL 8-1/2" OPEN HOLE F/11600'-12231' 03/23/93 (18) TD:12395' ( 164) 03/24/93 (19) TD:12395' ( 0) 03/25/93 (20) TD: 12395' ( 0) WASH & REAM THRU TIGHT SPOT MW: 9.8 VIS: 47 DRILL 8-1/2" OPEN HOLE F/12231' TO 12395', CBU, SHORT TRIP 15 STDS DP, CBU, POH FOR LOGS, POH INTO TIGHT SPOT @ 11613', WORK PIPE, KELLY UP, CIRC & JAR PIPE @ TIGHT SPOT, WORK THRU, L/D SINGLE, WASH & REAM THRU TIGHT SECTION CONDITION MUD MW: 9.9 VIS: 46 REAM TIGHT HOLE @ 11318', POH, RU ATLAS, RAN ACOUSTIC/CAL/DLL/CN/GR F/12390' TO SHOE, PU STEEL BHA, RIH, HOLE TIGHT @ 10775',11450' & 12395', APPEAR TO BE PUSHING FILL, NO DRAG ON PICKING UP, PUMP HI VIS SWEEP, CIRC & CONDITION MUD LOGGING W/MRI TOOL MW: 9.9 VIS: 57 CIRC & CONDITION MUD, FLUID LOSS ON BTMS UP WAS OVER 12CC. DRAG IN HOLE DROPPED ABOUT 60K WHILE CONDITIONING, POH, HAD TIGHT SPOT @ 11600' WIPED THRU TIGHT SPOT & THE HOLE FREED UP, RIH W/MRI LOGGING TOOL, MAGNETS IN TOOL STUCK TO CSG @ 8100', POH, P/U EXTRA WEIGHT BARS, RIH W/MRI TOOL, LOGGING @ REPORT TIME JUN I 5 199,5 ..A.~aska Oil & Gas Cons. Cornrnission Anchorage WELL : 3-25A OPERATION: RIG : DOYON 16 PAGE: 4 03/26/93 (21) TD:12395' ( 0) 03/27/93 (22) TD:12395 PB:12356 03/28/93 (23) TD:12395 PB:12356 03/29/93 (24) TD:12395 PB:12356 03/30/93 (25) TD:12395 PB:12356 03/31/93 (26) TD:12395 PB:12356 REAM TO BOTTOM MW: 9.9 VIS: 62 RUN MRI LOG, POH & L/D ATLAS, PULL WEAR BUSHING, TEST BOPE, HCR VALVE FAILED TEST, CHG OUT KILL LINE HCR VALVE TO 11560'-11620', L/D DP, REAM 11549'-11904'' HIT LEDGE @ 11904', TAKING 35K TO REAM, CALIPER LOG SHOWS 7-3/4" TO 8-1/2" HOLE IN THIS INTERVAL. NOTE: COSTS FOR THE NUMAR MRI TOOL WILL BE CALCULATED AT THE END OF THE OPERATION AND DEDUCTED FROM THE FIELD COST FOR THE WELL. RIH W/6" BHA MW: 9.8 KC1 REAM TO BOTTOM , NO PROBLEMS AFTER LEDGE @ 11904', PUMP SWEEP, CBU, MAKE 15 STD SHORT TRIP, HAD SOME DRAG, POH, L/D BHA, RU TORQUE TURN, RAN 30 JTS 7" 13CR80 & 63 JTS NT80 CSG, PU BAKER LINER HANGER W/TYPE H PKR & 6' PBR, RIH W/ LINER ON DP NOTE: ALL COSTS TODAY (32471) CHARGED TO NUMAR LOGGING, NOT TO WELL AFE, THE FULL COST OF $122061 WILL BE DEDUCTED FROM COST RIH W/6" BHA MW: 9.8 KCl RIH W/7" LINER, PUMPED 45 BBLS CMT, SET LINER HGR & LINER TOP PKR, POH, L/D 34 STD DP, PU 6" BIT & SCRAPER, RIH & PU BHA & 3-1/2" DP NOTE: THE REMAINING NUMAR-CHARGES HAVE BEEN DEDUCTED FROM TODAYS DAILY COST L/D DP MW: 9.8 KCl P/U STORM PKR, SET BELOW WELLHEAD, ND BOP STACK, CHG OUT TBG HEAD, CH OUT REQUIRED DUE TO LACK OF NEW TBGHEAD ADAPTOR, TESTED NEW HEAD TO 5000 PSI, NU BOP, TESTED FLANGE, PULLED STORM PKR, RIH TO LNR TOP, DRLD OUT CMT, CONTINE RIH TO 11923', DRLD 6" CMT BRIDGE, CONTINUE IN HOLE, DRLD CMT 12273'-12316', TEST CSG TO 3500 PSI FOR 30 MINS, DISPLACE WELL W/SEAWATER, POH & LD DP RUN TBG MW: 9.8 KCl POH, STOOD BACK 10 STDS, L/D 3-1/2" BHA, PULL WEAR RING, CUT/SLIP DRLG LINE, RU TORQUE TURN, RUN 4-1/2" 13CR80 TBG & 5-1/2" 13CR80 TBG, RUN 7" BAKER SABL-3 PACKER & GLMS, PICKING UP SVLN @ REPORT TIME RELEASED RIG 24:00 3/30 MW: 9.8 KCl M/U CONTROL LINE TO SVLN, TEST TO 5000 PSI, RIH W/5-1/2" TBG, SET PKR, RIG DOWN OTIS & TORQUE TURN, N/D BOPE, N/U TREE, SECURE WELL, DISPLACE ANNULUS W/140 BBLS DIESEL FOR FREEZE PROTECTION, RELEASE RIG @ 24:00 3/30/93 '. SIGNATURE: (drilling superintendent) DATE: JUN Oil & Gas Cons. CommissioD ;Anchorage SUB- SURFACE DIRECTIONAL r~ UIDANCE ~10NTINUOUS ~ OOL Company Well Name Field/Location SURVE Date,,. I ~/11~, , ARCO ALASKA, INC. A~aska OJJ & Gas Cons. Commissiov~ Anchorace ii i D.S. 3-25A (1014' FSL, 29' FEL, SEC 10, TION, R15E) PRUDHOE BAY, NORTH SLOPE, ALASKA Job Reference No. 93193 LoQcled BV: _ SARBER Date 23-APR-93 Computed By: SINES II . SCHLUIVlBEROER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO DS3-25A PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE' APR-23-93 ENGINEER. SARBER METHODS OF COMPUTATION TOOL LOCATION: MINIMUM CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 68 DEG 0 MIN WEST COMPUTATION DATE' 29-APR-93 PAGE ARCO DS3-25A PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY- APR-23-93 KELLY BUSHING ELEVATION- 54.93 FT ENGINEER- 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 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0 O0 100 O0 2OO O0 300 O0 400 O0 5OO O0 6OO O0 700 O0 800.00 900.00 0 O0 100 02 200 02 300 02 400 O1 500 O1 600 O1 700 O1 800 O1 900 O1 -54 93 45 09 145 09 245 O9 345 08 445 08 545 08 645 O8 745 08 845 08 0 0 N 0 0 E 0 12 N 12 3 W 0 13 S 86 38 W 0 11 S 12 15 W 0 9 S 28 43 E 0 5 S 88 50 W 0 16 S 78 28 W 0 14 S 0 20 W 0 2O S 17 10 E 0 25 S I 33 W 0 O0 0 O5 0 37 0 52 0 34 0 27 0 58 '0 76 0 48 0 11 0 O0 0 22 0 28 0 27 0 19 0 18 0 23 0 29 0 23 0 51 0 O0 N 0 14 N 0 31 N 0 09 N 0 19 S 0 29 S 0305 0.59 S 1.09 S 1.69 S 0 O0 E 0 O0 E 0 27 W 0 52 W 045W 0 41 W 0 75W 1 06 W 0 96 W 0 81 W 0.00 N 0 0 E 0.14 N 0 50 E 0.41 N 40 56 W 0.53 N 8O I W 0.48 S 67 7 W 0.50 S 54 32 W 0.81 S 67 52 W 1.21 S 60 42 W 1.45 S 41 13 W 1.88 S 25 26 W 1000 O0 1000 01 1100 1200 1300 1400 1500 1600 1700 1800 1900 945 08 O0 1100 O0 1200 O0 1300 O0 1400 O0 1499 O0 1599 O0 1699 O0 1799 O0 1898 O0 1045 07 O0 1145 07 O0 1245 07 O0 1345 07 96 1445 03 83 1544 90 65 164.4 72 41 1744 48 87 1843 94 0 33 S 4 18 W 0 27 S 7 22 E 0 5 S 66 28 E 0 5 S 6O 56 W 0 43 N 73 35 W 2 18 N 66 38 W 3 21 N 65 55 W 3 32 N 62 48 W 4 50 N 77 27 W 6 37 N 77 9 W -0 15 -0 55 -0 87 -0 88 -0 48 2 28 7 23 13 30 20 16 30 22 0 2O 0 19 0 36 0 29 0 41 1 42 1 23 0 66 1 39 2 O0 2.56 S 3.49 S 3.88 S 3.87 S 3.85 S 2.81 S 0.85 S 1.79 N 4.19 N 6.05 N 0.87 W 0.81W 0.63 W 3 0.61W 3 1.04 W 3 3.60 W 4 8.14 W 8 13.62 W 13 20.05 W 20 30.15 W 30 2.70 S 18 45 W 3 58 S 13 7 W 93 S 9 15 W 92 S 8 58 W gg S 15 3 W 57 S 51 59 W lg S 84 4 W 74 N 82 30 W 49 N 78 11W 75 N 78 39 W 2000 O0 1997 99 1943 06 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2834.20 2779 8 18 O0 2096 O0 2194 O0 2291 O0 2385 O0 2476 O0 2567 O0 2657 O0 2747 72 2041 69 2139 08 2236 11 2330 87 2421 58 2512 85 2602 04 2692 79 9 53 76 13 18 15 17 44 18 21 47 94 24 32 65 25 13 92 25 46 11 28 23 27 30 10 N 62 28 W 43.44 N 54 3 W 59.02 N 49 21W 78.10 N 48 53 W 103.13 N 48 24 W 135.17 N 46 53 W 172.40 N 46 16 W 211.55 N 50 0 W 251.90 N 55 51W 295.52 N 62 46 W 343.94 2 09 2 05 2 46 3 17 3 77 3 92 2 90 2.02 1.89 2.37 10.94 N 19.39 N 31.95 N 71 49.40 N 91 71 81N 116 98 58 N 146 127 59 N 176 156 54 N 208 183 74 N 244 208 60 N 286 55 82 W 59 32 W 78 27 W 103 77 W 137 11W 176 62 W 217 43 W 260 49 W 305 68 W 354 42.43 W 43 82 N 75 33 W 09 N 70 51W 15 N 65 52 W 78 N 61 34 W 08 N 58 25 W 25 N 56 0 W 88 N 54 9 W 67 N 53 6 W 84 N 53 4 W 54 N 53 58 W 3000 O0 2919.35 2864.42 33 31 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 3001.05 2946 12 36 40 O0 3080 05 3025 O0 3157 21 3102 O0 3230 92 3175 O0 3301 14 3246 O0 3370 46 3315 O0 3439 43 3384 O0 3508 24 3453 O0 3577 11 3522 12 38 48 28 40 28 99 44 28 21 46 0 53 46 15 50 46 28 31 46 32 18 46 22 N 68 12 W N 69 38 W N 68 38 W N 67 24 W N 68 5 W N 68 I W N 68 3 W N 68 7 W N 68 5 W N 68 I W 1007 396.27 453.89 515 17 578 78 646 31 717 50 789 58 861 98 934 55 05 3 54 3 88 3 5O 2 91 1 50 1 83 1 73 1 26 0 39 0 2O 230 52 N 334 25 W 406 04 N 55 24 W 251 272 296 322 348 375 403 430 457 05 N 388 75 N 445 76 N 5O4 35 N 566 99 N 632 97 N 699 04 N 766 10 N 834 22 N 901 10 W 462 43 W 522 33 W 585 83 W 652 84 W 722 68 W 794 84 W 866 17 W 938 41W 1010 22 N 57 6 W 31 N 58 31W 17 N 59 32 W 08 N 60 22 W 69 N 61 7 W 30 N 61 45 W 30 N 62 16 W 52 N 62 43 W 74 N 63 6 W COMPUTATION DATE' 29-APR-93 PAGE 2 ARCO DS3-25A PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY' APR-23-93 KELLY BUSHING ELEVATION' 54.93 FT ENGINEER' 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 3646 07 3591 14 46 16 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3715 O0 3785 O0 3854 O0 3923 O0 3992 O0 4062 O0 4132 O0 4202 O0 4271 50 366O 09 3730 32 3799 57 3868 97 3938 53 4007 2O 4077 10 4147 72 4216 57 45 53 16 46 3 39 46 18 64 46 11 04 45 50 60 45 55 27 45 46 17 45 52 79 45 33 N 67 SS W 1079 47 N 67 34 W 1151 N 67 18 W 1223 N 67 24 W 1295 N 67 26 W 1367 N 67 27 W 1439 N 67 28 W 1511 N 67 29 W 1583 N 67 42 W 1654 N 67 44 W 1726 44 24 41 55 54 38 11 62 41 0 16 0 25 0 32 0 36 0 32 0 29 0 25 0 19 0 27 0 36 484 37 N 968 55 W 1082.91 N 63 26 W 511 539 567 594 622 649 677 704 731 63 N 1035 24 N 1101 02 N 1168 73 N 1234 35 N 1301 88 N 1367 39 N 1433 63 N 1499 85 N 1566 16 W 1154.69 N 63 42 W 44 W 1226.36 N 63 55 W 05 W 1298.40 N 64 6 W 66 W 1370 43 N 64 17 W 15 W 1442 32 N 64 26 W 50 W 1514 07 N 64 35 W 76 W 1585 72 N 64 43 W 88 W 1657 15 N 64 50 W 30 W 1728 84 N 64 57 W 5000 O0 4342 14 4287 21 44 56 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4413 O0 4483 O0 4554 O0 4624 O0 4694 O0 4764 O0 4834 O0 4902 O0 4970 O5 4358 64 4428 06 4499 52 4569 82 4639 76 4709 O8 4779 41 4847 O1 4915 12 44 52 71 45 13 13 45 16 59 45 15 89 45 28 83 45 48 15 46 31 48 47 14 08 47 49 N 67 34 W 1797 40 N 67 39 W 1867 N 67 50 W 1938 N 67 52 W 2009 N 67 47 W 2080 N 67 33 W 2151 N 67 20 W 2223 N 67 10 W 2295 N 66 48 W 2368 N 66 47 W 2442 91 74 74 70 82 29 36 36 O3 0 53 0 53 0 49 0 32 0 58 0 53 0 44 0 43 0 58 0 63 758 86 N 1631 96 W 1799 77, N 65 4 W 785 812 839 866 893 92O 948 976 1006 75 N 1697 59 N 1762 35 N 1828 12 N 1894 13 N 1959 58 N 2025 44 N 2092 99 N 2159 04 N 2227 14 W 1870 69 W 1940 45 W 2011 17 W 2082 96 W 2153 95 W 2225 43 W 2297 63 W 2370 35 W 2444 21 N 65 9 W 98 N 65 15 W go N 65 21W 80 N 65 26 W 87 N 65 30 W 30 N 65 34 W 35 N 65 37 W 34 N 65 40 W 01 N 65 42 W 6000 O0 5036 57 4981 64 48 36 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5102 O0 5169 O0 5235 O0 5300 O0 5366 O0 5430 O0 5490 O0 5549 O0 5607 88 5047 04 5114 09 5180 65 5245 38 5311 52 5375 69 5435 42 5494 25 5552 95 48 30 11 48 31 16 48 54 72 49 14 45 49 0 59 51 38 76 53 53 49 54 11 32 55 16 N 66 44 W 2516 65 N 66 51W 2591 N 66 44 W 2666 N 66 38 W 2741 N 64 24 W 2816 N 59 22 W 2891 N 53 51W 2966 N 51 13 W 3043 N 51 2 W 3121 N 50 57 W 3199 47 45 51 96 87 97 77 22 23 0 74 0 57 0 48 0 34 0 58 1 48 2 74 3 91 3 27 2 26 1035 48 N 2295 93 W 2518 63 N 65 43 W 1064 1094 1124 1155 1190 1232 1282 1332 1384 95 N 2364 51N 2433 24 N 25O2 15 N 2571 54 N 2637 99 N 2701 02 N 2764 82 N 2827 19 N 2891 73 W 2593 64 W 2668 59 W 2743 48 W 2819 97 W 2894 82 W 2969 84 W 3047 86 W 3126 23'W 3205 46 N 65 45 W 44 N 65 47 W 52 N 65 49 W 02 N 65 49 W 18 N 65 43 W 86 N 65 28 W 61 N 65 7 W 21 N 64 46 W 49 N 64 25 W 7000 O0 5663 80 5608 87 55 42 7100 7200 7300 74OO 7500 7600 7700 7800 7900 O0 5719 O0 5772 O0 5826 O0 5878 O0 5930 O0 5982 O0 6034 O0 6085 O0 6134 21 5664 94 5718 05 5771 65 5823 70 5875 84 5927 88 5979 56 6030 76 6079 28 56 54 O1 57 48 12 58 3 72 58 41 77 58 41 91 58 16 95 59 5 63 60 2 83 60 54 N 50 32 W 3277 99 N 50 16 W 3357 N 50 17 W 3437 N 50 5 W 3518 N 49 55 W 3599 N 49 43 W 3680 N 49 30 W 3761 N 48 57 W 3842 N 48 19 W 3923 N 47 52 W 4005 33 67 32 21 32 3O 15 47 31 0 88 0 86 0 97 0 78 0 59 0 52 0 51 0 63 0 77 0 95 1436 38 N 2955 09 W 3285 69 N 64 5 W 1489 1543 1597 1652 1707 1762 1818 1875 1933 44 N 3019 34 N 3O84 63 N 3149 27 N 3214 41N 3279 69 N 3344 44 N 3409 42 N 3473 61N 3538 23 W 3366 09 W 3448 15 W 3531 32 W 3614 52 W 3697 52 W 3780 20 W 3863 88 W 3947 63 W 4032 62 N 63 45 W 70 N 63 25 W 23 N 63 6 W 12 N 62 48 W 36 N 62 30 W 59 N 62 13 W 85 N 61 55 W 79 N 61 38 W 47 N 61 21W COMPUTATION DATE' 29-aPr-93 PAGE 3 ARCO DS3-25A PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' APr-23-93 KELLY BUSHING ELEVATION- 54.93 FT' ENGINEER' 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 HIM VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG BIN 8000 O0 6183 30 6128 37 60 52 8100 82OO 8300 8400 8500 8600 8700 8800 8900 O0 6232 O0 6287 O0 6347 O0 6413 O0 6482 O0 6552 O0 6621 O0 6692 77 6177 4O 6232 60 6292 19 6358 30 6427 O2 6497 91 6566 O0 6637 O0 6762.44 6707 84 59 9 47 54 49 67 51 13 26 47 19 37 45 50 09 45 40 98 45 27 O7 45 10 51 45 36 N 47 25 W 4087 27 N 47 0 W 4168 N 46 58 W 4246 N 47 26 W 4321 N 47 27 W 4391 N 48 10 W 4459 N 48 32 W 4527 N 48 40 W 4594 N 50 4 W 4662 N 55 59 W 4730 54 61 21 83 67 16 63 O3 59 0.86 0.90 1.70 2 81 3 69 3 41 2 20 0 59 0 61 2 40 1992 54 N 3603 22 W 4117 45 N 61 3 W 2051 2108 2163 2214 2262 2310 2357 2404 2447 53 N 3667 78 N 3728 08 N 3786 16 N 3842 69 N 3895 36 N 3949 64 N 4OO2 53 N 4056 14 N 4113 04 W 4201 11W 4283 63 W 4360 16 W 4434 72 W 4505 26 W 4575 92 W 4645 67 W 4715 90 N 60 47 W 20 N 60 30 W 91 N 60 16 W 49 N 60 3 W 15 N 59 51W 41 N 59 40 W 62 N 59 30 W 76 N 59 21W 39 W 4786.28 N 59 15 W 9000 O0 6831 80 6776 87 46 28 9100 9200 9300 9400 9500 9600 9700 9800 ggo0 O0 6900 O0 6969 O0 7039 O0 7109 O0 7178 O0 7248 O0 7317 O0 7388 O0 7458 39 6845 46 46 23 82 6914 89 46 9 27 6984 34 45 47 06 7054 13 45 47 66 7123 73 45 54 16 7193 23 46 0 86 7262 93 45 36 04 7333,11 45 25 46 7403.53 45 1 N 61 35 W 4801 64 N 63 42 W 4874 N 65 35 W 4945 N 67 44 W 5017 N 67 58 W 5089 N 67 27 W 5161 N 67 32 W 5233 N 67 45 W 5304 N 67 41W 5376 N 67 52 W 5447 12 93 86 48 28 18 88 12 12 3 67 3 3O 0 86 1 24 1 22 0 76 0 32 0 32 0 31 0 38 2484 57 N 4174 90 W 4858 28 N 59 15 W 2517 2548 2577 2604 2631 2658 2686 2713 2740 68 N 4239 89 N 43O4 24 N 4370 04 N 4437 31N 4503 go N 4569 16 N 4636 21N 4702 10 N 4767 69 W 4930 54 W 5002 66 W 5073 08 W 5144 50 W 5215 90 W 5287 21W 5358 13 W 5428 83 W 5499 89 N 59 18 W 59 N 59 22 W 94 N 59 28 W 77 N 59 36 W 87 N 59 42 W 13 N 59 48 W 17 N 59 55 W 77 N 60 1W 13 N 60 7 W 10000 O0 7528.71 7473.78 45 36 10100 10200 10300 10400 1'0500 10600 10700 10800 10900 O0 7598.70 7543 77 45 25 O0 7668.95 7614 O0 7738.83 7683 O0 7808.99 7754 O0 7879.45 7824 O0 7949.12 7894 O0 8018.88 7963 O0 8088.62 8033 O0 8157.99 8103 02 45 29 90 45 38 O6 45 8 52 45 36 19 45 48 95 45 56 69 45 45 06 46 23 N 69 5 W 5518 28 N 71 18 W 5589 N 71 37 W 5660 N 72 11W 5732 N 72 22 W 5803 N 72 36 W 5873 N 72 47 W 5945 N 73 1W 6016 N 72 55 W 6088 N 72 54 W 6159 64 68 04 11 86 35 74 14 90 0.56 1.06 1. O0 0.78 0.48 0.51 0.56 0.46 0.60 0.57 2766.27 N 4834 O1 W 5569 55 N 60 13 W 2790.19 N 4901 2812.92 N 4968 2835.05 N 5036 2856.81 N 5104 2878.25 N 5172 2899.61 N 5240 2920.68 N 5309 2941.66 N 5377 2962.80 N 5446 31W 5639 75 W 5709 76 W 5779 63 W 5849 27 W 5919 74 W 5989 23 W 6059 76 W 6129 61W 6200 86 N 60 21W 73 N 60 29 W 84 N 60 38 W 66 N 60 46 W 18 N 6O 54 W 42 N 61 3 W 56 N 61 11W 73 N 61 19 W 30 N 61 27 W 11000 O0 8226.80 8171 87 46 39 11100 11200 11300 11400 11500 11600 11700 11800 11900 O0 8295.44 8240 51 46 46 O0 8363.77 8308 84 47 2 O0 8432 30 8377 37 46 9 O0 8502 47 8447 54 44 40 O0 8574 37 8519 44 43 29 O0 8647 69 8592.76 41 58 O0 8722 71 8667.78 41 0 O0 8798 47 8743.54 40 28 O0 8874 97 8820.04 39 43 N 72 37 W 6232 21 N 72 33 W 6304 N 72 33 W 6377 N 72 8 W 6450 N 70 35 W 6521 N 68 58 W 6590 N 69 9 W 6658 N 69 6 W 6724 N 68 59 W 6790 N 69 1W 6854 71 49 10 21 68 66 77 03 42 0 46 0 45 0 29 0 45 0 94 1 58 1 72 1 65 1 11 0 91 2984.36 N 5515 89 W 6271 48 N 61 35 W 3006.23 N 5585 3028 10 N 5654 3O5O 18 N 5724 3072 79 N 5791 3097 05 N 5856 3121 40 N 5920 3144 95 N 5982 3168 35 N 6043 3191 39 N 6103 25 W 6342 91W 6414 31W 6486 87 W 6556 99 W 6625 47 W 6692 25 W 6758 19 W 6823 32 W 6887 90 N 61 43 W 62 N 61 50 W 24 N 61 57 W 50 N 62 3 W 41 N 62 8 W 91 N 62 12 W 55 N 62 16 W 38 N 62 20 W 35 N 62 24 W -.) COMPUTATION DATE: 29-aPr-93 PaGE 4 ARCO DS3-2$A PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY: APR-23-93 KELLY BUSHING ELEVATION: 54.93 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE ~EASURD VERTICAL VERTICAL DEVIATIDN AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZI~LFFH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/ZO0 FEET FEET FEET DEG WIN 12000.00 8952.30 8897.37 39 4 N 68 57 W 6917.82 12100.00 9030.34 8975.41 38 21 N 68 40 W 6980.34 12200.00 9108.65 9053.72 38 28 N 68 30 W 7042.52 12300.00 9187.23 9132.30 38 5 N 68 31 W 7104.38 12395.00 9262.00 9207,07 38 $ N 68 31 W 7162.98 0.69 3214.17 N 6162.50 W 6950.35 N 62 27 W 0.68 3236.76 N 6220.80 W 7012.49 N 62 31 W 0.61 3259.45 N 6278.70 W 7074.33 N 62 34 W 0,00 3282,28 N 6336.20 W 7135.88 N 62 37 W 0.00 3303.74 N 6390.72 W 7194.17 N 62 40 W COMPUTATION DATE: 29-APR-93 PAGE 5 ARCO DS3-25a PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF sUrVEY: APr-23-93 KELLY BUSHING ELEVATION: 54.93 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURB DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES hOrIZ. DEPARTURE SECTION SEVERI~ NORTH/SOUTH EAST/WEST DIST. AZIMLFFH FEET DEG/IO0 FEET FEET FEET DEG 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0.00 O0 1000 01 O0 1997 O0 2919 O0 3646 O0 4342 O0 5036 O0 5663 O0 6183 O0 6831 -54.93 0 0 945.08 0 33 99 1943.06 8 18 35 2864.42 33 31 07 3591 14 46 16 14 4287 21 44 56 57 4981 64 48 36 80 5608 87 55 42 30 6128 37 60 52 80 6776 87 46 28 N 0 0 E S 4 18 W -0 N 62 28 W 43 N 68 12 W 396 N 67 55 W 1079 N 67 34 W 1797 N 66 44 W 2516 N 5O 32 W 3277 N 47 25 W 4087 N 61 35 W 4801 0 O0 15 44 27 47 4O 65 99 27 64 0 O0 0 20 2 09 3 54 0 16 0 53 0 74 0 88 0 86 3 67 0 O0 N 2 10 230 484 758 1035 1436 1992 2484 56 S 0 94 N 42 52 N 334 37 N 968 86 N 1631 48 N 2295 38 N 2955 54 N 3603 57 N 4174 87 W 2 43 W 43 25 W 406 55 W 1082 96 W 1799 93 W 2518 09 W 3285 22 W 4117 90 W 4858 0 O0 E 0 O0 N 0 0 E 70 S 18 45 W 82 N 75 33 W 04 N 55 24 W 91 N 63 26 W 77 N 65 4 W 63 N 65 43 W 69 N 64 5 W 45 N 61 3 W 28 N 59 15 W 10000.00 7528.71 7473.78 45 36 11000.00 8226.80 8171,87 46 39 12000.00 8952.30 8897.37 39 4 12395.00 9262.00 9207.07 38 5 N 69 5 W 5518.28 N 72 37 W 6232.21 N 68 57 W 6917.82 N 68 31 W 7162.98 O. 56 0.46 O. 69 O. O0 2766.27 N 4834.01 W 5569.55 N 60 13 W 2984.36 N 5515.89 W 6271.48 N 61 35 W 3214.17 N 6162.50 W 6950.35 N 62 27 W 3303.74 N 6390.72 W 7194.17 N 62 40 W COMPUTATION DATE' 29-APR-93 PAGE 6 ARCO DS3-25A PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY' APR-23-93 KELLY BUSHING ELEVATION' 54.93 ET ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN iO0 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTL~E SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 54 91 154 9I 254 91 354 91 454 554 654 754 854 0 O0 54 93 154 93 254 93 354 93 92 454 93 92 554 93 92 654 93 92 754 93 92 854 93 -54 93 0 O0 100 O0 2OO O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 15 N 0 48 W 0 12 N 60 55 W 0 12 S 43 43 W 0 11 S 20 48 E 0 3 S 34 41E 0 13 S 88 19 W 0 16 S 45 16 W 0 18 S 10 58 E 0 21 S 15 49 E 0 O0 0 O0 0 21 0 50 0 44 0 26 0 41 0 75 0 63 0 27 0 O0 0 O0 0 28 0 29 0 24 0 17 0 24 0 24 0 29 0 71 0.00 N 0.00 N 0.28 N 0.22 N 0.07 S 0.27 S 0.28 S 0.42 S O.84 S 1.41 S 0.00 E 0.00 E 0.12 W 0.45 W 0 50W 0 39 W 0 55W 0 98 W 1 02 W 0 86 W 0 O0 N 0 0 E O0 N 0 0 E 30 N 22 28 W 50 N 63 29 W 51 S 81 46 W 48 S 55 14 W 62 S 62 59 W O7 S 66 50 W 32 S 50 18 W 65 S 31 21W 954 92 1054 1154 1254 1354 1454 1555 1655 1755 1855 954 93 93 1054 93 1154 93 1254 93 1354 94 1454 03 1554 20 1654 39 1754 78 1854 900 O0 93 1000 O0 93 1100 O0 93 1200 O0 93 1300 O0 93 1400 O0 93 1500 O0 93 1600 O0 93 1700.00 93 1800.00 0 31 S 3 59 W 0 33 S 7 0 E 0 11 S 42 4 E 0 1 N 2 17 W 0 11 S 88 10 W 1 41 N 67 25 W 2 57 N 66 52 W 3 31 N 64 24 W 3 53 N 69 29 W 6 9 N 8O 3O W -0 O2 -0 36 -0 76 -0 91 -0 78 0 67 4 75 10 56 16 81 25 43 0 20 0 19 0 33 0 36 0 23 1 08 1 49 0 88 1 03 1 90 2 14 S 3 09 S 3 80 S 3 86 S 3 90 S 3 44 S 1 84 S 0 56 N 3 26 N 5 15 N 0 84 W 0 86 W 0 71 W 0 58 W 0 73 W 2 11 W 5.87 W 11.16 W 16.81 W 25.34 W 2 29 S 21 26 W 3 3 3 3 4 6 11 17 25 21 S 15 31W 87 S 10 35 W 91 S 8 34 W 97 S 10 38 W 04 S 31 33 W 15 S 72 36 W 17 N 87 7 W 12 N 79 2 W 86 N 78 31W 1956 51 1954 93 1900.00 2057 2159 2262 2367 2475 2586 2696 2808 2923 7 48 62 2054 27 2154 24 2254 61 2354 92 2454 02 2554 76 2654 96 2754 99 2854 93 2000 O0 93 2100 93 2200 93 2300 93 24O0 93 2500 93 2600 93 2700 93 2800 9 17 O0 11 44 O0 15 52 O0 20 33 O0 24 12 O0 25 8 O0 25 44 O0 28 37 O0 30 40 N 67 20 W N 56 56 W N 50 32 W N 48 36 W N 48 38 W N 47 14 W N 46 17 W N 49 49 W N 56 24 W N 63 50 W 37 36 52 15 69 71 92 84 124 11 163 14 206.03 250.55 299.67 355.98 2 27 2 42 2 28 2 94 3 58 3 98 3 15 2 03 1 9O 2 53 8 35 N 15 26 42 64 91 123 155 186 214 36.93 W 40 N 50.02 W 52 26 N 64.57 W 69 22 N 83.07 W 93 03 N 107.99 W 125 83 N 138.85 W 166 48 N 172.32 W 212 64 N 207.34 W 259 11N 248.01W 310 37 86 N 77 16 W 34 N 72 53 W 71 N 67 52 W 19 N 63 4 W 55 N 59 20 W 47 N 56 31W O0 N 54 23 W 26 N 53 6 W 08 N 53 7 W og N 297.44 W 366.48 N 54 15 W 3043 05 2954 93 2900 O0 34 57 3167 3297 3433 3577 3722 3867 4012 4156 4300 90 3054 02 3154 86 3254 55 3354 52 3454 83 3554 81 3654 62 3754 88 3854 93 3000 93 3100 93 3200 93 3300 93 3400 93 3500 93 3600 93 3700 93 3800 N 69 11W O0 38 16 N 69 8 W 495 O0 40 23 N 67 24 W 576 O0 45 lg N 68 2 W 670 O0 46 10 N 68 3 W 773 O0 46 32 N 68 7 W 878 O0 46 25 N 68 2 W 983 O0 46 12 N 67 53 W 1088 O0 45 50 N 67 20 W 1192 O0 46 18 N 67 24 W 1296 42O 5O 2O 85 18 37 33 75 72 O7 O4 3 83 3 65 2 94 1 71 1 76 1 02 0 21 0 17 0 3O 0 36 239 32 N 356 83 W 429 65 N 56 9 W 265 296 331 369 409 448 487 527 567 56 N 426 O2 N 5O2 28 N 588 91N 684 13 N 782 50 N 879 85 N 977 22 N 1072 26 N 1168 79 W 502 55 W 583 97 W 675 65 W 778 O1W 882 81W 987 11W 1092 68 W 1195 64 W 1299 67 N 58 7 W 26 N 59 30 W 74 N 6O 39 W 19 N 61 37 W 57 N 62 23 W 53 N 62 59 W 13 N 63 28 W 24 N 63 5O W 04 N 64 6 W COMPUTATION DATE' 29-APR-g3 PAGE 7 ARCO DS3-2$A PRUDHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY' APr-23-93 KELLY BUSHING ELEVATION' 54.93 FT ENGINEER' SARBER INTERPOLATED VALUES FOR EVEN 100 FEET 0f 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. AZIBUTH FEET DEG/IO0 FEET FEET FEET DEG BIN 4445 26 3954 93 3900 O0 46 5 4589 07 4054 4732 53 4154 4876 O0 4254 5018 06 4354 5159 26 4454 5301 23 4554 5443.22 4654 5585.90 4754 5730.39 4854 93 4O0O 93 4100 93 4200 93 4300 93 4400 93 4500 93 4600 93 4700 93 4800 O0 45 59 O0 45 33 O0 45 46 O0 44 53 O0 45 11 O0 45 15 O0 45 19 O0 45 45 O0 46 47 N 67 27 W 1400.18 N 67 28 W 1503.53 N 67 34 W 1606.38 N 67 45 W 1709.25 N 67 33 W 1810.15 N 67 46 W 1909.84 N 67 52 W 2010.62 N 67 44 W 2111.41 N 67 21W 2213.18 N 67 5 W 2317.47 0 29 0 26 0 22 0 32 0 55 0 52 0 32 0 6O 0 45 0 48 607.25 N 1264 80 W 1403 02 N 64 21 W 646 87 N 1360 686 725 763 801 839 877 916 957 28 N 1455 34 N 1550 72 N 1643 66 N 1735 68 N 1829 74 N 1922 68 N 2016 04 N 2112 25 W 1506 23 N 64 34 W 26 W 1608 96 N 64 45 W 43 W 1711 71 N 64 56 W 74 W 1812 50 N 65 5 W 93 W 1912 10 N 65 13 W 26 W 2012 78 N 65 21W 60 W 2113 48 N 65 28 W 63 W 2215.20 N 65 33 W 80 W 2319.45 N 65 38 W 5877 59 4954 93 4900 O0 47 35 6027 6178 6330 6482 6639 6809 6984 7166 7354 71 5054 69 5154 19 5254 54 5354 94 5454 42 5554 25 5654 24 5754 65 5854 93 5000 93 5100 93 5200 93 5300 93 5400 93 5500 93 5600 93 5700 93 5800 O0 48 26 O0 48 35 O0 48 56 O0 48 48 O0 52 56 O0 54 13 O0 55 43 O0 57 44 O0 58 16 N 66 48 W 2425 45 N 66 48 W 2537 N 66 45 W 2650 N 66 28 W 2764 N 60 22 W 2878 N 52 12 W 2997 N 51 1W 3128 N 50 36 W 3265 N 50 18 W 3410 N 50 2 W 3562 39 48 26 84 49 53 57 47 46 0 61 0 69 0 48 0 31 1 28 3 27 3 18 1 16 1 01 0 69 999 50 N 2212 11 W 2427.43 N 65 41 W 1043 1088 1133 1183 1252 1337 1428 1525 1627 66 N 2314 20 N 2418 30 N 2523 82 N 2626 03 N 2727 62 N 2833 11N 2945 10 N 3062 42 N 3184 99 W 2539 38 N 65 44 W 97 W 2652 47 W 2766 64 W 2881 04 W 3000 79 W 3133 04 W 3273 13 W 3420 72 W 3576 47 N 65 47 W 27 N 65 49 W 08 N 65 44 W 72 N 65 2O W 63 N 64 44 W 03 N 64 8 W 90 N 63 31W 44 N 62 56 W 7546 66 5954 93, 5900 O0 58 44 7739 7941 8142 8311 8460 8604 8747 8889 9033 24 6054 56 6154 08 6254 47 6354 70 6454 16 6554 13 6654 29 6754 70 6854 93 6O00 93 6100 93 6200 93 6300 93 6400 93 6500 93 6600 93 6700 93 6800 O0 59 26 O0 61 2 O0 57 9 O0 50 38 O0 45 54 O0 45 41 O0 45 37 O0 45 26 O0 46 49 N 49 40 W 3718 18 N 48 41W 3874 N 47 40 W 4039 N 46 43 W 4201 N 47 26 W 4329 N 47 57 W 4433 N 48 33 W 4529 N 48 42 W 4626 N 55 25 W 4723 N 62 41W 4826 O0 41 9O 47 16 97 36 12 02 0 48 0 65 0 95 1 23 2 91 3 75 2 09 0 39 2 26 3 93 1733.21 N 3309 92 W 3736 26 N 62 22 W 1840.66 N 3434 1958.05 N 3565 2075.98 N 3693 2169.05 N 3793 2243.83 N 3874 2312.33 N 3951 2379.86 N 4028 2442.83 N 4107 2496.01 N 4196 57 W 3896 54 W 4067 14 W 4236 13 W 4369 75 W 4477 49 W 4578 17 W 4678 09 W 4778 71 N 61 49 W 80 N 61 14 W 62 N 60 4O W 51 N 60 14 W 55 N 59 56 W 33 N 59 40 W 66 N 59 26 W 66 N 59 15 W 57 W 4882.76 N 59 15 W 9178.55 6954 93 6900 O0 46 0 9322.44 7054 93 7000 9465.90 7154 93 7100 9609.74 7254 93 7200 9752.88 7354 93 7300 9895.00 7454 93 7400 10037.48 7554 93 7500 10180.02 7654 93 7600 10323.01 7754.93 7700 10465.10 7854.93 7800 O0 45 42 O0 45 55 O0 46 0 O0 45 23 O0 45 0 O0 45 39 O0 45 22 O0 45 34 O0 45 8 N 64 49 W 493O 5O N 68 2 W 5033 N 67 35 W 5136 N 67 33 W 5240 N 67 42 W 5342 N 67 49 W 5443 N 7O 17 W 5545 N 71 27 W 5646 N 72 12 W 5748 N 72 26 W 5849 93 79 18 59 58 O6 47 43 O9 0 76 1 28 0 97 0 30 0 31 0 39 0 73 1 02 0 64 0 50 2542.38 N 4290 53 W 4987 22 N 59 21 W 2583.30 N 4385 2621.93 N 4480 2661.58 N 4576 2700 46 N 4671 2738 77 N 4764 2775 62 N 4859 2808 41N 4955 2840 08 N 5052 2870 79 N 5148 55 W 5089 88 W 5191 37 W 5294 11W 5395 56 W 5495 11W 5595 25 W 5695 41W 5795 57 W 5894 84 N 59 3O W 61 N 59 40 W 07 N 59 49 W 53 N 59 58 W 62 N 60 7 W 99 N 60 16 W 76 N 60 27 W 94 N 60 40 W 85 N 60 51W ARCO DS3-25A PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 29-APR-93 PAGE 8 DATE OF SURVEY: APR-23-93 KELLY BUSHING ELEVATION: 54.93 ET ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 10608 33 7954 93 7900 O0 45 47 10751 10895 11040 11187 11332 11473 11609 11742 75 8054 57 8154 98 8254 04 8354 53 8454 15 8554 76 8654 62 8754 11873 91 8854 93 8000 93 8100 93 8200 93 8300 93 8400 93 8500 93 8600 93 87OO 93 8800 O0 45 43 O0 46 22 O0 46 38 O0 47 0 O0 45 42 O0 43 46 O0 41 46 O0 40 48 O0 39 56 12003.40 8954.93 8900.00 39 3 12131.37 9054.93 9000.00 38 23 12258.96 9154.93 9100.00 38 5 12386.01 9254.93 9200,00 38 5 12395.00 9262.00 9207.07 38 5 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN N 72 48 W 5951.30 N 73 1W 6053.72 N 72 55 W 6156.70 N 72 28 W 6261.92 N 72 34 W 6368.04 N 71 49 W 6473.42 N 69 6 W 6572.16 N 69 10 W 6665.20 N 68 59 W 6752.67 N 69 4 W 6837.72 .56 O. 64 .47 30 6O 50 73 50 93 2901 38 N 5246 45 W 5995 27 N 61 3 W 2931 2961 2993 3025 3057 3090 3123 3154 3185 52 N 5344 86 N 5443 31N 5544 26 N 5645 41N 5746 44 N 5839 73 N 5926 94 N 6008 41N 6087 73 W 6095 55 W 6197 32 W 6300 86 W 6405 53 W 6509 68 W 6607 58 W 6699 31W 6786 73 W 6870 go N 61 15 W 16 N 61 27 W 74 N 61 38 W 31 N 61 49 W 26 N 61 59 W 02 N 62 7 W 41 N 62 12 W 27 N 62 18 W 75 N 62 23 W N 68 56 W 6919.96 N 68 36 W 6999.81 N 68 31W 7079.07 N 68 31 W 7157.44 N 68 31W 7162.98 O. 68 O. 70 0.00 0.00 0.00 3214.94 N 6164.50 W 6952.47 N 62 27 W 3243.86 N 6238.93 W 7031.85 N 62 32 W 3273.00 N 6312.64 W 7110.70 N 62 36 W 3301.71 N 6385.56 W 7188.65 N 62 40 W 3303.74 N 6390.72 W 7194.17 N 62 40 W ARCO DS3-2$A PRUDHOE BAY NORTH SLOPE, ALASKA MARKER GCT EAST READING TD COMPUTATION DATE: 29-APR-93 PAGE 9 DATE OF SURVEY: APR-23-93 KELLY BUSHING ELEVATION: $4.93 FT ENGINEER: SARBER INTERPOLAT~:D VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1014' FSL, 29'FEL, SECIO TION R15E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 12250.00 9147.90 9092.97 3270.83 N 6307.51W 12395.00 9262.00 9207.07 3303.74 N 6390.72 W ARCO DS3-2$A PRUDHOE BAY NORTH SLOPE, ALASKA MARKER COMPUTATION DATE: 29-APR-93 PAGE DATE OF SURVEY: APR-23-93 KELLY BUSHING ELEVATION: 54.93 ET ENGINEER: SARBER · ~~~ STRATIGRAPHIC SUMMARY SURFACE LOCATION = lO14' FSL, 29'FEE, SECIO TlON RlSE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 12395.00 9262.00 9207.07 3303.74 N 6390.72 W FINAL WELL LOCATION AT 'rD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 12395.00 9262.00 9207.07 7194.17 N 62 40 W DIRECTIONAL SURVEY COMPANY ARCO FIELD PRUDHOE BAY WELL DS3-25A COUNTRY USA RUN I DATE LOGGED 23 - APR - 93 DEPTH UNIT FEET REFERENCE 931 93 All Interpretations are opinions based on Inferences from electrical or other measurements 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. costs, damages or expenses Incurred or su~alned by anyone resulting from any interpretation made by any of our offlcet-s, agents or employees. These Interpretations are also subject to our General Terms and Conditions as set out in our current price Schedule. k'ELL' D. $. 3-25A (1014' FSL, 29' FEL, SEC 10, TION, R15E) HORIZONTAL PROdECTION REF 93193 SCALE = I / 2000 tN/FT NORTH I ,:::: :::: iiii :::: !:ii :::: i!ii !ii! :::~ !::i ~::i i:i, :!i! !!~:!!:: i!:-~-- ::i: iii: ::ii :::: :::: :i!! :::: !iii iii: !iii :iii iJ~il:ill ii[ ii:i :.* : :.:::: :::: ;:;: :::: ;;:: ;*:: :::: :::: :!!! i:il iii: .::i:*! :. :::: :::: : · :.:: :::: :::: :: : :::: .::: :::: :::: :::: :: :.. · : , ~!i, i~.-i...i i..-!--.i-.i ~..!..~.!..}.--!..!.i i..-! !..i... .... .......I. ii i .;-i.........!... ...........i.!i i.: i.. !,,. ~.~...i ...~...~...i...i .... i...;...i..i .... ;.i.~i .... i..i..i..-i .... i..i..i..i ..... ~...i...i..i ..... ;.i ..... ~ ...... ;.i..;...i..~...~...ii..i..,..;.i.,~..i..i..ii..i...L;!}!, 4000 ':.' ::: i~ ii~ : .: i~': i~.;.i ~i.ii i..i.i.i...i.-~.~i iiil..iill ~iil.ii;i ii;~ i~.~-~.i~.ili~ i]i; ii~; :'.! ...: :.: ::.. .:.: :::; :::: ::;. :::: .::: .;:: :::: :: .... :.: ::: ,:. ":' ''" '"' ........ ~" ;:;' iili ill! ii!i,ii ' -7'~-'-:-7T~- :.: .... ::: :::: '!!i iii! !!:! ii!: , , i-; ;-.~.L;..-i ...... i..:..L.! ...... ;..-i---!---i ..... :"?"!"'i ...... ~'"~"':'"~ ...... i"'~'":'"~ ..... ~'"~ ........ :'",'! : i':"i"i": .... ~'!'i"i' ";-'; .... ~ : ....t ....! ; .... : ~.; ': * :: ..... ~' *:: ::: *--:' · i:::':* : · :.i.i.-i .... i'"?'i'i i..;i-} .... i-'-i'-i--} .... i'"i-"i-': i'-i"i--: :!'}"i',~'~i }i~'i ~i:':~:'?·~'; ,',, i;i; i,,, ::.;.h.;...i ;.i...i.~.; .... ;.;~..; ;.~ i;:~ :i~; ,,: ,}ii;:,: ~, ~ ~ i , : : :: ::': :::: :::' :::: :'i[,[![~ ....... !"!!'! .... !':, :', i .... ' ....... · :::. .::: :::: :::: -:: :::: ::,: : , ~ :~[ [~.i -4000 !'i'5 5' '!'"}'"!"'i ..... i*"i"'!"*! ..... !'}'i'"i'i-'5"!"!'}'!'"i'"i'~"~'"!'}"}'"~ } i 5'~ } r :'5 ! !'~ 5 ~ ~'i ...... , 7': 'i i':" i': :'' : : : : ! ! : ! I ! ! ! i' ~-'!"!"i'~ i"i"'!'"! .....!'"!'i'"i .... i"!"i"!' ~ :': i' , i"~'i i' i i i"! : ! ~ i ': : : i ~ ~ :': : · ! · iiii'.i.:..-!.i-..!..-!-..! ...... !--i.!...!-..i.!-.!!.!.-i!!.!.!ii !!.:i.!.:! : .... :i!.: ! i::i.: :'': .... !!i:.*-~iiii:i!i! i iii- iii!* il ;-~ ;i--~-~ iii ~,. i!-~---~-~-: ........ ;5-.:--~ ..... :--~ · .~.~ ~.~. i.~.~.-~ ~ i :.~-.~. -~--~..~..~ ~...~.~--~*- ~-.~.~.~ ~ ~..~.. ~.-~ ~ ~ .~-~.~ ~. ,.~.-~...~ ~ ~.~ .:-~..:..~ .... : ~ . : · ~ . : . ........................... ~u~-6000 ' ' : ' ' ~ ' ' ~ -10000 -8000 -6~0 -4~0 -2000 0 2000 4000 60~ WEST fEAST IJELL: D.S. 3-25A (1014' FSL, 29' FEL, SEC 10, TION, R15E) VERTICAL PROJECTION 112.00 -4000 -2000 0 0 2000 4000 6000 8000 10000 12000 . : : -!.!!~ .!!..!.! !'!!! .... !.!...!...!...!..!...!.,.! .... !...!.!..,!.!...!...!..! .... !.!!.~1~!!.~ !!..!..! :.:,::;: :: :::: :::: :::: :::: ::: , :.~ ~i! !::~ ~. : , 292.00 II PROJECTION ON VERTICAL PLANE 112.00 292,00 SCALED IN VERTICAL DEPTHS HORIZ SCALE = I / 2000 IN/FT DINF'N.,~i PRUDHOE BAT I~ILLIN(; WELL LOC. ATI~ 1 PRUDHOE BAY LOC~TI£~ MAGNETIC DECLINA?!ON 30,17 DATE: 1'.7-M~-93 WELL i~J/'IB~: 0 ~LL HEAD LO~TIO~: LAT(N/-5) AZi~TH P~NYl ROTARY TABLE TO TARGET IS TIE IN POINT(TIP) : MF_..ASUF-~D DEPTH TRU~ Ul~RT DID'TH INCLINATION AZIPILCH LATITUDE(N/-S) DEPARTL~'£(£/-W) 8800,(X, 6690,~:i 45.52 312,78 259>.00 -;~47.00 DEF'(E/-W) 290,02 RE E VED JUN 1 5 t99;~ ,Alaska Oil & Gas Cons. Commissio~ ;Anchorage J~.A$~ED :FT~L VERTI~L Bh¥'TH DEPTH ft ft fr 8800,00 0.0 6690,00 9221.17 421.2 6984,74 9313,61 92.4 7048,96 9406.79 93.2 7113,90 9471,78 ~5,0 7159,02 SUR~ CALCULS7IONS TARGET ~T~TI~ AZI~TH LATIniZE ft deg des ft 4595.18 45,52 312,7~ ~87,34 ~,26 ~2.40 2750,89 4~3,77 45,71 ~2,0~ 2776,03 5020,54 4~,94 292.~0 5067,24 46.I1 2~.~ 2819.94 DEPARTL~:E DISPLACEMENT at E/-W ft ft -3947,00 4720,90 -4199,~ 5020,13 -42&),87 508%41 ~ ~ 51Sl,ll -4365,h4 5197.20 AZIMUTH de:: 333,27 303,23 :3,')3,0~, 332,36 de,,~/ lOOft 3,47 0,66.. 0,71 9502,48 9597,46 968%67 9781,79 9875,57 30.7 7180.35 95.0 7246,~ ~2.2 7310,54 92.1 7375,01 93,8 744O.87 ~89.29 45.88 292-31 2828~51 5157,54 46.08 252,2,: 2854.4i 5223,76 45.70 291.80 2879,25 5289.46 45.46 5356,17 45.32 292-53 29~.24 -43~5,98 5218,94 302,82 2,60 -4449,18 5286,11 332,68 0,22 -4510,5~ 5351,19 302,55 0.55 -4571,57 .~15,87 302,42 0,37 -46~,33 5481,62 302.30 0,32 ~67,89 10061,59 i0155,05 10247,15 10341,74 92,3 7505,47 93,7 7570.78 93.5 7636.25 92,1 7700,67 ~a.6 7766,65 5422,~0 45,88 £'"$1,:1 29.53,75 5489,2d 45,73 2~P.46 2?77,04 5555.97 45,34 2~9,~:: 5621.7~ 45,89 288.45 3020,13 5689.50 45,65 2~7,61 3041.11 -4694,56 5546,49 3>2,19 -4757.56 5612,24 -4820,55 5677,30 -4882,&~ 5741,41 ~,1.74 -4947,30 .~7,26 1,25 1,27 0,55 0,74 0,68 10432,56 10524,57 10518,60 10709.94 10804.27 ?0,8 92,0 7894,73 94,0 7960,12 91,3 8023,64 94,3 8089,12 5754,12 45,18 287.37 3~60,55 5819.81 46,!1 286,65 3079.81 5887,26 45.77 266.52 5952,82 46,12 287.~ 3118,~ 6020,65 45.95 287.44 313~.82 -5009,02 5870.~ 301,43 -5071,93 5933,78 33:,27 -5136.~: 5999.',17 301,10 -5199.43 6062,87 -52,.q,18 6128,93 30C.81 0,56 1,14 0,3~, 0,93 0.22 10895.97 10985,07 11080.66 11174,04 91.7 8!52,EJ 89,1 8213,82 ~.6 8279,41 ~,4 8343.37 b086,/"5 46,44 2~6,85 3158.~ 6151,37 ~.75 286-70 3177.0I 6220.80 46,~ 2~6<84 3177.07 6o~ ~ 46,93 287-59 3217,2i -5327,42 6!93,25 3~,66 -5389,~' 6256.11 30C.52 -5455,97 6323,68 3~,37 -b-'520,96 6389,95 3C<,23 0,71 0,36 0,18 0,68 ? IRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/3-25A 500292102101 NORTH SLOPE COMPUTATION DATE: 3/24/93 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN tGiNAL DATE OF SURVEY: 032393 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-30016 KELLY BUSHING ELEV. = 62.00 FT. OPERATOR: ARCO ALASKA INC COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/IO0 NORTH/SOUTH EAST/WEST VERT. SECT. 8800 6690.00 6628,00 45 30 9063 6875,62 6813,62 45 30 9156 6940.81 6878,81 45 30 9249 7005.82 6943.82 45 47 9342 7071.63 7009.63 44 5 N 47.20 W .00 2590.00N 3947.00W 4708.23 N 70.42 W 6.28 2685.82N 4105.28W 4893.13 N 70.62 W .15 2707.94N 4167.82W 4958.54 N 71.62 W .83 2729.46N 4230.74W 5023.99 N 72.52 W 1.95 2749.69N 4293.24W 5088.44 9455 7152.09 7090.09 45 5 9528 7203.2'1 7141.21 46 0 9621 7267.98 7205.98 45 42 9714 7332.94 7270,94 45 42 9807 7397.60 7335,60 46 12 N 72.52 W .88 2773.52N 4368.92W 5166.17 N 71.52 W 1.57 2789.61N 4418,48W 5217.30 N 72.22 W ,63 2810.38N 4481.90W 5282.81 N 71.22 W ,77 2831.25N 4545.09W 5348.19 N 71.82 W ,71 2852.44N 4608.49W 5413.90 9900 7.461.67 7399.67 46 42 9993 7525,33 7463.33 46 54 10086 7588.88 7526.88 46 54 10179 7652.19 7590.19 47 17 10272 7715.96 7653.96 46 5 N 71.72 W .54 2873.52N 4672.51W 5480.10 N 71.52 W .27 2894.90N 4736.84W 5546.71 N 71.82 W .24 2916,26N 4801.30W 5613.43 N.71,52 W .49 2937.68N 4865.97W 5680.36 N 71,12 W 1.33 2959,36N 4930.09W 5746.93 10365 7780.74 7718.74 45 35 10458 7846.38 7784.38 44 35 10551 7913,06 7851.06 43 47 10644 7980,24 7918.24 43 42 10737 8048.14 7986.14 42 30 N 70.82 W .59 2981.11N 4993.17W 5812.63 N 69.52 W 1.46 3003.45N 5055.13W 5877.64 N 68,12 W 1.36 3026.87N 5115,59W 5941,86 N 68.02 W .13 3050.89N 5175,24W 6005.67 N 68.62 W 1.36 3074,36N 5234.29W 6068.68 11109 8320.86 8258.86 43 12 11202 8388.65 8326.65 43 12 11295 8456.28 8394.28 43 30 11388 8523,68 8461.68 43 35 11481 8591,03 8529.03 43 35 N 68.42 W .19 3167.00N 5469.70W 6319.45 N 68,52 W ,07 3190.37N 5528.92W 6382.56 N 68.22 W ,39 3213.90N 5588.27W 6445.86 N 68,12 W .13 3237.73N 5647.75W 6509.43 N 67,92 W ,15 3261.73N 5707.22W 6573.07 11574 8658.55 8596,55 43 17 11667 8727.32 8665.32 41 17 11760 8797.46 8735.46 40 47 11853 8868.23 8806.23 40 5 11946 8939.73 8877.73 39 24 N 68.22 W .39 3285.62N 5766.55W 6636.53 N 69.72 W 2.41 3308.09N 5824.95W 6698.49 N 69.42 W .58 3329.41N 5882.18W 6758.87 N 69.42 W .75 3350.61N 5938.67W 6818.55 N 69.12 W .78 3371.66N 5994.29W 6877.38 12039 9011.85 8949.85 38 54 12132 9084.58 9022.58 38 12 12225 9157,66 9095.66 38 12 12318 9231.14 9169.14 37 24 12349 9255.77 9193,77 37 24 THE CALCULAT THREE-DIM N 69.22 W .54 3392.54N 6049.16W 6935.49 N 69.02 W .76 3413.20N 6103.31W 6992.86 N 68,42 W ,40 3434.07N 6156,90W 7049,84 N 67.92 W ,92 3455.26N 6209,82W 7106.38 N 67.92 W ,00 3462.34N 6227.26W 7125.07 ION PROCEDURES ARE BASED ON THE USE ENSION MINIMUM CURVATURE METHOD. HORIZONTAL AT NORTH 60 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 299.07 DEG. DTSPLACEMENT = 7125.07 FEET JUN 1 5 1993~ DEG. 55 MIN. WEST AT MD = 123,4A~aska Oil & Gas Cons. Commission Anchorage $~RRY-SUN DR]'LLZNG SERV]'CES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRZLLZNG PBU/3-25A 500292102101 NORTH SLOPE COHPUTATZON DATE: 3/24 /93 DATE OF SURVEY: 032393 JOB NUMBER: AK-EI-30016 KELLY BUSHZNG ELEV. = 62.00 FT. OPERATOR: ARCO ALASKA ZNC ZNTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDZNAT NORTH/SOUTH EAST/WE ES MD-TVD VERTZCAL ST DZFFERENCE CORRECTZON 8800 6690.00 6628.00 2590.00 N 3947.00 -W 2110.00 9800 7392.75 7330,75 2850.86 N 4603,69 W 2407.25 297,25 10800 8094.58 8032,58 3089.88 N 5273.92 W 2705,42 298.17 11800 8827.74 8765.74 3338.59 N 5906.65 W 2972.26 266.85 12349 9255,77 9193,77 3462.34 N 6227.26 W 3093.23 120.96 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-D~MENSZON M~N~MUM CURVATURE METHOD. ?~"~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/3-25A 500292102101 NORTH SLOPE COMPUTATION DATE: 3/24 /93 DATE OF SURVEY: 032393 JOB NUMBER: AK-EI-30016 KELLY BUSHING ELEV. = 62.00 OPERATOR: ARCO ALASKA FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/NEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8800 6690.00 6628.00 2590.00 N 3947.00 W 2110.00 8902 6762.00 6700,00 2634.83 N 4003,75 W 2140.11 30.11 9043 6862,00 6800,00 2680.97'N 4092.35 W 2181.59 41.49 9186 6962,00 6900.00 2715.10 N 4188.16 W 2224,23 42.64 9328 7062.00 7000.00 2746.89 N 4284.34 W 2266.59 42.36 9469 7162.00 7100.00 2776.51 N 4378.41 W 2307.04 40.45 9612 7262.00 7200.00 2808.50 N 4476;06 W 2350.43 43.39 9755 7362.00 7300.00 2840.84 N 4573.29 W 2393.61 43.18 9900 7462.00 7400.00 2873.63 N 4672.84 W 2438.48 44.86 10046 7'562.00 7500.00 2907.29 N 4774.01 W 2484.66 46.18 10193 7662.00 7600.00 2941.05 N 4876.06 W 2531.47 46.81 10338 7762.00 7700.00 2974.82 N 4975.09 W 2576.21 44.74 10479 7862.00 7800.00 3008.84 N 5069.56 W 2617.93 41.72 10618 7962.00 7900.00 3044.36 N 5159.08 W 2656.78 38.85 10755 8062.00 8000.00 3078.99 N 5246.12 W 2693.80 37.03 10891 8162.00 8100.00 3112.40 N 5331.44 W 2729.44 35.63 11028 8262.00 8200.00 3146.67 N 5418.30 W 2766.26 36.82 11165 8362.00 8300.00 3181.20 N 5505.63 W 2803.44 37.18 11302 8462.00 8400.00 3215.91 N 5593.31W 2840.89 37.45 11440 8562.00 8500.00 3251.34 N 5681.60 W 2878.91 38.02 11578 8662.00 8600.00 3286.82 N 5769.57 W 2916.75 37.83 11713 8762.00 8700.00 3318.64 N 5853,48 W 2951.13 34.38 11844 8862.00 8800.00 3348.77 N .-'5933.76 W 2982.86 31.74 11974 8962.00 8900.00 3378.18 N 6011.38 W 3012.82 29.96 12103 9062.00 9000.00 3406.84 N 6086.72 W 3041.27 28.45 12230 9162.00 9100.00 3435.32 N 6160.08 W 3068.52 27.25 12349 9255.77 9193.77 3462.34 N 6227.26 W 3093.23 24.71 THE-CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-6-93 REFERENCE: ~ / */1-24A 2-7-93 ~/' 01/3-20 4°6-93 ARCO CASED HOLE FINALS 22 0A 4-13-93 0A 4-28-93 4-23-93 4-23-93  4-16 TX-?~ 4-18-93 -10 ~Z~ ~ 1-2-93 -~s ~.~ 4-=o-~s -12A ~ ~ ~ 4-19-93 ~6-12A ~' . ~ 4-24-93 ~'~-- **~2-148T F/~/~14-27-93 ~e-=o~-~? 4-=5-e3 ~13-25 C2-~/ 12-26-93 ~-43 ~-/or 1-3-93 ~6-27 ~. ~g 12-27-92 ~7-13 ~-~7~ 4-18-93 Please sign and GR/CCL/Jewelry/Temp Run 1, Tubing Cutter Run 1, 8BT/GR/CCL Run 1, Perf Record Run 1, Jewelry/GR/CCL Tie-In Run 1, CNL/GR Color Run 1, USIT/GR Color Run 1, Leak Detect Run 1, Static Press/Temp Run 1, Leak Detect Run 1, 2"&~' Prod Profile Run 1, 5" Production Log' Run 1, Pressure Build-Up Run 1,. Press/Temp Run 1, Perf Record Run 1, Production Log Run 1, r'&5,' Dual Burst TDTP (Borax] Run 1, Perf Record --. Run 1, PFC/GR (Packer Set] Run 1, InJ Profile Run 1, Leak Detect Run 1, Leak Detect Run 1, Leak Detect Run 1, InJ Profile Run 1, Prod Profile Run 1, Prod Profile Run 1, :r'&5" Leak Detect Run 1, 2'&5'' 8BT/GR/CCL Run 1, 2'&5' RECEIVED Have A Nice Sonya Wallace ATO- 1529 as re~ of data. 93056~ # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # EXXON # MOBIL # PB WELL FILES. # BPX # STATE OF AI~KA The Co~ect wen name for this log is 1-24A. The correct APl# for 3-20A is 50-029-20980-01, The correct APl# for 12-14ST is 50-029-20659-00. Camco Atlas Atlas ach ach ach ach Camco ach ach Camco ach ach 8ch ach Atlas Camco Camco 8ch ach Camco Camco Camco ach Atlas ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-6-93 REFERENCE: ARCO CASED HOLE FINALS ~'--3-18A ?~-~/~ 4-30-93 3-25A ~~ 4-26-93 3-25A 4-26-93 3-31 ~ ~-? ~ ~2~93 ~ F~ ~ ~2~93 ~13 ~ o~3~. ~27-93 ~-~ ~1-93 ~~ ~93 -3~ ~- ~ ~2~93 ~3~ ~93 -I~T Completion l~_m 1, 5" Sch Peal Record Run 1, 5" Sch Jewelry/GR/CCL Tie-In lh_m 1, 5" Sch Leak Detect Run 1, l"&I~' 5ch Leak Detect Run 1, 1"&2' Sch Dual Burst TDTP (Borax) Run 1, 5" Sch Production Log Run 1, 5" Sch TDTP (Borax) Run 1, 5" Och CET Run 1, 5" Sch PITS Run 1, 5" Sch Static Pressure Survey Run 1, 5" Sch Compensated CBT Color Run 1, 5" Sch USIT Color Run 1, 5" Sch Completion Run 1, 5" Sch Completion Run 1, 5" Och PITS Run 1, 5" Sch PITS Run 1, 5" Sch PITS Run 1, 5" Sch Please sign and retur ~ attac~/g~py as receipt of data. RECEIVED BY'~~~_i~~,~ Have A Nice Day! Sonya Wallace APPR OVED__~/J2/___ ATO- 1529 Trans# 93058 # CENTRAL FILES , ~ C/].~PHILLIPS # CHEVRON 4/,~,~ ,~r47. ~' ~.},p WELL FILES D&M ~ O/?~ /0 /~0^_ # CLU~? CHaPMA~ } % ~ ~d# BFX # EXXON **°~o~'°~*~~ Co,,,, # STATE OF ~KA MARATHON -~s ,~r%%TEXACO,~ # MOBIL ARCO Alaska, Inc. P.O.Box 100360 Anchorage. Alaska 99510 DATE: 4-29-93 REFERENCE: ARCO 4-13-93 SSTVD 4-13-93 DLL/GR/SP 4-13.93 BHCA/GR 4-13-93 CNL/GR 3.23.93 SSTVD 3-23-93 DLL/GR/SP 3-23-93 BHCA/GR 3-23-93 CNL/GR 3-23-93 BH Profile 3-31-93 DLL (Simultaneous) 3-31-93 BHCS/SSTVD 3-31-93 BHC8 3-31-93 CNL 3/26-31/93 MWD: DPR/GR 3/26-31/93 MWD: DPR/GR 4-17-93 SSTVD 4-17-93 DLL/GR 4-17-93 ZDL/CNL/GR 3/13-18/93 LWD: CDN Mad Pass 3/13-17/93 LWD: CDN Drilling Pass 3/13.18/93 LWD: CDR M~d Pass 3/13.17/93 LWD: CDR Drilling Pass 3/13-18/93 LWD: CDN N/F Mad Pass 3/13.17/93 LWD: CDN N/F Drilling Pass 3/13-18/93 LWD: CDN Mad Pass TVD 3/13-17/93 LWD: CDN Drilling Pass TVD 3/13-18/93 LWD: CDR Mad Pass TVD 3/13-17/93 LWD: CDR Drilling Pass TVD 4-6-93 SSTVD 4-6-93 DLL/GR 4-6-93 BHCA/GR 4-6-93 CNL/GR 4-6-93 f ~ .... 4 Arm CSI/GR (BH Profile) 3-19-93 ~ Induction Electrolog 3.20-93 CNL/GR 4-20-93 DLL/MLL/GR/SP/CSI 4-20-93 BHCA/GR 4-20-93 BH Profile 3-28-93 $STVD 3-28-93 DLL/MLL/GR/CSI 3-28-93 BHCA/GR 3-28-93 BH Profile Run 1, l"&2" Run 1, 2"&5~ Run 1, 2"&5~ Run 1. Run 1, l"&2~ Run 1, 2"&5" Run 1, 2"&b"" Run 1, Run 1.5~ Run 1. 2"&5" Run 1. ~' Run 1, 2"&5" Run 1, 2"&5" Runs 1-3, 2"&5'~MD Runs 1-3, 2"&5'~rVD Run 1, Run 1, Run 1, Composite, 2"&5" Composite. ~'&5" Composite. 2"&5" Composite, 2"&5" Composite, 2"&5" Composite. Composite, Composite. Composite. 2"&5" Composite, Run 1, 1"&2' Run 1. 2'&5' Run 1, 2~ad$" Run 1, 2'8~' Run 1, 5" Run 1, 2"&5" Run 1. Run 1, 2"8u5' Run 1, 2'&5" Run 1, 5" Run 1, Run 1, 2"&5" Run 1, 2"&5" Run 1, 5" Please sign and return ~/e attach~d~copy as receipt of data. RECEIVED BY___~_____~~~ Have l Nice Dayl ff~ Sonya Wallace 93051 ATO-1529 ~PPROVED CEnTRaL F ES 0 6 1993 . PmuaPS CHEVRON ~ PB ~LL ~ D ~ M ~ Oil & ass Cons. Commis;i~ c~ c~ Anchoraoe ~ON t STATE OF ~~ MOB~ t T~CO Atlas Atlas Atlu Atlas Atlu Atlu Atlu Atlu Atlas ach ach ach ach Teleco Teleco Atlas Atlu Atlu 8ch 8ch 8ch ach ach ach ach ach Atlu Atlu Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas Atlas * The lo~s for tht~ well all say field, but are actual~ .finals. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-29-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS tClVI~lCNIOI~ ~Sll)~l~ m,I~IAClC~IC~I4 Cai DPR/Den Poro/GR ~)~I~/a~/ACiOI~ Run I Job#5914 Atlas Run I Job~93152 Sch Run I Job#5923 Atlas l~_m I Job~5749.01 Atlas Run I Job#1155 Teleco Rrm I Job#5918 Atlas Have A Nice Dayl Sonya Wallace ATO-1529 APPROVED_ffff~ Trans# 93052 CENTRAL FILES (CH) CHE~ON D&M # BOB OCar~aS (OH/OCr) # EXXON MARATHON MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: David W J~ date: Chairman ~ file: thru: Blair E Wondzell '~-0-~"~' subject: Sr Petr Engineer from: 'Bobby Foster Petr Inspector March 25, 1993 031393.doc BOP test - Doyon 16 AAI PBU DS 3-25A Permit #93-23 Saturday, March 'J~A" 1993: The BOP test began at 2:30pm and was concluded at 5:30pm. There was one (1) failure. The flange between the bottom pipe rams and the mud cross leaked. This was tightened and retested. The rig was clean and the equipment was in good working order. The location is a bit close due to this being a large producing pad and a lot of wire line in progress. There were 3 wireline units on this pad. Summary: I witnessed the BOP test on Doyon 16. Test time was 3 hours with one failure. attachment STATE OF ALASKA OIL AND GAS ""'"'"""~ ~"'" '"'"""'"'" DOPE Test Report OPERATION: Drtg' / Workover: DATE: 'Nell Marne: ~ 5. ~.~--- ~1~ pmt.~ ~-~ Rig ph,~ _7A/ C6 .... ' .... Drlg ContractOr:casing. Size: ~b~~ ............... Rig No./~ Rep.: _~~ ~~ ---~"~'.'~'.~']~' ~ ~ Z setr~ ~ ~__~'7 ......... Location; Se~ 'T. '/~- R.' ~Meridian~ InitiAl- ' Weekly Other Test: ~-' ' ..... ' .......... Test BOP STACK: Ann. Preventer Pipe Rams Blind Rams ChldLn Valves HCR Valves Kill Line Valves Check Valve MISC. INSPECTIONS: Location Gen.: J Welt Sign Housekeeping:Reserve Pit ~(Gen).,. Drl, Rig Qua, Pressure PIF .__1 1 2_5'0o, I,~ t' I.~o MUD SYSTEM: Visual Alarm Trip Tank Pit Levet Indicators ~ -~,,-'~' FIow tncticator FLOOR SAFETY VALVES: Quan. Pressure P/F Upper KELLY! IBOP Ball Type Inside BOP ../_J_.__~,?~. _o_.~_ ' .......... · CHOKE MANIFOLD: No. Valves NO. Flanges Manual Choke~ Hydrauli~ Chokes ACCUMULATOR SYSTEM: System Pressure _~ ),OO ........ J Pressure After Closure j q b0. ,, 200 psi Attained After Closure - minutes,~;~.~iec,. Sys,'em Pressure Attained __.~..._ minutes ~ Blind Switch Covers: M~ter: _~ Remote: ..t..~'. Nitgn, Btl's: ,~ ,.re ~..¢~0. /e~ Gas Detectors ~ _~.~.'. ~ ~'~'~ ..2 ~¢¢-~ .- , .... , .... Psig, , ,, Equipment shall be made wi~in ~ days. No~ ~e Inspector on du~ and follow ~th Wri~en or Faxed verification to the AOGCC Co~is~ion Office at: Fax No.: 276.7~2 inspector No~h Slope Pager No. 6~9-360T If your call is not returned by ~e inspe~or ~min 12 hour, please con, ct ~e P. I. Supe~sor al 279,1433. Distribution: orig-Welt File ¢ ~ Oper,tRig ¢. Database c. Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES NO 24 HOUR NOTICE GIVEN YES NO ~ Waived By: Witnessed By: WALTER J. HICKEL, GOVERNOI~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 February 26, 1993 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit DS 3-25A ARCO Alaska Inc 93-23 1014'NSL, 29'WEL, Sec. 10, TiON, R15E, UM 4364'NSL, l192'WEL, Sec 09, T10N, R15E, UM Dear Mr Zanghi: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated February 12, 1993 are in effect for this revision. Sincerely, Chairma B~ O]~D~R OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section, w/o encl Dept of Environmental Conservation w/o encl STATE OF ALASKA ~---~. REVISION #1 ALASKA ~,'-- AND GAS CONSERVATION CO~,... ;iSSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill I;'lllb. Type of well. Exploratoryr"l Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-I11 Service I-1 Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) :10. Field and Pool ARCO Alaska, Inc. KBE = 62'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 19G612. Anchoraae. Alaska 99519-6612 ADL 28328 4. Location of well at surf-ace 7. Unit or property Name !11. Type Bond(me 20 ^^c 25.o2s) 1014' NSL, 29' WEL, SEC. 10, TION, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 4328' NSL, 514' WEL, SEC. 9, TION, R15E, UM 3-25A U-630610 At total depth 9. Approximate spud date Amount 4364' NSL, 1192' WEL, SEC. 9, TION, R15E, UM 3/21/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28329-4086 feet No clr, se Approach feet 2560 12506' MD/9172' TV/]eet 16. To be completed for deviated wells 17. Anticipated pressure (s~e 20 AAC 25.035 (e)(2)) Kickoff depth 98~ofeet Maximum hole an~le~o.80o Maximum surface 3330pslg At total depth (TVD) 8800'/4390pslg 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) 8-1/2" 7" 29# 13CR/ NSCC/ 2411 10095' 7630' 12506 9172' 498 sx Class "G" NT-80 NSCC 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12265feet Plugs (measured) true vertical 9229 feet Effective depth: measured 12216feet Junk (measured) Alaska 0il & Gas Cons. 00mm'tss~( true vertical 9194 feet Anchorage Casing Length Size Cemented Measured depth True Vertical depth Structural C o nd uct o r 80' 20" 2020# Poleset 80' 80' Surface 2538' 13-3/8" 2575 sx CS III/ 2538' 2538' Intermediate 400 sx CS II Production 11234' 9-5/8" 5oo sx "G"/305 sx CS / 11234' 8505' Liner 1311' 7" 425 sx "G" 12258' 9224' Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify/that the foregoing is true and correct to the best of my knowledge _ ,~ ,.-,~ Dat(~'/' 7 S,,~]ned y(" ~ Title Drilling Engineer Supervisor "-" )/,~ Commission Use Only Perm~ !~umber_,.'"" IAPi number .... IApproval date ..., ISee cover letter I Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required l~l Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey requ~reo [] Yes [] No Required working pressure for BOPE []2M; 1-13M; 1-15M; !-]10M; !-]15M; Other: Origina! ~ned ~Y by order of Approved by David V'.~ Johnston Commissioner ,ne comm,ssion gate~l~G/~r.5 · .. Form 10-401 Rev. 12-1-85 Submit in triplicate OBJECTIVE: The DS 3-25A objective list is as follows: · Permanently abandon the current wellbore and pull tubing string. · Optimize Victor oil production that is currently hampered by the nearby fault/graben configuration. · Obtain open hole Icg information for completion strategy and correlation to surrounding wells. · Install chrome tubulars and liner. CURRENT STATUS: · Produces 70 BOPD, 3700 BWPD (98%WC), and 650 GOR. · Well is currently amidst a complex fault/graben system and the bottom hole location is at the intersection of two of these faults. It is possible that water is funneled to the wellbore along these faults. · Historically, a channel from the Zone 3 conglomerate down 70 feet had been the source of high gas production prior to waterflooding and is now a likely source for the high watercut. · Two WSO squeezes have been performed with limited success. PERMITTING: A sundry notice covering the plugback of the original well has been submitted. The attached drilling permit covers the proposed drilling program for the redrill. REEEIVED FEB 1 9 199,l Alaska 0il & Gas Cons. CommisSiOn Anchorage DS 3-25A AFE SUMMARY PROCEDURE . . 3. 4. 5. . 6a. 7. . . 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 5-1/2" tubing at 10.000' MD. Freeze protect. MIRU workover rig. Test 9-5/8" packoff to 3500 psi. Pull BPV. Circulate out freeze protection fluid. Set two-way check valve. ND tree. NU BOP's. Test BOP's to 250/5000 psi. Test annular to 250/3500 psi. Pull two-way check valve. Pull and lay down ~;-1/2" tubing. RIH w/9-5/8" bridge plug and set at 9950' MD. Spot an 18 ppg mud pill on bottom. RIH with a 9-5/8" section mill and cut a 50' section in the 9-5/8" casing starting at +/- 9800' MD. RIH with open-ended DP. Mix and pump 150 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. Replace intermediate packoff if necessary. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below the section. Kickoff the well and directionally drill to align well with the target. Drill with a 8-1/2" packed hole assembly to total depth of 12506' MD / 9172' TVD or 150' MD below the HOT at-9110' ss TVD. RU wireline and log with the DLL/GR / SP / Sonic. Make a second logging run for the Numar MRIL log. Make wiper trip depending on hole conditions and logging time. Run 7" 29# 13CR NSCC x 7" 29# L-80 NSCC standard liner assembly to TD with liner top packer/hanger and tie-back extension w/+/- 150' lap. Crossover from 13CR to L-80 at 11.302'MD. Cement liner with 42[; sacks based on 40% open hole washout, shoe volume, lap volume, and 200' excess on top of liner with DP. Clean out liner to PBTD and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. Circulate corrosion inhibitor down the annulus. RIH with 5-1/2" 17# NSCC 13CR80 xo to 4-1/2" 12.6# NSCT 13CR80 completion string w/_7" packer. Space out, land completion, and set packer at 11.402' MD based on end of tubing at 100' above tOD of Sadlerochit marker. Test down tubing to 4000 psi. Test tubing x casing annulus to 3500 psi. Set two-way check valve. ND BOP's. NU and test the 5M tree to 5000 psi with diesel. Pull two way check valve. Shear RP valve and freeze protect. Set BPV. Release rig. RU wireline and perforate. RECEIVED FEB 1 9 199,~ Alaska 0ii & Gas Cons. Commission Anchorage PRELIMINARY WELL PLAN WELL: APl NO.: LOCATION: ESTIMATED OPR. DAYS TO COMPLETE: 3-25A Redrill PBU 50-029-21021-00 (on the original 3-25 well) Surface: 1014' FSL, 29' FEL, Sec. 10, T10N, R15E Target: 4328' FSL, 514' FEL, Sec. 9, T10N, R15E @ 8540' ssTVD BHL: 4364' FSL, 1192' FEL, Sec. 9, T10N, R15E @ 9110' ssTVD START: March 1, 1993 18 (6 days prep & mill, 7 days drill, 5 days complete) CONTRACTOR: Doyon Rig #16 DIRECTIONAL: Kickoff at 9850' MD. 8.98° angle build and 39.74° CCW turn. WELLBORE: Item 20" CONDUCTOR 13-3/8" SHOE KOP TOP SAG RIVER SANDSTONE TOP SADLEROCHIT TOTAL DEPTH TVD(ss) MD(BKB) Mud Wt. 48' 110' N/A 2451' 2538' N/A 7381' 9850' 9.8 ' ' 10.0 8540' 11,602' 10.2 9110' 12,506' 10.2 LOGGING PROGRAM: 8-1/2" Hole: GR / DLL w/microresistivity / CNL/Density Numar MRIL on Atlas wireline REEEIVED FEB 1 9 t99;~ Alaska Oil & Gas Cons. Commission Anchorage MUD PROGRAM: The milling/drilling fluid program will consist of a 9.8 ppg XCD polymer / KCI water based mud in the 8-1/2" hole. DEPTH DENSITY PV YP INT (TVD) (PPG) (CP) (#/FT) GEL 7443' 9.8 10 10 5 7 6 to to to to to · to to 9172' 10.2 16 18 10 15 3 10MIN FL OIL SOLIDS MUD GEL cc/30min (%) (%) TYPE 0 5 Water to to Base 0 9 Mud MUD WEIGHT CALCULATIONS / WELL CONTROL: Mud Wt. (8-1/2" Hole): 9.8 - 10.2 ppg. Est. Pore Press. Sag River: Est. Pore Press. Sadlerochit: 4059 psi/8798' ss TVD 3500 psi/8800' ss TVD. Overbalance Sag River: 424 psi. Overbalance Top Sadlerochit: 1180 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC- 2A. REE'EIVED FEB 1 9 t99,,t Alaska 0il & 13as Cons. Commissiot'~ Anchorage LINER DETAILS: CASING DEPTH BURST COLLAPSE TENSILE 7" 29# 13CR80 NSCC 12,506'- 11,302' MD 8160 psi 7" 29# NT80SS NSCC 10,095'- 11,238' MD 8160 psi 7" X 9-5/8" Liner Hanger and Liner Top Packer @ 9650' MD 7030 psi 676 klbs 7030 psi 676 klbs CEMENT CALCULATIONS: 7" Liner Measured Depth: 9650' MD (Hanger) - 12,506' MD (Shoe) Basis: Total Cement Vol: open hole 40% open hole excess 40' shoe joint 150' of 7"x9-5/8" annulus 150'. above liner top 2856 x 0.0226 = 64.5 x 0.40 = 40 x 0.0372 = 150 x 0.0256 = 150 x 0.0489 = 64.5 bbls 25.8 bbls 1.5 bbls 3.8 bbls 7.3 bbls 102.9 bbls 578 cuft or 498 sxs of Class G blend @ 1.16 Cu ft/Sk TUBING DETAILS: 5-1/2" 17 # 13CR-80 NSCC (0'- 9600' MD) 4-1/2" 12.6 # 13CR-80 NSCT (9600' - 11,502' MD) REEEIVED Alaska 0il & Gas Cons. Commission N~cherage L~2~-D DIRECTIONAL DRILLING, Corporate Office 1111 Ea$~ 80th Avenue Anchorage, ~J< 99518 (907) 349-4511 Fax 349-2487 DIRECTIOI~AL WELL PL~ for PRUDHOE BAY DRILLING well ......... : DS 3-25k (P3) Field ........ : PRUDHOE BAY DRILL SITE 3 Computation..: MINIMIZ~ CURVATURE ~its ........ : FEET Prep~z~d ..... : 02/09/95 Section it... : 273.06 KB elevation.: 62,00 LEGAL DESCRZPTION Surface ...... : 1014 FSL 29 FEL S10 Tie-in ....... : 4097 FSL 4510 FEL Targe~ ....... : 4328 FSL SI4 FEL S09 T!0N ~15E UM BHL .......... : ~364 FSL 1192 FEL X ASP ZONE 4 Y 713241.72 5937052.12 708670.25 707380.00 5940205.00 706701.51 5940222.57 WELL PROFILE STATION MEA$ iNC~ VERT-DEPTHS IDENT~FiC~.TIO}~ DEPT~ D~GLE BKB SUB-S · TiE- IN SECT D/ST 9850 41.9~ 7443 7381 ~6~5 ~900 42.04 74~0 g415 4671 i0000 ~2.53 7554 7492 4727 10!00 43.32 7627 7565 47S7 DIRECTION EEL- COOkOI NA'3ES AZIMIJ~ FROM-WELLKEJ~ S12.S0 30~3 K 4487 298.15 2180 N 4624 292.59 3210 N 4687 ~0~00 47.27 753~ 777? !0500 4~.0~ 7~06 7844 i05~4 50,B9 7~66 ?~04 5i26 252,17 32~2 N 6824 272.06 3313 I'~ 5750 12506 50.8~ 9%72 9110 6617 272.06 3323 N 5750 273.06 3314 N [U72 273.06 3351 I{ 6450 DL/ <T~E qo0 ~.0 4 , 0 4.0 C,0 0.0 O.O 11313 {c)~- D$325A 2!.40 10:!~ J~J~ 2~ RECEIVED FEB 1 9 199 Alaska Oil & Gas Cons. Commissit:,~ Anchorage 9600 PRUu'HOE BAY.,DRZLL,,~NG ...... ] A} TIE-IN 9850 74a3 4645 4~.§1 _ BI END OF CURVE i0594 ?956 5~36 50.89 CJ TARGET BJ TO ~2506 9172 66!9 50.89 Section at: 273 6 [~U ITVD Sca:re.: J inch = ~200 fee~B iDep Scale: :~ inch :t200 ¢~e~ I 9 199~ ..:;%7'-- , !~ '[',. !1.:: ~ ~ " ~ .I... Anchor&o )o-- Ii : ~! ; ~.'l i' i' ', .---'~ [ ...... g '-'~' : i' ; I~--'l.: .!: "- ;il ..... !._j.. I Spear land ~.~'~c~ona; Dr'J')]jn .... :!:;:-.::i: ' i I" ': ;. -':'[" h ', i'- i __ . i i " ' ~ ~ · )o ' "' ' 'i I , : ll · _t I t ,-';'/ . ~_ . ~ ~ , . , /... ' : I ' :I t i I . ~ t '" I I ~ I I'~'- ' ~ , t , I 'i "r,- ! " ,. i I !" i '- ; .----~--=. - ~li ::"' .! ....... !-,.. /... ; I' ::" ,.' : --- -lt.. ''~ ..... ~'~'-: ' . .... ~-I ~ ! ! .... ' : ' .. ' ' I/ ~ ,o_q · ,,, : . ..... II I ' : -:- ', ,. . !-':'~ ....... ,. ,.: ! ,, ..... It .' ":' ' ....... .' I' -i :. ' ..... [: .... ! , ' '~'. I , , - ! "' I · ... I i "i : - ~ ' I I ~ ! I ~ / I J t ! '" ; J I iI "', ; ! i '7" : '- , ~ ..... . ~ ....... I -~ , - [ .. I , T ......... I ~; I i ] . o.-, : ,'-.,, .. .- -., I . .. ,',,, ,. , .... . f , , . t .-. . .... , , , . . .,1 ..... ~ ........... I . . , ._L , ,~,1: , - ..... , ..... , · ..... ' '~ ; ~ .... '"ti t . , ' u-- ' , "T;,! j ' . 'F", , . I , , ~ ..... ~ , . "-' ; ,, i ~ r-- ~ it ' i! ~[Il " , , . ~ :--~ ' -'i ii i~ , t:..... · ~ ., , ..-1.--. , ~ ........ .. . : ,. , ' ' ~ '-- .-- , , ~ ~ , ~ ~. ' ~ I ; i : Ir ' ~ i .... "'" 'I ...... --" ~ ' ' I '*"' ' i ' ~ i ~ : ~' ..... '~ ' F-' '' i .... . ~ ; , '~' '-' '':;: ::, ,' "~--1!~, .~,' ;I: ' '', ~ ~ ~; ; ..... ' : ~. '~..1 ~ "...'_,:.~..:"~'"' ~ : ! ~ ~ ~ ~..-~J . ..,, ~ .~...I.! .l..! ; ',-t I I I : '. iI~ ....... i ..... ~ '- I ' -- - ~ , . ~ i .... ~ , : , . .~-!-.t-.r--i" , , , -.7 ., -t .... - .,......, : ' , -t.,... _: . ..-_~ --' ,..Ii +I~' I~., I-~ l":i-~ ,, :i z..: ':'..~ ,, : d.., - ~J ~ =! ! ! .t.,-~ ! ! : ' [--. I !' ! t_; , i : ( ; t J ...... ~ , ~ ~ ·: :''r- . *, , ,.'- i ~ ' . ~ ' ' ', [ , , ' ' , : '.';i'"i i , ..- .~ ,:!-,, ;" ~I' ' ~'- . ', ~-,,' ' ' '~ ' 'tl , .-I,, .;-~. , ...... f, , .... . . .,, ,,, ...,. . .., · .Il' I ' ' .... ~ ~" )-- , , ~, '' , .J I .' ._~ ',: ~ '~-"l '-~~--'~ , " !~; *' '. ' ''.--: ,.--- : -! ..... ?,_ F ~ ..... ].!'' - '' i., ..... ~~1 _ .:. .:: ,, .-- .... ! .:~ ~ "1 }'.I'Ii --I .- : } : · / ..-~ :, !!~.~.I "1...~-'!!i ,"-~ 1'-~_."-~: ~."-~- --- ' ~ ' I I'1.11 ' i 4, ' ' ' ' '/ ' '.~ . · ~ t ' I ' ' '{ · ! ~ -, : . . ~, 'j , ~ ~ . ; . -: ] .... '' , I I I .......... , '' '. · ,, ,,,,' , '1 .- ,.~ .... ,., ..., ~: ... :...,, ,.: '':'''''-'' .,, . , ,.. i.i , .., .,. '----".. ..... · t ,. --. :--'-:--'-,, -'---: ,. .... ..... .,_ ? 1.. -- ~'3 ' ~ i , i ''' :~' I ~ : ...~ i : , ' I · 7 i I~ '[ -'-:-'~ :"'! " .... , ., ~ ~ : ....... %. -~~,~', ~,~~:~Ft ',-l~-~.~.l!';l.~ . . . 'i !"~'---~---"~lt'~~"l--~-.~~! ':t ~. ~'I' :-I i'-ii'-~..~'~. ,~.~"2~'--~ 0 500 l~O0 '!BO' ,-- ' ~ ' ~ ' ~7 ' ~ 0 2400 3000 3sO0 4200 4800 5400 6000 6500 7aO0 7800 Section Departure 05525A B~.4O ~0: ~ A~ 2] i011 Marker Identification ~) lIE-IN ENO OF CURVE TARGET O) TO 8800- gO00-~'- : : 9200-J '-PRUuHOE "BAY DR I L L1 NG MD BKB SECTN INCLN g850 7443 4645 4J.g~ 10594 7966 5136 50.89 ~]602 8602 5gJB 50.89 ]2506 9~72 6629 50.89 L.. DS 3-25A (P3) VERTICAL SECTION VIEW RECEIVED TVD Scale.' J inch : 400 feet Der Sca]e.' J inch : 400 feet FEB 1 9 199,3 Drawn ' O2/Og/g3 Alaska Oil & Gas Cons. .... A.u[~vraoe ' Great Land DJrectJona] [~_8D (c)~-2 D~325A BI .40 :~0; 3! AW, Q- r.__L_ : ' I i i _bOu , ;, I : !"1 ' , : ', '1 i : ~ :' : -' ! : ! ~' ! ,, ,,' ' I ". if--r $ ' :~' : "~ , ~ . i ~"~ '. ~ ': ~ ~ ~ ' ~.~. ::~., ~,:,, ,., ::,~:'"i ~- ~ . r .:~'1~-z,I , r--:~-.-I~;~ ....t..~ :..., ,... .. ~....,u.. ~ ~J [- ~--,. ~~..: ~ ~000' a~ ~ ' ~ ~' r-',~ ;'' ::, i , "I i i :..~ j ) ! ~ J ~ '. i ~ : ~ ~_ ~ ' : "~ ~" "'-~t ~ i "~ ~ :"~ ' ~ ~'~ ': : ~ ~ :' ~.-~--~ .- i -.i ' ~.. · ~ ~ ' : ~ I' ~f"'~. 't~-~..~ ~ -..~.-':" ~,: : I... , ~_,.. J..'. .'J~l,, ..~ +- i~.:~ [~ .... ~,..- ~ .!-I.~.: ~, '":.r'~:~ ~'i.. ~ t. ,-~.~ ~:'~ :'1 ~-"'~ r~'~ ,I ~:, . ~.. ~ ...... I ' ~I ' ~ / ' ' / ~ I ' ~'- ' ~000 4200 ~00 ~500 4800 ~000 5200 5400 5600 5800 6000 6200 6400 6600 6800 Section Departure sio~ ~ PRODH Ms~'~.er Iden[ i f icat i o~ MD N/B E/bI At TIE-IN 9~F$ ~0~3 ~ 44~ ,, FEB 1 9 1BB~ 8J END ~ CURVE 10594 3271 N 4969 V,' ~ DS 3-25A (P3) PLAN VTEN i CLOSURE ' 7268 feet at Azimuth 297.~15 DECL]NATION,- 30.i7 E SCALE ' 1 inch : 800 feet DRAI~N ' 02/09/g3 6800 5400 60[1O 5.F,I)tl F.n,' ' (':1-qP. qS.¥'5,t §].40 ~0:3] ,f,K 2.1 ~600 1200 8(~.n 400 O 40¢  LendD~ MarKer Io~nti f i eat ion ND N/S E/W Al ITE-IN 9850 3083 N 4d67 8] Ek~ OF CURVE 1~594 3~7~ N ~969 C] IAHGET 11602 3313 ~.? 5750 DS 3-25A (P3) PLAN VIEN __ · CLOSURE · 7268 fee( ar. Aziauth 29?.45 I)ECL!N^TION.: 30.~7 £ SCALE · t inch = 300 feet EIR~,WN ' 02/09/93 3600 34 0 I) F 240 6900 6750 6600 6,15~ 6300 6]50 6000 5850 5700 5550 5400 5250 4950 4BO0 465~ 4500 4350 4200 <- ~ESF MUD & DOYON RIG #16 SOLIDS CONTROL EQUIPMENT _ _ _ _ _ _ _ Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console REEEIVED FEB 1 9 1993 Naska.0il & Gas Cons. 'Anchorage DOYON 16 ,, ~ 13 §/8" 5,000 psi Stack t 10.15 ,t 4.5 RKB HYDRIL ~FLO 12.40 ,R 15.40 5.02 1.02 1.80 2.35 GROUND LEVEL 0.25 I I Variable 3.5"x 6" Pipe Ram · I Variable 4.5" x 7L" Pipe Ram MUD CROSS Blind Ram 17.60 20.70 I24.85 TBG SPOOL TBG SPOOL BASE FLG ! 25.10 RECEIVED FEB 1 9 t993 Alask~ Oil & Gas Cons. commiSs'~o~ Anchorage Stste: Alaska Borough: VVeii: DS3--25A Field: Prudhoe Bay St. Perm ;93-2:3 Date 2_./24/93 E?ngr: M. Minder Casing ir~te.rval Interval Size Bottom Top Length IA 7 9172 7630 ?_411 2A 7 9172 7630 2411 3A 0 0 0 0 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 29 13CR-80 NOs% 0 29 NTSOSS NCSS 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 0 0 0 0 lB 2B 3B 4B 5B 6B 7B 8B 9B lOB Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/it psi/it 10.2 0.530 0.430 10.2 0.530 0.430 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 O. 0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi 13DF 3330 8160 3330 8160 0 0 #DlVi0! 0 0 #DiVlO! 0 0 #DIVIO! 0 0 #DIVi0! 0 0 #DlVl0! 0 0 #DIV/O! 0 0 #DlVi0! 0 0 #DlVlO! 1C 2C 3C 4C 5C 6C 7C 8C 9C 10C Tension Strength K/Lbs 69.919 69,919 0 0 0 0 0 0 0 0 K/Lbs TDF 676 9.67 676 9.67 0 #DlVtO! 0 #DIM/0! 0 0 ~D~/0~ 0 ~D~O~ 0 ~DIV~ 0 CDIV~! 0 ~DIVJO! Collapse Collapse P~Bo~Psi 3948 3948 0 0 0 0 0 0 0 0 Resist,, CDF 7020 1.778 7020 1.778 0 #DIVI0! 0 #DIVI0! 0 #DIVi0! 0 #DNIO! 0 #DIM/O! 0 #DlVl0! 0 #DIVI0! 0 #DIV/0! 3._¢_56 ~..M T.×LS State: 'v,/elk Field: State Permit Rudhoe Bay Engineer: Work Sheet: Date: Cement V~me Eblculalion,~ 2/24/$3 Casing Type Casing Size -Inches Casing Length - Feet Hole Diameter -Inches Cement-Sacks Cement-Yield Cement- Cubic ft~I1 Cement- Cubic ft Cement- Sacks Cement- Yield ~I2 Cement- Cubic tt Cement- Cubic ft Cement- Sacks ~I3 Cement- Yield Cement- Cubic t't ~3 Cement- Cubic [( ~3 Cement- Cubic tt /Vol Cement- Fill Factor Conductor 0.000 O. O00 0.000 0.000 0.000 O. O00 0.000 0.000 0.000 0.000 0,000 0.000 I~DIV/O! Surface 0.000 0.000 0.000 0.000 0.000 O. O00 0.000 0.000 0.000 0.000 0.000 0.000 0.000 O. O00 0.000 0.000 ~DIV/O! Liner 7.000 2,411.000 8.500 498.000 1.160 577.680 577.680 0.000 0.000 0.000 0.000 577.680 1.890 Casing Type Casing Size Casing Depth Hole Diameter Cement- Sacks Cement- Yield Cement- Cubic ft Cement- Cubic it Cement- Sacks Cement- Yield Cement- Cubic fi. Cement- Cubic tt Cement-Sacks -inches - Feet -Inches ~I1 t~1 ~I1 ~I2 ~I2 ~t2 ~I3 Cement- Yield ~I3 Cement- Cubic tt ~I3 Cement- Cubic It Cement- Cubic tt / Vol Cement-lntewai Top of Cement- Feet Intermediate 1:11 0.000 O. OOO O. O00 0.00 0.00 O. O0 0.00 OO0 0.00 O. OO O. O0 0.00 0.00 0.00 0.00 0.00 I:IDIV/O! I:[:DIV/O! intermediate ~12 0.000 0.000 8.000 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/O! ~BIV/O! Production 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 ~IOIV/O! :M:DIV/O! ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276--7542 February 12, 1993 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re .' Prudhoe Bay Unit DS 3-25A ARCO Alaska, Inc. Permit No. 93-23 Sur. Loc. 1014'NSL, 29'WEL, Sec. 10, T10N, R15E, UM Btmnhole Loc. 4622'NSL, 1052'WEL, Sec. ~9 T10N, R15E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDgR OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~O) printed on recycled paper b y STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COJv, MISSION PERMIT TO DRILL 20 AAC 25.005 !la. Type of work Drill [] RedrillElJlb. Type of well. Exploratory[] Stratigraphic Test[] Development OilE] Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) I10. Field and Pool ARCO Alaska, Inc. KBE = 62'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28328 4. Location of well at surd'ace 7. Unit or property Name :11. Type Bond(see 20 ^^c 25.025) 1014' NSL, 29' WEL, SEC. 10, TION, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 4526' NSL, 324' WEL, SEC. 9, TION, R15E, UM 3-25A U-630610 At total depth 9. Approximate spud date Amount 4622' NSL, 1052' WEL, SEC. 9, TION, R15E, UM 3/21/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28329-4226'feet No close Approach feet 2560 12467' MD~9110' TVDfeet 16. To be completed for deviated wells 117. Anticipated pressure (s~, 20 AAC 25.035 (e)(2)) Kickoff depth ~o2sofeet Maximum hole angles2.~° IMaximum surface 3330psig At total depth (TVD) 8800'/4390psig 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) 8-1/2" 7" 29# 13CR/ NSCC/ 2372' 10095' 7630' 12467' 9172' 425 sx Class "G" L-80 NSCC 19. To be completed for Redrill, Re-entry, and Deepen Operations. ["~'"d~ '-" _ Present well condition summary ~i.' "~. "~ ~'~.,;: .[,;oi'~s,. Total depth: measured 12265feet Plugs (measured) Aiask~ Oit ¢,,.;a,, · true vertical 9229 feet Effective depth: measured 12216feet Junk (measured) true vertical 9194 feet Casing Length Size Cemented Measured depth True Vertical depth Structural C o nd uct o r 80' 20" 2020# Poleset 80' 80' Surface 2538' 13-3/8" 2575 sx CS III/ 2538' 2538' Intermediate 400 sx CS II Production 11234' 9-5/8" 500 sx "G"/3o5 sx cs / 11234' 8505' Liner 1311' 7" 425 sx "G" 12258' 9224' Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl :Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements I-! 21. I hereby certify, that the. foregoing is true and correct to the best of my knowledge Signed ~J~,¢ ~. Title Drilling Engineer Supervisor Date Commission Use Only Permit ~.~ - .¢_ ..~Number "' 1AP I ~ 5 0 - O .;7.. ~ - .2. / O.2./--' ~/numberI'AP ,~,o valj d~ate ....c~_~y ISee cover letter -- Ifor other requirements Conditions of approval Samples required [] Yes ..E~'No Mud Icg required es ~ No Hydrogen sulfide measures [] Yes ~' No Directional survey requ~recl ~ Yes [] No Required working pressure for BOPE [] 2M; 1-13M; J~SM; I-I10M; r-115M; Other: Original .Signed By by order of Approved by I3~/id W-,iohnstort Commissioner the commission Datec,~-,/;~' Form 10-401 Rev. 12-?-~; Submit in trit STATE OF ALASKA '- ALA: . ~ OIL AND GAS CONSERVATION COMMISSI, APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend ~ Operation Shutdown__ Re-enter suspended well __ Alter casing Repair well __ Plugging X Time extension __ Stimulate ~ Change approved program ~ Pull tubing ~ Variance Perforate~ Other X ~ Plugback for Redrlll 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory __ Stratigraphic ~ Service 6. Datum elevation (DF or KB) 62' RKB feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 1014' NSL, 29' WEL, SEC. 10, TION, R15E, UM At top of productive interval 9. 443' SNL, 33' EWL, SEC. 10, TION, R15E, UM At effective depth 10. 8. Well number 3-25 Permit number 83-145 APl number 50- 029-21021 At total depth 4'SNL, 346'WEL, SEC. 9, TION, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 12265 feet Plugs (measured) 9229 feet 12216 feet Junk (measured) 9194 feet Length Size Cemented 80' 20" 2020# Poleset '2538' 13-3/8" 2575 sx cs 111/4oo sx cs II 11234' 9-5/8" 500 sx "G"/305 sx CS I 1311' 7" 425 sx "G" measured 11682'-11700', 11724'-11734', 11802'-11852' 11. Field/Pool Prudhoe Bay Field~Oil Pool RECEIVED Alaska 0il & 6a$ Cons. C0mmlssio. ni Measured depthArlC[10ragffrue vertical depth 80' 80' 2538' 2538' 11234' 8505' 12258' 9224' true vertical 8815'-8827', 8844'-8851', 8899'-8935' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10894'MD, 4-1/2", 12.6#, L-80, PCT @ I0976'MD Packers and SSSV (type and measured depth) Otis RRH packer @ 10895'MD, Otis 5-1/2" RQ SSS V@ 2218' MD 13. Attachments Description summary of proposal x Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 2/2O/93 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify tha the foregoing is true and correct to the best of my knowledge. Si.gned ~-- '~,,~/ TitleDrillingEn~ineerSupervisor 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- I Approva, No. Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE OBJECTIVE: The DS 3-25A objective list is as follows: Permanently abandon the current wellbore and pull tubing string. Optimize Victor oil production that is currently hampered by the nearby fault/graben configuration. Obtain open hole log information for completion strategy and correlation to surrounding wells. Install chrome tubulars and liner. .,CURRENT STATUS: Produces 70 BOPD, 3700 BWPD (98%WC), and 650 GOR. Well is currently amidst a complex fault/graben system and the bottom hole location is at the intersection of two of these faults. It is possible that water is funneled to the wellbore along these faults. Historically, a channel from the Zone 3 conglomerate down 70 feet had been the source of high gas production prior to waterflooding and is now a likely source for the high watercut. Two WSO squeezes have been performed with limited success. PERMITTING: A sundry notice covering the plugback of the original well has been submitted. attached drilling permit covers the proposed drilling program for the redrill. The OBJECTIVE: The DS 3-25A objective list is as follows: Permanently abandon the current wellbore and pull tubing string. Optimize Victor oil production that is currently hampered by the nearby fault/graben configuration. Obtain open hole log information for completion strategy and correlation to surrounding wells. Install chrome tubulars and liner. CURRENT STATUS: ~ Produces 70 BOPD, 3700 BWPD (98%WC), and 650 GOR. ~ Well is currently amidst a complex fault/graben system and the bottom hole location is at the intersection of two of these faults. It is possible that water is funneled to the wellbore along these faults. ~ Historically, a channel from the Zone 3 conglomerate down 70 feet had been the source of high gas production prior to waterflooding and is now a likely source for the high watercut. _o Two WSO squeezes have been performed with limited success. PERMITTING: A sundry notice covering the plugback of the original well has been submitted. attached drilling permit covers the proposed drilling program for the redrill. The DS 3-25A AFE SUMMARY PROCEDURE 1. Pre-dg work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 5-1/2" tubing at 10480' MD. Freeze protect. 2. MIRU workover dg. Test intermediate packoff to 3500 psi. 3. Pull BPV. Circulate out freeze protection fluid. 4. Set two-way check valve. ND tree. 5. NU BOP's. Test BOP's to 5000 psi. Pull two-way check valve. 6. Pull and lay down 5-1/2" tubing. 6a. RIH w/9-5/8" bridge plug and set at _10395' MD. Spot an 18 ppg pill on bottom. 7. RIH with a 9-5/8" section mill and cut a 60' section in the 9-5/8" casing starting at +/- 1024,~' MD. 8. RIH with open-ended DP. Mix and pump 150 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. 9. Replace intermediate packoff if necessary. 10. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally drill to align well with target. 11. Drill with a 8-1/2" packed hole assembly to total depth of 12467' MD / 9172' TVD or 150' MD below the HOT at -9110' SS T.VD. 12. RU wireline and log with the DLL/GR / SP / Sonic. Make wiper trip depending on time /hole conditions and logging7,' 29'# L-80 NSCC standard liner assembly to TD with 13. / Run 7" 29# 13CR NSCC x liner top packer/hanger and tie-back extension w/+/- 150' lap. Crossover from 13CR to L-80 at 112,;38.'.MD. 14. Cement liner with 425 sacks based on'40% open hole washout, shoe volume, lap volume, and 200' excess on top of liner with DP. 15. Clean out liner to PBTD and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. Circulate corrosion inhibitor down the annulus. 16. RIH with ,,5-1/2" 17# NSCC 130R80 xo to 4-1/2" 12.6# NSCT 13CR80 completion string w/Z" packer. Space out, land completion, and set packer at 11438' MD based on 100' above t~op of Sadler0¢hit marker. Test down tubing to 4000 pSi. Test'tubing x casing annulus to 3500 psi. Set two-way check valve. ND BOP's. NU and test the 6" 5M tree to 5000 psi with diesel. Pull two way check valve. Shear RP valve and freeze protect. Set BPV. Release rig. RU wireline and perforate. 17. 18. 19. 20. DS 3-25A AFE SUMMARY PROCEDURE . . 3. 4. 5. 6. 6a. 7. , . 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 5-1/2" tubing at 10480' MD. Freeze protect. MIRU workover rig. Test intermediate packoff to 3500 psi. Pull BPV. Circulate out freeze protection fluid. Set two-way check valve. ND tree. NU BOP's. Test BOP's to 5000 psi. Pull two-way check valve. Pull and lay down 5-1/2" tubing. RIH w/9-5/8" bridge plug and set at 10395' MD. Spot an 18 ppg pill on bottom. RIH with a 9-5/8" section mill and cut a 60' section in the 9-5/8" casing starting at +/- 10245' MD. RIH with open-ended DP. Mix and pump 150 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. Replace intermediate packoff if necessary. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally drill to align well with target. Drill with a 8-1/2" packed hole assembly to total depth of 124(~7' MD / 9172' TVD or 150' MD below the HOT at -9110' ss TVD. RU wireline and log with the DLL/GR / SP / Sonic. Make wiper trip depending on hole conditions and logging time. Run 7" 29# 13CR NSCC x 7" 29# L-80 NSC~,, standard liner assembly to TD with liner top packer/hanger and tie-back extension w/+/- 150' lap. Crossover from 13CR to L-80 at 11238'MD. Cement liner with 42,5 sacks based on 40% open hole washout, shoe volume, lap volume, and 200' excess on top of liner with DP. Clean out liner to PBTD and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. Circulate corrosion inhibitor down the annulus. RIH with 5-1/2" 17# NSCC 13CR80 xo to 4-1/2" 12.6# NSCT 13CR80 completion string w/7" packer. Space out, land completion, and set packer at 114.,3~' MD based on 100' above tod of Sadler0chit marker. Test down tubing to 4000 psi. Test tubing x casing annulus to 3500 psi. Set two-way check valve. ND BOP's. NU and test the 6" 5M tree to 5000 psi with diesel. Pull two way check valve. Shear RP valve and freeze protect. Set BPV. Release rig. RU wireline and perforate. PRELIMINARY WELL PLAN 3-25A Redrill PB U APl NO.' 50-029-21021-00 (on the original 3-25 well) LOCATION: Surface: 1014' FSL, 29' FEL, Sec. 10, T10N, R15E Target: 750' FNL, 325' FEL, Sec. 9, T10N, R15E @ 8540' ssTVD BHL: 4622' FSL, 1052' FEL, Sec. 9, T10N, R15E @ 9110' ssTVD .ESTIMATED START: March 18,1993 ,~PR.' DAYS TO COMPLETE: CONTRACTOR; Doyon Rig #16 18 (6 days prep & mill, 7 days drill, 5 days complete) DIRECTIONAL: Kickoff at 10,250' MD. 12.43 degree angle build and 36.2 degree west turn. WELLBORE- Item '20" CONDUCTOR 13-3/8" SHOE KOP TOP SAG RIVER SANDSTONE TOP SADLEROCHIT TOTAL DEPTH TVD(ss~ MD(BKB~ Mud Wt, 48' 110' N/A 2451' 2538' N/A 7684' 10250' 9.8 8486' 11 450' 10.0 8540' 11538' 10.2 9110' 12467' 10.2 LOGGING PROGRAM: 8-1/2" Hole: GR / DLL w/microresistivity / CNL/Density PRELIMINARY WELL PLAN APl NO.: LOCATION: ESTIMATED OPR.' DAY,,~ TO' COMPLETE: 3-25A Redrill PBU 50-029-21021-00 (on the original 3-25 well) Surface: 1014' FSL, 29' FEL, Sec. 10, T10N, R15E Target: 750' FNL, 325' FEL, Sec. 9, T10N, R15E @ 8540' ssTVD BHL: 4622' FSL, 1052' FEL, Sec. 9, T10N, R15E @ 9110' ssTVD START: March 18,1993 18 (6 days prep & mill, 7 days drill, 5 days complete) CONTRACTOR; Doyon Rig #16 DIRECTIONAL: Kickoff at 10,250' MD. west turn. WELLBORE: 12.43 degree angle build and 36.2 degree Item 20" CONDUCTOR 13-3/8" SHOE KOP TOP SAG RIVER SANDSTONE TOP SADLEROCHIT TOTAL DEPTH TVD(ss) ~ Mud Wt. 48' 110' N/A 2451' 2538' N/A 7684' 10250' 9.8 8486' 11450' 10.0 8540' 11538' 10.2 9110' 12467' 10.2 LOGGING PROGRAM: 8-1/2" Hole GR / DLL w/microresistivity / CNL/Density MUD PROGRAM: The milling/drilling fluid program will consist of a 9.8 ppg XCD polymer / KCI water based mud in the 8-1/2" hole. DEPTH DENSITY PV YP INT 10 MIN FL OIL SOLIDS MUD _ (%VD) (PPG) f. CP) (#/FT) GEL GEL cc/30min (%) (%) TYPE 7746' 9.8 10 10 5 7 6 0 5 Water to to to to to to to to to Base 12467' 10.2 1 6 1 8 1 0 1 5 3 0 9 Mud ,MUD WEIGHT CALCULATIONS ./ WELL CONTROL: Mud Wt. (8-1/2" Hole): 9.8 - 10.2 ppg. .. Est. Pore Press. Sag River: 4059 psi/8798' ss TVD Est. Pore Press. Sadlerochit: 3500 psi/8800' ss TVD. Overbalance Sag River: 424 psi. Overbalance Top Sadlerochit' 1180 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS' CASING DEPTH BURST .COLLAPSE TENSILE 7" 29# 13CR80 NSCC 11238' - 12,467' MD 7~i (7564'-9110' ss TVD) 7" 29# NT80SS NSCC 10,095' - 11,238' MD -7240 psi (7564'-8356' ss TVD) ~¢¢¢ 7" X 9-5/8" Liner Hanger and Liner Top Packer @ 10,095' MD .54-t0' psi .6O4-klbs psi 6e4 klbs MUD PROGRAM' The milling/drilling fluid program will consist of a 9.8 ppg XCD polymer / KCl water based mud in the 8-1/2" hole. DEPTH DENSITY PV YP INT 10 MIN FL OIL SOLIDS MUD R'VD) (PPG) (¢P) (#/FT) GEL GEL ~c/30min (%) (%) TYPE 7746' 9.8 10 10 5 7 6 0 5 Water to to to to to to to to to Base 12467' 10.2 16 18 10 15 3 0 9 Mud MUD WEIGHT CALCULATIONS / WELL CONTROL: Mud Wt. (8-1/2" Hole): 9.8 - 10.2 ppg. Est. Pore Press. Sag River: 4059 psi/8798' ss TVD Est. Pore Press. Sadlerochit: 3500 psi/8800' ss TVD. Overbalance Sag River: 424 psi. Overbalance Top Sadlerochit: 1180 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING DEPTH BURST ~;?~;;29#~13CR80 NSCC 7. 29# NT80SS NSCC 11238' - 12,467' MD (7564'-9110' ss TVD) 10,095' - 11,238' MD (7564'-8356' ss TVD) .Z2,40 psi 7" X 9-5/8" Liner Hanger and Liner Top Packer @ 10,095' MD COLLAPSE TENSILE _5~HO psi ~ psi, ~lbs~ CEMENT Measured Depth- Basis: Total Cement Vol' CALCULATIONS: 7" Liner 10,095' MD (Hanger) - 12,467' MD (Shoe) 40% open hole excess, 40' shoe joint, 7"x9-5/8" annulus w/ 200 ft. above liner top in 5"x9-5/8" annulus. 477 cuft or 425 sxs of Class G blend @ 1.16 Cu ft/Sk TUBING DETAILS; 5-1/2" 17 # 13CR-80 NSCC (0'- 10,045' MD) 4-1/2" 12.6 # 13CR-80 NSCT (10,045' - 12,467' MD) CEMENT CALCULATIONS: Measured Depth: Basis: Total Cement Vol: 7" Liner 10,095' MD (Hanger) - 12,467' MD (Shoe) 40% open hole excess, 40' shoe joint, 7"x9-5/8" annulus w/ 200 ft. above liner top in 5"x9-5/8" annulus. 477 cu ft or 425 sxs of Class G blend @ 1.16 Cu ft/Sk TUBING DETAILS' 5-1/2" 17 # 13CR-80 NSCC (0'- 10,045' MD) 4-1/2" 12.6 # 13CR-80 NSCT (10,045' - 12,467' MD) DOYON RIG #16 MUD & SOLIDS CONTROL EQUIPMENT _ _ m _ ~ ~ m _ Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Trifiow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console DOYON RIG #16 MUD & SOLIDS CONTROL EQUIPMENT I i I m ~ ~ Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console FF,,UI'I L]Rr'l'-ll Ll-Ilti) ,g),l.l'~ .L)I'~IL_LII"'I~ IU : GREAT LAND DIRECTIONAL DRILLING, INC. Corporate Office 1111 East 80th Avenue Anchorage, AK 9951R (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING Well ......... : DS 3-25A (P1) Field ........ : PRUDMOE BAY DRILL SITE 3 Computation..: MINIMUM CURVATURE Units ........ : FEET Prepared ..... : 01/19/93 Section a~...: 277.28 KB elevation.: 62.00 ft LEG~L DESCRIPTION Surface ...... : 1014 FSL 29 FEL Sl0 T1ON R15E U~ Tie-in ....... : 4275 FSL 4701 FEL $10 T10N R!SE UM Target ....... : 4526 FSL 324 FEL S09 T10N ~15E UM BHL .......... : 4622 FSL 1052 FEL S09 T!0N R15E UM X ASP ZONE 4 Y 713241.72 5937053,12 708474.93 5940182.13 707564.00 5940411.00 706834.39 5940483.92 PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-IN MEAS INCLN DEPTH ~GLE 10250 39.72 10300 40.17 10400 41.30 10500 42.71 10600 44.38 VERT-DEPTHS SECT BKB SU~-S DIST 7746 7684 5053 7784 7722 5080 7860 7798 5136 7934 7E72 5!97 8007 7945 5262 DIRECTION REL-COORDINATES DL/ AZIMUTH 313.51 310.47 304.59 299.00 293.72 FROM-WELLHEAD 100 3261 N 4678 W <TIE' 3283 N 4702 W 4.0 °°22 N 4753 W 4.0 3358 N 4810 W 4,0 3388 N 4872 W 4.0 END OF CURVE TAi~GET 10700 46.29 10800 48.39 10900 50.66 10962 52.15 11538 52.15 8077 8015 5331 8145 8083 5403 8210 8148 5479 8248 8i86 5528 8602 8540 5983 288.77 284.i4 279.82 277.28 277.28 3414 N 4938 W 4.0 3435 N 5009 W 4.0 3450 N 5083 W 4.0 3458 N 5131 %: 4.0 3515 N 5582 W 0.0 TOP SkDLEROCHIT TD 11538 52.15 12467 52.15 8602 8540 5983 9172 9110 6716 277.2S 277.28 3515 N 5582 W 0.0 3608 N 6310 W 0.0 'GLt~D (:c)9:Z D$3~_5A B1,40 2:11 PN 2) ~KUI'I ~HI LHIN~ UIK UKILLIIN~ IU GPd~AT LAND DIRECTIONAL DRILLING~ Corporate Office 1111 East 80th Avenue Anchorage, AK 9951R (907) 349-4511 Fax 349-2487 INC. DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING Well ......... : DS 3-25A (P1) Field ........ ~ PRUDHOE BAY DRILL SITE 3 Computation..: MINIMUM CURVATURE Uni%s ........ : FEET Prepared ..... : 01/19/93 section at...: 277.28 KB elevation.: 62.00 ft LEGAL DESCRIPTION Surface ...... : 1014 FSL 29 FEL Sl0 TiON R15E UN Tie-in ....... : 4275 FSL 4701 FEL S10 T10N R15E UM Target ....... : 4526 FSL 324 FEL S09 T10N ~15~ U~ BHL .......... : 4622 FSL 1052 FEL S09 T10N R15E UM X ASP ZONE 4 Y 713241.72 5937053.12 708474.93 5940182.13 707564.00 5940411.00 706834.39 5940483.92 PROPOSED W~LL PROFILE STATION ~iEAS INCLN VERT-DEPTHS IDENTIFICATION DEPTH A/~GLE BKB SUB-S TIE-IN $~CT DIST 10250 39.72 7746 7684 5053 10300 40.17 7784 7722 5080 10400 41.30 7860 7798 5136 10500 42.71 7934 7872 5197 10600 44.3B 8007 7945 5262 DIRECTION AZIMUTH 313.51 310.47 304.59 299.00 293.72 REL-COORDINATES DL/ FROM-WELLHEAD i00 3261 N 4678 W <TIE' 3283 N 4702 W 4.0 3322 N 4753 W 4.0 3358 N 4810 W 4.0 3388 N 4872 W 4.0 ~.ND OF CUR%~ TARGET 10700 46.29 8077 8015 10800 48.39 8145 8083 10900 50.66 8210 8148 10962 52.15 8248 8186 11538 52.15 8602 8540 5331 5403 5479 55~8 5983 255.77 3414 N 4938 W 4.0 284.14 3435 N 5009 W 4.0 279.82 3450 N 5083 W 4.0 277.28 3458 N 5131 W 4.0 277.28 3515 N 5582 W 0.0 TOP SADLEROCHIT TD 11538 52.15 8602 8540 12467 52.15 9172 9110 5983 6716 277.28 3515 N 5582 W 0.0 277.28 3608 N 6310 W 0.0 (GLDD Cc)92 D$.325A B1.40 2:11 PM 2) NSr'kl~p Identification TIE-tN E~ OF CURVE TARGET 4800 4950 5100 i-'hSD ENG ! NEERS P. 04 PRUDHOE BAY 10250 7746 5053 39.72 J0962 $248 5528 52.t5 11538 8602 5983 52.~5 12467 9J72 67J6 52.15 DRILLIN6 DS 3-25A (P VERTICAL SECTION VIEW ---=" ~ " '", 'i:~ ' :F';??:'.~' ',,, '? ' ' " TVD Scale.' 1 1nch = 300 feet Oep Scale.' t 5nch = 300 fee,t. Drawn ' 0~/1g/93 ..... ' --" ~. _ , ill., ..... i,,, ! 52_5O 5400 5550 5700 5~50 5000 5.~50 ,6 ' Sec~ ~.on Departure 6300 6450 6600 6750 6900 Manker IdentJficatJon MO 8KB SECTN INCLN TIE-IN 10250 77~6 5053 3g,72 ENO OF CURVE I0~G2 8~B 5528 52.t5 T~GET 11538 8602 §983 52. t5 TO 12467 ~2 67~6 52.t~ DS 3-25A (P V E Ssction at: 277,28 TVD Scale.' Dep Scale.' Drawn ' 01/19/g3 Shear Land Oirectional £nilling ' 4800 4950 5100 5250 5400 5550 5700 5850 Sect ion Depanture (6LD~ (el 92 0s~25~ B~.40 2:30 PM 2) 6000 6150 6300 6450 6600 6750 6900 ,.? 400 6800 , : .... iml _ . ~ iii : , i i DS 3-25A (Pi) PLAN VlE~q CLOSURE .... ' 7268 feet at Azimuth 299.76 __ -i -'- _L"' ! " -1 . =- _ .!.,?-'~%JS?~-._- ·ISCALE ....... : ! inch : BO0 feet o--'" .... ,~ ; ....... - ',,-T' ,7 ;-!:' -_'_ ,-.-T .... --S -'"¥!-_ S'S,!_-i_ OFIAVIN ....... --- '-~I ,__ _ _ _ :.iE .. ,_ L._. £ _ _ L.__"_,__ _ ..... -- ~ ' , i .~ -'-'---~ ........ I ~. i- --i~ ............... ~ ...... :- -: .......... , ......... -~ .......... -, ...... f- S]Z~LZ .................. - ' ~ I-. ~ l_._ ! ..... ~ ..... ~ ........... ,, _.._, .................. ~ ........... ~_ Z Z _-_ Z.'.-_ Z S SI -- __/.. ii, ; ri i / ., : . ! [ . °----.-~. "---~-'----'~.-. ,'----~-:'~- :: ,: :: i ~ .; - i: [ .--t----t4----:-'i:--i-:~:~:----~T--~ ..... _-. Z _. 2 _ S, ,~ .... ~ "=-~ ' ~" -: -,---'--- .... ,'--'--", ....... ........ ........ ,. ' --' -'-'-- ......... .... ....... ,, + , ........ -_:: .... ~ .~t .................... - ....... ' SSS ............. .i._ -"~ , , ..... S- . ~~- SSS-L-~' FS ........ I-%! ii'i SSS S 2 ~-; .... 1~-'9-- , -1 - ~ , - i ........ -I r - - }~; i ', i ; i r-i ~ ~ i ~ -_ -'--F ........... i ~--i ...... :-i--si-.- ! ..... '-'-i~--: .......... ~ ..... '-'-' ..... !_,L .... -I '-: ..... ' ....... !~Z--! .... ' .... ....... : ..... i .... : ........ 1- -b ................ t; ......... ~ ...... r--:---;~- !--~- - -i ....... ~. ........... i~-'i- , ......" ~ ----~ .... i- - ~-~--~' .... ' ~ ...... i " ............ ~ ........ --~---~ ...... ~ ..... ~ - --1-" ...... '¢, ...... !--~'--I ....... '-q ............... , , ..... ~-- ~ ' ' ' ' ' ' ' ' {1 ['}- , ; ~ _J.j ' ' ': . 1 ~, ..... , ~ "J,.-' .... 'J, -~ = -'- -' ~ ~ I .... ~ - - -'~ ......... '-]1 ..... ' ....... , ~--.i,-: ..... !. .......... _~ ................. . ...... , ................... , .......... ...... ._,_. ........ -- -'I ........ I ............ : ' ~ i ' : I ~,~ s [ I ]1 ~ i i 2 _l -'S -7ZZSSZS2Z Z _SS ZS.'T_iSLSS T 7 S S Z ZZZ SSS,SS S 2!72 S]:, S ~,~ T S'!SjZIZ Z'.SSZ]2Z SL_,___S ~ 17 7_~S.; ~:.J L~ L._'!__ :_.i..! .... ~ ! i I ~ % I il ] I_ _ , :~.... '. : __,u_ :__!--., .... 2..... f ........... '- i=i ..... -< - -7S22 Z _-_ .... J.._~ __{ ..... , _, ....... % .................... ~ ..... .,J---4 -i- ............. T ...................... ~ ......... · -- ii_ . 4 :. , rl _-,2__L,i ~ ......... . .................... .. ........ . ! '~ , : . .~ i= =' .. · . , :: .... , ,......... ..., , ...... , ........... I_-1-? ................. ,.-.- ....~ _j -'~-.' - _ . -i ....... ,,. ..... -4 ................ ' ,,! i ........ ~( ~ .-p.. ~ -4.-- ........ "' ~ - ...........-4 r ............................ -"'-'"'--= 'T- ' I _¢ .... , ;~ ......... t ................. ._.,. . .{_ i .... J ................ ,i .......... { ........ ~ ..... ! ....... 4 ..... ~ ....... ~- -I ................. ~-~' -,__ : _ _ ,...~ ........... L.-~ ....... , ~ ; · : ! ,. , , ~ I ............ ii 4 ....... ~ i. ~ _'..] . i-- -- ~[ ........ ' ......................... F - - L -4 - :,-i : ' t, i ' - _!_[__ .... ~_._!__ _ .~ ..... r .... ~- -~ ...... . -.-~ .... ~._,__. ...... = ,,---- ....... : ...... ~--~_~= -.., .............. I I i ~. ................... / I ~- ~ i .... Ii ......... ; ..... : ..... ............. ! ..... '[- ........, -----1 ! ...... '-1---I ..... -' J ~ , I ' I ~ I } ! I ~ ii\ .... ? ..... -.,-- i : i ' ' [ ' I ~ i-- .... : -! ........ . ........ f--' ..... i---~-"1-- --', ,, - ............... ~---,- .; ~ ...... , ...... ,---- =-~ L: --[-{--=- {' - -I'ST-'--t-' [ ii ~ / -- ..... ~--F- i [ ~ { } l '.- { '",--r- _El-, { ~ . ~ ~ I. _ l-l- ~!? : : [-1 , _ ~ / i 3 1 F ~ ,I _l._.z__ ~_ I j I I . I I l I. . .'. I ~ I ~ I ~II t. ~ , ........................ 6400 fi000 5600 5200 4800 4400 4000 3600 3200 2800 2400 2000 t600 1200 800 400 0 400 <- ~EST' EAST -> tt;LClO Icl 92 CS%'St, U1.43 2:32 I.','~ Ig I ............, PRUDHOE ill , ..................... ~arke~ IdBnt i f iCa[io~ ~0 N/S A] lIE-IN 18250 326] 81 EN~ OF CURVE i~982 3458 D) lB ~2487 3608 ...... : m __ mi m I mil Great Land flir~ctional £rilling mi__ mi ii i DS 3-25A PLAN VIE~ I; 6BO0 -I : Z' -~--- DECLINATION.: 30.17 E ~,~ ~ -- ] .SCALE ...... : I inch = 800 feet I ._. ..,,.~:-:.::::~ .- ........................... ................. Z''-~.~,a ~ ...................... . ..... .... : ~-'~ .......................... ~___ ~ ~...... -' _ _Lm_ --L . L ...... _ ~q ............... , ~ _ q- _ I ............ 1 , · ~ ......................... ....... . _ -- ......... ~ ~ ..... i, . ---~- i t .... ~ j ~ .~t ~ J- . .... · - , i . i'- , '' : - - _ _ ii,~_ ' ........ :L I ', -- , ~ ,: i ...... , I '-i ,. -' 76 64Q0 6000 5600 5200 4800 4400 4000 3600 3200 2800 240O 2000 )600 1200 800 400 0 400 <- ~'EST' E~$T -> ............. i mmmmm, , I .. 'I ..... i MUD & DOYON RIG #16 SOLIDS CONTROL EQUIPMENT m _ ~ _ ' t Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console MUD DOYON RIG #16 & SOLIDS CONTROL EQUIPMENT m i i i ~ t m Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console DOYON 16 13 5/8" 5,000 psi Stack 10.15 ,t, 4.5 5.02 r / RKB 1 I J RI, i FLO I I HYDRIL 12.40 Variable 3.5" x 6" Pipe Ram ~R 15.40 17.60 1.02 1.80 2.35 GROUND LEVEL 0.25 Variable 4.5"x 7L" Pipe Ram MUD CROSS ,! Blind Ram 20.70 I24.85 I TBG SPOOL ~ TBG SPOOL ~ II ~ BASE ~~)~ FLG 25.10 DOYON 16 13 5/8" 5,000 psi Stack 10.15 4.5 GROUND LEVEL 5.02 1 .O2 1.80 RKB 1 2.35 0.25 i 1 HYDRIL Variable 3.5" x 6" Pipe Ram RI~ i FLO 12.40 Variable 4.5" x 7L" Pipe Ram MUD CROSS 15.40 17.60 Blind Ram I ETBG SPOOL ,TBG SPOOL i I  BASE FI_G 20.70 I24.85 25.10 Stale: Alaska Borough: 'Weilh DS3~25A Field: Prudhoe Bay I~ale 2/5/93 Engr: M. Minder DS3-25~.XLS Cas in g Interval Interval Size Bottom Top Length lA 7 9172 76:90 2372 2A 7 9172 76:90 2:972 :gA 0 0 0 0 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 29:9CR-80 & N OSS & 0 26 L-80 NCSS 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 0 0 0 0 lB 2B 3B 4B 5B 6B 7B 9B 1 OB Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/ft psi/ft 10.2 0.5:90 0.4:90 10,2 0.5:90 0.4:90 0,0 0,000 -0.100 0,0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.1 O0 0,0 0.000 -0. ! 00 0,0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 8:9:90 8160 2.5 8:930 7240 0 0 #DNIOI. 0 0 #DIVlOI. 0 0 #DIVIO! 0 0 #DIV/O! 0 0 #DlVlO! 0 0 #'DIV/01. 0 0 #DIV/0! 0 0 #DIVI0! 1C 2C 3C 4C 5C 6C 7C 8C 9C 10C Tension Strength KJLbs 68.788 61.672 0 0 0 0 0 0 0 0 K/Lbs TDF 676 9.83 604 9.79 0 #DIV/O! 0 #DIV/O! 0 #DIV/0~, 0 #DIV/0! 0 #DIV/O~ 0 #DIV/O! 0 #DIV/0! 0 #DIV/O! Collapse Collapse Pr-Bot-Psi 3948 3948 0 0 0 0 0 0 0 0 Resist, C:DF 7020 1.778 5410 1.370 0 #DlVlO.I 0 #DIV/O,I 0 #DIVI0! 0 #DIV,/O! 0 #DIVlO! 0 #DIViO.I 0 #DIVI01. 0 #DIV/O! 3-25&CMT.XLS State: Well: Field: State Permit £.~S9-4,4 .¢3.24 Engineer: Work Sheet: Date: ,4.,(. C. er~nt Volume Calculations 2/5/.93 Casing Type C~sing Size -Inches Casing Length - Feet Hole Diameter -Inches Cement- Sacks Cement-Yield ~I1 Cement- Cubic ft Cement- Cubic ft ~I1 Cement- Sacks 112 Cement- Yield 112 Cement- Cubic fl 112 Cement- Cubic ft Cement- Sacks 113 Cement- Yield ~I3 Cement- Cubic It 113 Cement- Cubic ft Cement- Cubic ft / Vol Cement- Fill Factor Conducto~ 0.000 0.000 0.000 0.000 0.000 0.000 O. O00 0.000 0.000 0.000 0.000 0.000 I~DIV/O! Surface 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ~DIV/O! L~nef 7.000 2,372.000 8.500 425.000 1.160 493.000 493.000 0.000 0.000 0.000 0.000 493.000 1.639 Casing Type Casing Size -Inches Casing Depth- Feet Hob Diameter-Inches Cement- Sacks ~11 Cement- Yield 111 Cement- Cubic It ~11 Cement- Cubic ft ~I1 Cement- Sacks 1:12 Cement- Yield ~12 Cement- Cubic ft ~2 Cement- Cubic Irt Cement- Sacks Cement-Yield Cement- Cubic ft 113 Cement- Cubic t~t ~3 Cement- Cubic ft /Vol Cement-Inte:vai tt Top of Cement- Feet Intermediate 0.000 O. O00 0.000 O. O0 0.00 O. O0 0.00 0.00 0.00 0.00 O. O0 0.00 0.00 0.00 0.00 IIDIV/O! ~DIV/O! Intermediate ~I2 0.000 0.000 0.000 0.00 0.00 O. O0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 IIDIV/O! I~DIV/O! P~oduction 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 MDIV/O! ~DIV/O! ~.l~.~.,,-ed ~ep~h ** CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc ~ ~ [ 2 thru (3) Admi n/<?~]~-- [9 thru [10 & 13] [14 thru 22] [23 thru 28] [29 thru' 31~' (7) Contact [32] (8) Addl ,,d~.~,','~,~$~.-m-~-9._~' Company~~_~;:~ YES 1. Is permit fee attached ............................................... ~ 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... ~ 5. Is sufficient undedicated acreage available in this pool ............. ~__ 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ I 10. 11. 12. 13. 14. 15. 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. Lease g Well ~ ,~'~ Z~'~.2-~;~.' NO Does operator have a bond in force ................................... Is a conservation order needed ....................................... I s admi n i st rat i ve approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ I s conductor st r ing provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 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 ..................... 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 ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams $ descriptions of ~l~l~llJ~ ~Ii~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 ...................................... 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 nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. 0 -rz ~0 Gm-~ geology' engineerinq: MTM. g RAD RP~. BEW JDH~ :~'-~. LG rev 12/92 jo/6.011 INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional MERIDIAN: remarks' UM SM Exp/Dev Inj , TYPE,: Redri 1 1' Rev ** CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee A~/~_ ,~/~ (2) Loc ~p~ ~ [ 2 thru 8] [8] (3) Admin ~?d. .~.~/~.~_~ '['cj -thru 13]' [10 & 13] [14 thru 22] [23 thru 28] (5) BOPE le 3. 4. 5. 6. Company YES Is permit fee attached ............................................... /~_ Is we, l]' to be located in a defined pool .............................. _~_ Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. /~ Lease & Well NO Is well to be deviated & is well bore plat included ................... /~ Is operator the only affected party .................................. Can permit be approved before 15-day wait REMARKS . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... Is a conservation order needed ....................................... ~_ Is administrative approval needed .................................... Is lease ncrnber appropriate .......................................... Does well have a unique name & n~rnber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 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 ..................... 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 ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of ~,l~l~j~ BOPE attached .... Does BOPE have sufficient pressure rating -- test to~'~O~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... (6) Other ~?rC ~ '[29 thru 31] (7) [3 2] (8) Add l ~. ¢~',~t', ~. -~-~ geology' engineering: DWJ MTM ~ RAD ..~' RPC,.~, BEWLG JDH~J~ 12/92 jo/5.011 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 n~rnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE , Additional remarks: UM MER I D I A~,.I' SM" ~ ~YPE: Exp~_~ /X In j. Red ri 1 I Rev o Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ARCO ALASKA INC D.S. 3 - 25A PRUDHOE BAY RECEIVED Run 1' 23 - March - 1993 DLL/ACICNIGR 8550 12376 nore Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: RUN1 5914.00 BRAD ESARY SEE REMARKS D.S. 3 - 25A 500292102101 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 12-APR-93 RUN2 RUN3 10 i0N 15E 1014 29 62.00 61.00 28.00 RECEIVED MAY 0 6 1993 AJaska Oil & Gas Cons. Commission Anchorage OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8791.0 8.500 12395.0 AC/CN/DLL/GR LOGS WITNESSED BY: N. SCALES, D. CROCKETTE, T. COLLIER, K. CHURLE. CIRCULATION STOPPED: 06:00 23-MAR-93. LOG TIED TO GAMMA RAY DATED 28-NOV-83. REPEAT SECTION SPLICED AT 11470' FOR OVER LAPPING AFTER EXCESSIVE PULL. CALIPER PRESENTED ON MAIN PASS IS FROM DOWN PASS. EX- CESSIVE PULLS ON BRIDLE CABLEHEAD CAUSED OPEN CON- DUCTOR TO CALIPER. CALIPER BEFORE LOG VERIFICATION PERFORMED IN CASING, AFTER LOG ON SURFACE. CNC IS CALIPER CORRECTED, CHISM FILTERING NOT ACTIVE. DUAL LATEROLOG AFTER LOG VERIFICATIONS PERFORMED ON SURFACE. SAME OPEN CONDUCTOR IN BRIDLE CABLEHEAD WOULD NOT ALLOW TOOL TO BE SWITCHED TO VERIFICATION MODE DOWNHOLE. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS 2435 DLL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 8796.0 12312.0 11400.0 12376.0 11250.0 12319.0 11400.0 12344.0 GR (MEASURED DEPTH) BASELINE DEPTH DT 8796.0 8796.0 11257.0 11295.5 11306.0 11350.5 11359.5 11382.0 11439.5 11443.0 11446.5 11447.0 11452.5 11486.0 11526.5 11527.5 11531.5 11536.0 11537.5 11538.5 11540.5 11543.0 11543.5 11554.5 11562.0 11563.0 11584.5 11585.5 11587.0 11590.5 11591.5 11602.5 11603.0 11603.5 11607.0 11610.5 11611.0 11613.0 11617.0 11619.0 11620.5 11442.0 11486.0 11525.0 11531.0 11539.0 11544.5 11587.0 11591.0 11602.5 11610.0 11617.5 all runs merged; EQUIVALENT UNSHIFTED DEPTH NPHI LL3 LLD 8796.0 8796.0 8796.0 11257.0 11294.5 11306.5 11350.5 11360.0 11382.0 11439.5 11447.0 11453.0 11447.0 11526.5 11530.5 11531.5 11540.0 11543.0 11544.5 11536.0 11538.5 11555.0 11562.5 11563.0 11584.5 11585.0 11603.0 11610.5 11609.5 11613.0 11617.0 11591.0 11601.5 11606.0 11620.5 no case 11640.5 11646.0 11668.5 11677.5 11720.0 11741.5 11752.0 11785.0 11793.5 11827.5 11829.0 11834.0 11840.5 11841.0 11843.5 11846.5 11850.0 11866.0 11870.5 11874.0 11880.0 11884.0 11898.0 11906.0 11917.0 11940.5 11972.0 11978.5 11992.0 12002.0 12030.0 12031.0 12031.5 12038.5 12043.5 12046.5 12047.5 12051.5 12060.5 12061.0 12075.5 12078.0 12087.5 12090.0 12091.0 12102.5 12103.0 12112.5 12121.0 12128.5 12132.5 12133.0 12133.5 12134.5 12184.5 12185.0 12193.5 12195.0 12201.5 12202.0 11641.0 11720.0 11742.0 11793.5 11827.5 11841.5 11866.5 11884.0 12076.5 12088.5 12102.5 12112.0 12120.5 12130.0 12133.5 12201.5 11645.0 11668.5 11676.5 11792.5 11869.5 11873.0 11879.5 12030.0 12060.5 12121.0 12133.0 12202.5 11741.5 11752.0 11829.0 11839.5 11846.5 11941.0 12031.0 12039.0 12061.0 12102.0 12184.0 12201.0 11785.0 11834.0 11843.0 11850.0 11898.0 11906.5 11917.5 11972.5 11978.5 11992.0 12002.5 12031.5 12044.0 12047.0 12047.5 12051.5 12078.0 12090.0 12090.5 12133.0 12133.5 12183.5 12192.5 12194.5 12212.5. 12216.0 12217.0 12227.0 12227.5 12235.0 12243.0 12247.5 12297.5 12335.5 12400.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS 2435 DLL $ REMARKS: CN WN FN COUN STAT 12216.5 12227.0 12235.5 12400.0 RUN NO. 1 1 1 1 12248.5 12297.5 12227.5 12243.0 12212.0 12217.0 12335.5 12400.0 12400.0 12400.0 PASS NO. MERGE TOP MERGE BASE 5 8796.0 12312.0 5 11400.0 12376.0 5 11250.0 12319.0 5 11400.0 12344.0 OPEN HOLE MAIN PASS. CAL3, TENS, & TEND WERE SHIFTED WITH DT. NUCT & FUCT WERE SHIFTED WITH NPHI. SP WAS SHIFTED WITH LLD. $ : ARCO ALASKA INCORPORATED : D.S. 3 - 25A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 CAL3 BCS 68 1 IN 4 4 TEND BCS 68 1 LB 4 5 TENS BCS 68 1 LB 4 6 NPHI 2435 68 1 PU-S 4 7 NUCT 2435 68 1 CPS 4 8 FUCT 2435 68 1 CPS 4 9 LL3 DLL 68 1 OHMM 4 10 LLD DLL 68 1 OHMM 4 11 SP DLL 68 1 MV 4 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 20 789 90 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 344 Tape File Start Depth = 12400.000000 Tape File End Depth = 8796.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 86509 datums Tape Subfile: 2 548 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 8550.0 8796.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CN WN FN COUN STAT CASED HOLE PORTION OF MAIN PASS. $ : ARCO ALASKA INCORPORATED : D.S. 3 - 25A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TEND GR 68 1 LB 3 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 21 990 60 6 4 4 10 579 41 1 4 4 10 579 41 1 12 * DATA RECORD (TYPE# 0) Total Data Records: 1014 BYTES * Tape File Start Depth = 8796.000000 Tape File End Depth = 8544.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2021 datums Tape Subfile: 3 34 records... Minimum record length: 22 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 5 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8550.0 12334.0 AC 11400.0 12394.0 2435 11250.0 12341.0 DLL 11400.0 12366.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC CAL $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC-ACOUSTILOG 3-ARM CALIPER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 23-MAR-93 FSYS REV. J001 VER. 1.1 600 23-MAR-93 1807 23-MAR-93 12395.0 12390.0 8550.0 12376.0 1800.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229EA/1229MA 3967XA 1609EA/1603MA 4290XA 8.500 8791.0 8796.0 KCL POLYMER 9.80 MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: MAIN PASS. NEUTRON IS CALIPER CORRECTED. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 3 - 25A : PRUDHOE BAY : NORTH SLOPE : ALASKA 47.0 10.0 6.0 181.0 0.122 0.037 0. 104 0.000 0.205 0.000 THERMAL SANDSTONE 0.00 0.000 0.0 56.0 181.0 56.0 0.0 56.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 GR AC 68 1 GAPI AC AC 68 1 US/F CAL-AC 68 1 IN CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L SSN 2435 68 1 CPS LSN 2435 68 1 CPS RS DLL 68 1 OHMM RD DLL 68 1 OHMM ED DLL 68 1 MV ES DLL 68 1 MV ID DLL 68 1 A IS DLL 68 1 A SP DLL 68 1 MV 4 4 06 969 49 6 4 4 48 852 89 1 4 4 94 885 22 5 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 83 368 34 1 4 4 84 023 70 1 4 4 40 514 81 0 4 4 39 859 45 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 23 415 80 5 * DATA RECORD (TYPE# 0) Total Data Records: 1187 994 BYTES * 72 Tape File Start Depth = 12400.000000 Tape File End Depth = 8544.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 379585 datums Tape Subfile: 4 1272 records... Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 4 0.2500 VENDOR TOOL CODE START DEPTH GR 11250.0 AC 11400.0 2435 11250.0 DLL 11400.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 12331.0 12394.0 12338.0 12363.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC CAL $ CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC-ACOUSTILOG 3-ARM CALIPER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 23-MAR-93 FSYS REV. J001 VER. 1.1 600 23-MAR-93 1626 23-MAR-93 12395.0 12390.0 8550.0 12376.0 1800.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229EA/1229MA 3967XA 1609EA/1603MA 4290XA 8.500 8791.0 8796.0 KCL POLYMER 9.80 47.0 10.0 FLUID- LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. NEUTRON IS CALIPER CORRECTED. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 3 - 25A : PRUDHOE BAY : NORTH SLOPE : ALASKA 6.0 181.0 0. 122 0.037 0. 104 0.000 0.205 0.000 THERMAL SANDSTONE 0.00 0.000 0.0 56.0 181.0 56.0 0.0 56.0 0.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 Name Tool Code Samples Units GR AC 68 1 GAPI AC AC 68 1 US/F CAL AC 68 1 IN CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L SSN 2435 68 1 CPS LSN 2435 68 1 CPS RS DLL 68 1 OHMM RD DLL 68 1 OHMM ED DLL 68 1 MV ES DLL 68 1 MV ID DLL 68 1 A IS DLL 68 1 A SP DLL 68 1 MV API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 969 49 6 4 4 48 852 89 1 4 4 94 885 22 5 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 83 368 34 1 4 4 84 023 70 1 4 4 40 514 81 0 4 4 39 859 45 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 30 739 95 0 4 4 23 415 80 5 72 * DATA RECORD (TYPE# 0) Total Data Records: 355 994 BYTES * Tape File Start Depth = 12400.000000 Tape File End Depth = 11248.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary? Rep Code: 68 89593 datums Tape Subfile: 5 438 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 6 is type: LIS 93/ 4/ 9 01 **** REEL TRAILER **** 93/ 4/14 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 14 APR 93 10:19a Elapsed execution time = 1 minute , 40.4 seconds. SYSTEM RETURN CODE = 0 Tape verification ~isti,~ cblumber.:~er g!asKa Computln~ Center 26-0CT-~ 994 !6:26 CONTINUATION ~ : P~EViOU~ ~EMb COM~E~T : ARCO ALASKa %NC., PR'[JDHO~ BAY, DS ~-~5~, 500292~02!0! D~TF : 94!06/~9 P~EVIOUS TAPE CON~E~:~T : ARCO ALASKA !NC,, ~F~.UI,)HC~E MAY, DS 3-25A, 50029~102~0~ LOGCING CO~PA~'~ Y ~ TaPF CRE~.TI~?~ jOB NU'MB~: OPEPATO~ W!~6S: SU~r~C5 LOC~TION TO~.NS~ID: FSL~ FWL: DEDRICK CRn[J~D bKV~L~ W~D[: CASING 500292i021 Ot ,.CHLI,IMBERGER ~',~ELL SERVICES 94~19 REYNOLDS 156; i014 2~ 62,00 61 O0 CU~VL SWlr't,' DATA - ~.bt, P~S,SF$ TO STAbiD.ARL~ft~EASU~ED DEPTH) tPPE~ W OI.~; CaS?bG DPILLFRS CASING MIT SIZE (IW) SIZE (I~) D~PT~ (FI) aEIGH~' 9.500 7.0UO 1~395,0 29.0 PAGE: 1 ,IS Tone Verif~catl, on L~st],nq ~cblumberc~er ~;!asKa Com;2utlno Center D!TF: LO~G~D~ !.224.2,5 2231.0 ~2217.0 12!,96.0 ~ 2!. BO,5 12~.20,5 12!1~,~ 1205~,S 12o58.o 1 2aSa, 5 1204~.5 ~2036,5 il~aO.s 1~4~ s . 11.~20,0 11780.5 ~1776,5 1176~,5 ~a SC~LUaBE~GE~ 12~25.0 ~2~24o0 ~22~6.5 12200.5 !2~97,0 ~2190,5 12~7~,0 !213~ o !2!07,0 12102.0 12094,5 12090.0 ~2075.5 12071.5 12060.5 !2060,5 ~2054,5 12OHO.0 1200a.5 !1031.5 11e83.5 1187~.0 l. Ia71.~ flaS~.~ ~1~54.5 11946.~ ~t~35.5 ~18~?.5 ~1~15,5 ~179~.5 ~177~,0 26-0CT-!994 i6:P6 ~L~., SERVICES U?$HIVTED DEPTH---------- PAGE: e Verif!cat!om Listt. t~ 26- ~' OC :..r.- ~ 994 16,' ~6 erqer ~!,as~a ¢omputin~ Center 176.4.5 11706,5 1760,5 1. 1762,0 175P,5 !1753.5 1175~.5 174~,:.~ 11746o0 1736,5 ~ !738,0 ]1716,5 ~!7J7,5 168~,5 ~.1690.0 ~ I690.5 I677,0 11677,5 1666,0 I!66~,5 !164~,5 !.. ~649,5 164.4,5 ~1645.0 163~,5 1163~.5 ~1620,5 1162.!.5 1~(:)~. 5 11603.5 !590.5 ~ i590,5 ~158~,0 11587.0 1584.5 ]I584,0 1.57~,5 !157~,5 156A.,5 ~1563.5 1560.5 1540,5 1154~, 0 laaO.s t. t481.o 1479,5 ! t48!.0 1~76.5 114.77,0 !14~,5 11447,0 !443.K ~ 1a43,5 ~1443,5 140 ,,~,5 1 }. 140!..5 11401,5 14'01 ,~ 1 !~-00.5 1361.5 135P.~ 11356.5 1 oo.r, 98,5 !o0.5 1NFOR~RTIOb PERTAT~INC T{3 2'P.E OPEN HOLE TIE-IN LOG, S!.~C~ ~S I.,OGGING COaoA~y [.~L}GGTNG DATE P~SS NU~P~R '~ERE NOT 'PR6VTI)E{;~ ~!TM ~H~ TAPE SI]PPbTED THE DFPT~; COR~ECTIO~S SMOwb ABOVE REFLECT C~SED HObE 1.'~ op~'~,, F;OLF; dR A~JD CnSRD hOLE NPnI TO PAGE: IS Tape Ver!,ftca. tion cblumberqer"Aiaska ComPuti~i6 center 26-OCT-!994 16:~6 ~AGE: F~L~ FILF ~O~B~R~ i DePth Shifted and clipped curves ior e~ch Pass ~n separate files D~P~H I~CRE~ENT: 0.5000 !.,DWG TOOI~ CODE START DEPTN S~OP DEPTH .. ..... .... .. .... ................ CRCH ~'22~0'0 ~.1~00,0 CMTH 12~47.0 CURVE SHIFT PITI - PASS TO mASSf~aS!l~a~ DEPTH) PASELINE CURVE FOR SHIFTS PASELI~,~E $ .......... ~(:).IVALE~T t..i'~IS~I'I~T~D DEPTH--- ....... RE~APK~: T~IS FI!~E CONTATilS PASS ~1 nF THE C~T!~.I. ND PASS TO PASS ,5~I~TS wEPE APP~ I~D TO THIS DATA. LIS F~Rt'~AT DATA BAY Field t~ame Well Name 50-o2~-~02~-o! Ap! Serial Number FSb & 2~' FE~ Field Location Section To~Dsh].D Ranae I~ ?a~e verif~cat~,on chtum~erqer t~!.aska Compute.n.~ Center PA~E: 5 T!,!~.:i ~ VAL[~ DEFI ~,.~. State or erovince ~Tt US.~ Nation S~N 453129 Serve. ce Order Number FDA? ~: $ [.~ Permanent datum EPD VT O. Elevation of Permanent Datum L.~F Rk~.b bo~ ~easured From APD r~T f2, ~bove Permanent Datum EKB FT 6~, Elevatlon of ~elly Bt~sh. inq EDF FT 61., Elevat~ oD of Derric~ Floor E~L KW 28. Elevat on of Ground 5evel TD[) FT 1~316, Total Depth - Dr~ller TDb F~F i.~289. Total Depth - bo~ger BLI rT 1~245, Bottom bog Interpal TLI FT ~12~0. Top bog InterVal D~[> ~/C3 ~'?0' - ~[lllin:~' FlUid Density TI~A~ 05. 3 2~-APR 93 me hoG,er at Bottom s~'r [,ECF !81. Bottom Hole Temperature NPH? Co~pensate(~ ~eutron Porosity, $8 Matrix, cal!& dead time corr. NPA? ~,~eutron Pation :¢;on-Dead time Corrected (~!/F) CPAT ~!e~t. roD Patio, Desd Time Corrected NCDT ~aw Hear Detector Count Pate, ~ead Time Corrected FC~T Paw Far Qetector Coumt rate, Dead Time Corrected CFTC Corrected Par Detector Coumt Rate C~TC Corrected {{ear Detector Coont Rate G~C~ Gam!~a Pay ~n Cas!.ng TFN~ .Surface CCL APl-Corrected Camma ~aV ~iIiIiii~iiII~I~ItIII~I~IIIIIIII~I--~I~I~IIII--~II Typ~ ~PP CU~E ~L~JE 1 66 o 2 65 0 3 73 44 4 66 IS Taoe Verification List]no chl,,mberger AlasKa ComDut!no Center 26-0CT-I994 16:26 PAGE: ~ 66 7 65 ....... i~ 6a 13 66 65 15 66 1.6 66 () 66 t 0 ** SET TYPE - CHAN ** N,AM~ S~V UNIT SE:~VlC,'.~,~ APl apl APl aP! PIt, E ~U~ NU~8 SIZE REPR PROCPgSS DE,. T F'T 4531~g O0 nO~ O0 0 I ~ ! 4 68 OOOO000000 NPHI CNTH PU-8 453129 O0 000 O0 0 I ! ! 4 68 0000000000 N~AT CNTH 453199 O0 000 O0 O I ~ ~ 4 6~ 0000000000 C~A? CNT~ 4531~9 O0 000 O0 0 1 1 1 4 68 O00OO00000 NCNT C~}.~ CPS 45~1~9 O0 OOO O0 0 1 1 I 4 68 0000000000 FCNT C~T}-! CPS 4531~9 O0 000 O0 0 1 ~ 1 4 68 O00000000O CFTC C~TH CPS 453129 O0 000 O0 0 I I 1 4 68 O000OO0000 CNTC Ca?H CPa 4531~9 O0 OOO O0 0 I !. 1 4 6B 0000000000 G~C~ C~H GAFI 453129 O0 OOO O0 0 1 ~ ], 4 68 0000000000 TF~$ CNTH LB .4,531~9 O0 000 O0 0 I 1 ! 4 68 0000000000 CCh C~ GaP! 4,53129 O0 000 O0 0 1 1. ~ 4 68 nO00000000 DFPw !22~().0o0 ~,~Pu I CNTH -999.250 NRaT. CNTH 999.250 NCN~CNTH -999,250 ~Ck~T ~ C~TH -999,~50 CFTC,CNT~ ~999,250 (;PC~, Ci'~ TH -909,250 T~NS.CNTN -999.25~ CC[,.C~TN 59.578 DEpm. 11.200.000 qPHI,Cr. Tw -qYa,250 NR/~T,CNTH -g99,250 NCN~ C~H 909.250 PCN'f. CU':P - . . .... .. .. ~, - . . T ~ 090 250 cPTC.CNT~ 999 250 G~C~;.CX~b -999.25C T~j~.;S. C~.3?Cu -qgo, 250 CCL.CUTH 281 .~07 CPAT.CNTH C~:TC.CNTH CRAT.CNTH CNTC.C~TH -9~9.250 -999.250 -999.250 -999,250 IS Tare Verification Listinm cbl.mberger ~lasKe Co.mput,!t~q Center 26-0CT-~994 16:26 S~RVICE ~ VFRSIOS : 00~COI RFC S!Z~ : I074 FILM NA~E : EDIT ,002 $~RViC~ : FL!C VERSION : 00~CO! D~TM : 94/06/~,9 ~AX R~C SIZE : !,074 FILE TYPE : LO L~ST FILE DePth sh~ft, ed and c1~,~ curves .... '.d ~or each mass in separate ~tles. 2 0.5000 DFPTH I~C~EMgNT I~OWG TO0!, CRCH CNTH START DEPTH !!56~.0 11370,0 bDWC CUn'~/~]; CODE: ~RCH PASEf,IN~ D~PTh 1156g.5 ~1564.K ~15~0,5 11547,5 11627,5 ~152a,K 11523,5 ~1520,5 .......... F~I.!IVALCFiT U~SHIFTED DEPTH- ......... GPCH CNTN - BO.~ ~8~ 1156],n 11554,0 1152~.o ~1525.n ~152~.5 11505,0 IS Ta~e ver.i.f!.cat!on ListJ..no chlumberger AlasKa Computino Center 26-0CT-1994 I6:26 ~1500,5 11500.5 ~ I480.5 !!.48!. 0 ,1.45~. S ~44a,~ l, i439 1 t440. ! 1436.5 11437.0 t a2~. 0 1.!a23.0 1413,5 11415.5 11407,5 t14~7,0 ! 1399.5 1!39q,5 ! 1399.0 11399.5 11395,5 . !379.5 11372.5 mE~'~!APKS: THIS FILE CONTAINS PASS ~2 OF THE CNTH. THE DEPTH CGRRECTIOUS S},!OW~ A~OVE: ~E~L~CT PASS ~2 GRCM TO PASS G~CH AND PASS ~2 MPHI TO PASS ~]._ NPHi, ~LL OTHE~ CNTH CURVES I,~F~E C~R~IED ~ITF'~ ~ME NPHI SHIFTS, L~S F~RMA, T DA~A API~ 50-029-21021-01 f'L 1Oi4' FSL $~C~ R~i~G 15~ COU~ NQ~TH ~t,OPE S~AT ALASKA NAT! U~A WIT~i SON 4531.29 PDA~ ESL gPO ~T L"F APO FI 62, EK~ FT Well Name AP1 Serial Number ~ieid Location Section Township Ranae County State or Province Nation Witness ~ame Service nrder ~umber Permanent datum Elevation of Permanent Datum Lo~ geasured From Above Permanent Datum Elevation o~ Kelly ~usbinQ Elevation of Derric~ FI. nor Elevation of Ground Level IS Ta~e Verification I.,ist~,na cblu~berger Alaska Computi. na C~nter 26-['~CT- J. 994 16:26 T!,li~! VALU D~FI TDL FT I~2~9. TOtal DePth ~!,I ?T !~245. ~ottom bo~ Interval TLI FT 11200' TOD Log 'Interval DFT SEAWATER Orll!J,.nq Fluid Type DFD G/C3 8°4 Drlilinq Fluid Density LA~ 0~:o3 23-~.PP-93 Time i..o~oer at Bottom I~T DEGF 187. BOt, to~i Ho ? . 1~- ~per~ture N~fl! Co,~pensated ~eutron Porosity, SS Matrix, call & dead time corr. N~AT ~:eutron ~ation '~ ' l~on Dead time Corrected CPAT 5!eutron aatio, Dead Time Corrected (RN/RF) NChT Paw ~ear Detector' Count Pate, Dead Time Corrected ~'CNT Paw ~ar Detector Count rate, pead Time Corrected CFTC Corrected war Detector Count Rate CNTC Corrected ~ear Detector Count ~ate GPCM ~ami~a ~av in CaS!hQ TWNS Surface Tension 1 ~6 4 66 5 66 6 7~ 7 65 9 65 17 68 !] 66 0 i~ ~5 PT 66 66 ImIII~I I III I Iii~iiiillmIiIIIi IS Tape verificat.lon L!stlno cblumberqer Ala.sKa Computino Center 26-0CT-!994 16:26 PA~ ** ~T TYPE - CH~N ** ID ORDE~ ~ LOG TYP~ CheSS gOD NUmb SA~P ~E~ CODE (HEX) '"'"'"'"'[["' ....... '; ..... '"'"'"'"" .... 'i'"'"'"'" ...... D~PT ~5~129 0 00[! O0 0 2 I 4 68 O00000OO P!!-S 45~i29 00 000 00 0 2 1 I 4 68 0000000000 N~AT OaTH 453129 O0 000 OO 0 2 I t 4 68 0000000000 C~AT CNTH 45~129 00 000 00 0 2 i i 4 68 0000000000 NON? CB~ CP~ 453129 O0 000 O0 0 2 i ! 4 68 0000000000 FCa? CNTh CPS 4531~9 00 000 O0 0 ? I 1 4 6~ O0OO000000 CFTC CNT}'~ CP~ 453129 O0 000 O0 0 ~ 1 ]. 4 68 00000000O0 CNTC CNT~.{ CP~ 45~199 PO 000 PO 0 2 1 1 4 68 0000000000 GRCM CNTM GAPI ~53i29 O0 000 O0 0 2 I 1 4 68 0000000000 T~N~ CN~ bB 453129 O0 O00 O0 O 2 I I 4 6~ 00000O0000 ** DhTA ** DEPT, 1j'925 438 ~C[:,~,,Ci"4T~, 51° 5~3 DEp~ 1t370 {)o0 r~PPl CNTH 54,770 N-CN~C~.~{.'.TH 1167,438 FCNf,CNT~ 297,594 G~CFI ' CNT~ 1.56, ~5 T~]NS.CMTH 4205,000 END OF PA'fA ** NRhToCNT~ CFTC,CNTM NRAT.CNTM C '' CN ,~FTC, 'TN 3.590 CI~AT.CNTH 541.063 CMTC.CNT~ 4..!25 C~AT.CNt~'! 2g~.~777 C~!TC.CN~M 131 FILF NA~E : MDIT ,002 VFRSION : nO,COl D~Tr ~ M~X R~C SIZE : 1024 FILW TYP~ ! LO **** FTL? ~E~DKR **** S~RvlcE : wLIC VERMImS! ! nOlCOl D~TF ~ 04/06/~9 MAX ~FC SlZ? : !024 LIS· F!!.,~ : i~ Tare Vet.fir. cat,.on ListfnO AVE~A~E~ ~ompensate~ ~eut. ron: Arithmetic aver'a~e of: ed].te-~ ~as~es ~or all curves. ulSed Neutron: ~naveraoed e~ite~ Pass I Gamma ~aV' and bac~round counts; arithmetic averaoe of edited static baself, ne passes fer all ot~r curve~. DEP~bl INC~E~:~T 0.5000 PaS~ES INCLHDEO I~:~ AVERAGE .... " ..... ";7""", TI,t~! VALU DMFI C~' A.~CO ALASKA, INC. Compamy F~ PRUDHO~ SAY Field Name W~:~ DS 3-25A Well Name API~ 50-029-~02!-01 AP! Merlal Number FL !0!4' FSL & 29' FEb Field Location SFCT 10 Section TO~ 10N Township R~c 15E Range CoU~ NORTH SLOPE County Sram ALASKA State or Province NATT USA Nation W!T~ R~Y~tOf, DS WitDesS Name $0~ 4531.29 Service Order Number pDAT MSL Permanent datum 5PD ~ 0. Elevation of Permanent Qatum L~F FK~ Loq ~easured From APD WT 62. Above Permanent Datum EE8 VT 62, Elevation o[ Kelly EDf' ~T 61. Elevation of Derric~ Floor ECL FT 2~. Elevati~on o~ Ground bevel TDD FT 12316. Total DePth -Drlller TDL PT 12299. Total DePth - Looger ~[,!' F? 19245. Bottom boo Interval TLI WT 11200. TOD ~,oo Interval DFT SFAWATE~ Drilling FlUid Type DmO ~/C3 S ~ ~illiDO Flu~O Density TI, AP 0~;03 23-App-o3 .&me Loqoer at Bottom ~HT DEaF 1~7. Bottom Hole Temperat~re Tame Ver!f.~.cat:i, on Li~tI. na ;c~lu~berger ,Alaska Computinq Center 16:26 DFF! NDHI Compeosated Neutron ~orosity, SS ~atrix, cal,! & dead time corr, N~A? {eut~on ~atton No,-Dead ti~e corrected C~AT ~eutron ~atio, Oead ~ime Correcte~ (RN/RF) NCNW ~aw ~ear Detector Count ~ate, Dead Time Corrected FCNT ~aw Far Detector Coumt rate, Dead Time Corrected CFTC Corrected Far Detector Count Rate CNTC Corrected Near Detector Count ~ate G~C~ Ca~ma ~av T~N$ S~lrface Tense, on PAGE: 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT 11. 66 ~5 I? 68 13 66 0 15 66 68 0 66 ~ '~:~. '"~.. .~,v ................ ,~,~? ~:;~c~,_ "''''A~ ;~i ........ ~ ~i'F~,,~ ~,,,~.~ ,~:~ ...... s~zE";~;'""'~"~o_.~"' b , TYPE CLASS EOD ~{U~8 SA~4P ELE~ ODE (HEX) DFPW FT 453179 aO 000 00 0 ] l I 4 68 0000000000 NPHT Ct ~V PU-S ~531~9 O0 000 O0 0 3 1 I 4 68 0000000000 NPAT CNAV 453179 O0 000 O0 0 ~ ! ! 4 6B 0000000000 CPA~ CNAV 453!~9 O0 00~ OU 0 ~ ! 1 4 6~ O0000nO000 NCNT C~;AV CPS 453!~9 FCNT C~A¥ CPS 4.5~! 99 00 O00 00 0 3 1 1 4 68 0¢>00000o00 CFTC C~,aV CPS a-53i29 O0 000 00 0 3 1 i 4 6~ 0000000000 iS ~'a~e ¥'erf..ff.~.catJon Listlno ch!umber~jer AIas~a Compt!tflno Center 26-0C~-1994 16:26 .... SE. v U~!IT SE V AP1 FILE NUmB NUMB S REPR ID ~RDE:R ~ LInG TYPE CNTC CNAV CPS ~53129 oO 000 O0 0 3 1 1 4 68 0000000000 G~C~ C~Av GAP! ~5~199 O0 000 O0 0 3 I 1 4 68 O00000000O T~N~ C~A'V' LB 45~!~9 O0 000 O0 0 3 ! i 4 68 0000000000 * * D A T A * * G~C~, C!'~ ~V 59~,393 T~;N$,CNAV 4~97.859 ~,~ R A T · C N A v CFT.~,CNAV 7 CRAT.CNAV **** FILE TRA ILE,P. **** FILE ~A~E : EDIT .003 SERvicE : FLI'C 'VERS I Of,~ : 001C01 D~TF : 94/06/].9 FILF~ TYPE : LO **** FTbM HEADER S~RVICE : rbiC DATF : FIL,~ TYPE : LO FILm VP;~DOR 'rmOI; CODE ~I'~R· DEPTP STOP DEpTr! ,, 2 .......5 11354,5 ~lles; raw backoroumd pass in last fi IS ?a~e ver,!ficatJ, on [,~istJ.'n~ chlumherger Alaska ~omPutino Ce~te~ 26-OCT-1994 1,6:26 14 DATE 'bOGgED: SOFTWARE VER$IOi~: TD DPi[,,[~ER CBT): ~1) LOGCER (FT): TOP LOG !NTE!~VAL BOTTOM bOG INTeRVAl, !~OGGING SPEED (ffPHR) DEPTH CONTROL !ISFD (YES/NO): TOOL STDING (TOP TO BOTTOa) V~I~?DO~ TOOL CRUDE TOOL TYP~] CNTH TEbFa~TPY CARTalDGE CNT~~ CO~PE~ISATED C~:~TH COaPENSATED OPg~,~ HOLg BIT $I'Z~ PRILLERS CAS!L~G DEPT~ (FT) LOCGFRS CASISG FLUID TYPE; SI.,t~FACE TEL~PERATUPE (DEGF): BOTTOu MOLE T~MPERATUPE (DEGF): F!.,U~ P 8g h!~,~ !TY FL~IIP I,,EVE!~ FLUTD RA'TF a'i" WATFR. CUTS rPcT) CHO~'E (DEC): iiOb~ CORRECTIOn: C!N) 23-APR-9~ 5C0-423 5O3 !,23i6 0 1.2245.0 1500-0 SANDSTONE ~.65 8,500 23-~.PR-93 CAL-Y ]0 TCC-B 28I SGC-SA 50 CbC-MA 398 50O SEAWATER 8.40 187.0 Pap COU'~T ~ATF~ bOW SCAI,E (CPS): mAP COI~r~T PATE[: d!(;~ SCALE (CPS): ~EAR COL;MT RA%E bOW SCA[,M WEAR COUNT i-~T~ NIGH SCALE iS Tape Ver!f!ca.t.~oD Listin~ chlum.b-erger AlasKa ComD%.~tln~ Center 26-0CT-1994 t6:26 15 T©OL STA~,:DOFF {I~)~ RKN:~RKS: THIS :.<~ELL WAS LOGGED USIN~ WI~ELIME P~I~APY DKPT~ CONTROL HOL~ CO~R~.',:ION=~]TT S!ZK~ :[~8=8,5"., . THE ~A!N AND REP~:AT P~SS ~O~ TH~: US!T AND C~L USED THE ~CDUST.IC COL[,A .:' ~ L:OCATD~ FPO~ TEE I~CIT . . .... ~ ..... '. ~ FiNaL PAS6 ~N.A~ ~DK ~!TH THE_ USIT TU~NKt~ OFF, ~'~D THE ~AGNKTIC COL, LAR bOCATO~ TU~KD ON, THIS ~ o!u Nn - r_.': CO:bARS 'THAN THE ACOUSTIC LOG DID LiS FORNAT DATA TYPE : CONS CN FN PRUDHOE BAY WW DS 3-25A AP!~' 50-029-2102!-0I FL 1014' FSL & 29' F~L SFC? Io R~NC COUN NORTH SLOPE 8TA? ADASK~ N~TT USA WTTN ~YNOLDS SON 4531.29 PDAT MSL EDD F7 0,. AP[) VT 6?, EKa ~T 62, EOF Ky 61, ECL MT 2~. TOD MT TDL WT 122R9. BLI VT 1~245, TLI ~: 11200, OFT SEAWATER OFD C7C3 ~.~ T!,AD Field Name Well ~ame AP! Serial Number Field Location Sectl, on Township Range County State or Province Nation Witnes~ ~a~e Service Order Number Permanent datum Elevatlom of Permanent Datum Log Heasured From above Permanent Datum Elevation of Kelly B,lshin~ Elevatiom of Derrick Floor ElevatJom o~ Ground Level Total Depth - Driller Total Depth - Logger Botto~', bog Interval TOD Log Interval Dr~ll, in~ Fluid Drilling Fluid Density Time L, og~er at Bottom 18 Ta~e Vertfi, cat!on bistlna chlumberger .Alaska Co~putI, r~o Celt:er 26-0CT-t994 16:~6 DEPT De~th ~P~l Compensated ~eutron Porosity, 88 ~atri×, call & dead time corr, R~N~ ~aw Taermal ~eutron~at~o TNR~ Thermal ~eutron aatio Cal. lhrated RCFT ~A~ FAR CNT COUNTS C~TC Corrected ~ear Detector Count pate CFTC Cerrectea Far ~etector Count ~ate G~ ~P!-Corrected TENS ~urfac~ CCL CC!., Ampl~tuOe PAGE: ~6 DATA FOR_~',~AT ~e~PKCII?TCATIOl~,! RECORD ** ** SET TYPE - 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 ,~g n 5 9 1! ~6 23 17 68 13 66 o 14 65 FT 15 66 68 1.6 66 1 u 66 . ........................... ........... DFPT FT 4531~9 oO 000 O0 0 4 I I 4 68 O0000000OO Nmfi? p$1 pl.} 453129 O0 o00 oo 0 4 1 1 4 68 6000000000 R~NR PS~ 453l~9 O0 000 OO 0 4 1 I 4 68 OHO0000000 ,r~R~ ~51 453129 r)O OOt) O0 o 4 1 i 4 68 onooooo00o RCNT ~$1 CPS 4b't1~9 OU 000 oO o 4 I t 4 68 0000000000 RCF? PS~. CPS 4531~9 nO 000 O0 0 4 1. I 4 68 0000000o00 1S Tane Verification Listing chl.mber~er AlasKa Ccmputin~ Center 26-OCT-!994 16:26 PAGE~ I¸7 N~ SFBit UNIT E~'~V CE API AP1 P F C~TC PS! CPS 453129 O0 000 O0 0 4 1 1 4 68 GO00000000 CfTC PSt CPS a5~I~9 o0 000 O0 0 4 ! 1 4 68 O000000OO0 G~ P5~ GAP! 4531P9 O0 000 O0 0 4 I 1 4 68 0000000000 TENS PS~ LB 4531P9 O0 000 O0 0 4 i i 4 68 0000000000 CCL ~Sl ¥ 45~129 ~0 000 O0 ~ ~ I I 4 68 0000000000 ** DaTA ** DE~T 12290.500 N.PHI'PSl 23.677 ~TNR,PSI RCMT P$~ 2007.75~1 P. CF2,PSI 855 453 CN...C,PS1 GP,PS! ~6.855 TENS,PSI 2415.000 CCL,P~l D~PT 11.]54.500 NP~II.PSI 56.976 rTNk,PSl GP,PS~ 79:,9~1 TESS.PS1 4040.000 CCL.PS1 ** E~D 0~ DATA ~ a 29 TN R 1~. PS t, 2024:9]~ CFTC'~81 0.91.7 888 * 709 4 697 T~RA.P$! 4.~13 10021749 CFTC,Pal 245,~33 '999' ~50 **** FILE TRAILED **** FYLF ~A~E : EDIT ,004 SERVICE : FLIC VFRSI~ : O0!COl DATV : 94/06/!9 MaX R~C STZE ! !074 FTbF TYP~ : LO FTLW ~A~E : EDIT .005 SFRVICE : FLIC VE~IDA : OOlCO1 D~T~ : 94/06/~9 ~X ~C SIZe: : !024 FTL~ TY~E : L~$~ FIt,E Fib~ ~.! U ~ P~i 5 RaW C!IRVLS Curvo$ and 1o~ t'~eader data for each pass in separate fi. les: raw backCroumd pass In last fi chlumberger Al.a$~a Computinq Center 26-~CT-~.994 1:6:26 PAGE: !¸8 # F!L~ VENDO~ TOOL CODE START DEPTH SOFTWARE TI~E ~OGGgR ON MOTTO~: WD DR~LLER TD LOGGER{PT): ~OTTO~ LOG INTerVAL DEPTi~ CO~!IROL USED (YES/NO): TOOL C~D~ TOOL TYPE C~TH C~T~ C~TW C ~! T ~ LOCA~OR TEbENETRY CARTRIDGE RAY COMPENSATED ~EUTRON ~OPE~OLE A~D Ca6IN~ DATA OPEN HOLE BIT 5!ZE DRILLERS C~SING DEPTH LOCG~S CASING DEPTH ~OPEHC~.~ CO~D!TiO~$ FLUID DENSITY {LB/G): SURWACE TEmPERATe;RE (DEGF): bOT~6~ NOL~j TFMPERATORE (DEGF): FLUID S~LI~IT¥ FLUID G.~6/O~b RATIO: CuC~E CDEG): STOP DEPTH 23-APR-9~ 5C0-423 50] 2]-AP~-93 ~,2316 0 1200 0 1,500,0 YES TCC-B 281 SGC-SA 5O CNC-HA 398 C~-A 8.500 SEA~ATER 8,40 187.0 ~ETTHE~ SANDSTONF 2.65 8,500 IS Tame Verification Listin~ chlumberger Alaska Computino Center 26-0CT-1994 !6:~6 FA~ COUNV ~ATE bO~'~ SCALE (CPS): YAP COt}NT ~ATE HIG~ SCALE (CPS): ~E~,R COU~.~T ~ATF LOW SCALE (CPS)' T~IS w.~fL L METMODS, INCL{~DI~.~C ~:~A~NE~'IC ;~AR~S ON WIRELINE, THIS ~!MML!NE w~S' ~APRFD (~}' I.PPlL I9, 1903,,A COMPARISON bOG W~8 AVA~tb~[~:t,~. !T ~AS TNE BHC'G. (ATLI,S) OF 3-31-93, THiS I~OC WA$ P~OT TIED i~TO Ta~ BHC-aR bOG. YHf~ C~L LOG ~4A8 RUN O~CASED NOLE, SANDSTONE MATRIX. MOLE COD ~ REC,IO,i-BIt o!Z~. ~,..-~.5 .: THE .AIN AND REPEAT PASS FOa THE USIT AND CML USED THE ACOUSTIC COLLAR LOCATOR OFP, ~,~ T[-!~ t~.A(I'NETIC COLLA~ LOCATOR TURNED ON. TMIS PASS DID i~iOT HAVE MI,iCa BETTE~ COLLARS THIN THE ACOUSTIC LOG DID. DATA TABLE TYPE : CONS T t],i~ I VALU DEF! CN A~CO ALASKA, INC. F~ P~UDHOg API~~ 50-029-21021-01 FI~ 10!~' FSL & 29' F~b SEC~ 10 TmW~ 10N R~C COU~ NORTH SLOPE STAT ALASka N~T~ USA WIT~ RE,MOLDS S~N 4531.29 PDAT ~iSb EPb ADD rT 62. EUF ~T 61, ECL WT DF7 T!,A~ 05:03 23-AP~-93 Companv Name Field Name Well Name AP1 Serial Number Field Location SectloD Township ~aDge Count~ State or Province Natio~ witness ~ame Service order Number Permanent datum Elevation of Permanent Datum ~o~ ~easured From above Permanent Datum ~levatto~ of Kelly Bushin~ Elevation oi Derrick Floor Elevation of Ground Level Total DePth - Driller Total. Depth - Lo~ger Botto~ Log Interval TOD I,OG Interval Dr!llinq F!ui, d Type Drlllin~ f'lulo Density Time boooer at Bottom 26-[~CT-1994 16:P6 187. Bottom hole Temperature ,, DFPT Depth .. ~ cal,~, & dead ti. me corr, NDHI Compensated Neutron PoroSlt¥, o,: ~atri.~, RT~ ~aw Thermal Neutron ~atio TN~:~ Therma~ Net~tron Ratio Calibrated RCNT RAW ~EAR C~T COU~TS CNTC Corrected ~!ear Detector Count ~ate CVTC Corrected Far Detector Count Rate G~ APl-Corrected ~amma CCL Aapl!tuOe 2 66 3 73 44 4 66 6 73 7 65 8 68 0.5 9 65 12 1~ 65 15 66 16 66 0 66 ,IS Tape Verification Listin~ ;ch.lumberger AlasK~ Co~p,.!t!nc Center 26-QCT-1994 16:~6 PAGE~ ** SET NA~ ..... PEP? FT R~ND PS2 RC~ P$~ CDS RCFT DS? CP5 CNTC P8~ CPS G~ P8~ GaPI CCh PS~ TYPE - CHAN ** · ICM Ami PI APl A B ~t..! M g lZ REPR PR UCE,,.. S ~RDER ~ LOG TYPE CG.~SS ~OD ~;t..]~ SA~P EDE~ CODE (HEX) 4531~9 O0 000 O0 0 5 1 I 4 68 0000000000 4531~9 O0 000 O0 0 5 I I 4 68 0000000000 4531~9 00 000 O0 0 5 I ! 4 68 0000000000 4531~9 O0 000 O0 0 5 1 I 4 68 0000000000 4531~9 O0 000 O0 0 5 I, I 4 68 0000000000 453129 O0 000 O0 0 5 1 I 4 68 0000000000 4531~9 O0 000 O0 0 ~ I I 4 68 0000000000 4531~9 O0 000 O0 0 5 1 I 4 bO 0000000000 453129 O0 000 OO 0 5 i 1 4 6~ 0000000000 453129 O0 OOO O0 0 5 1 I 4 68 0000000~00 453129 O0 GO0 O0 0 5 I. 1 4 68 0000000000 2i ** DATa ** DEPt. I ] 601.500 ReNT; G~.P62 47. 030 DEpt, 11364.000 ReNT.PS2 !072.933 GD.DS~ 88.44,7 ** END OP DATA ** ~PHI.P82 59. i!2 mTMR-PS2 4.968 T~Pa:.P$2 RCFT,PS2 ~14.920 CNTC-P$2 1097.679 CFTC.P$~ T~S.P$2 4~50,000 CCLoPS2 -999.~50 2.481 628.517 4.368 245.320 **** FIbP TRILLER **** FTbF MA~E : FD!T SERVICE : wbIC VERSION : ~O~COi DnT~ : o4/06/~9 FTbF TYPE : T.,O **** 'rape TRAILED **** D~TF : 94/06/19 ODI~iN : FblC T~pF ~!A~g ! 94219 pRgvIOb8 TAPE PRUDHUF: ~AY, DS 500~92102101 IS ?ace Ver.~,f~.cat!on bi, st~na c~lUmberger Alaska Computing. CeDter 26-(~CT-! 99,g 16:26 PAGf: O~ICIN ~ FLIC REEL ~A~. : 94219 CONTINUAl !0~,~ ~ C~4~E~,~T : aRCO hLASKA INC., PR.~DH(.~ 8AY, DS 3-~5A, 50029~10210! BP Exploration Alaska Inc Well: 11-04A Field: PRUDHOE BAY UNIT North Slope, Alaska, USA Report Production Array Log Analysis Prepared For : BP Exploration Alaska Inc Logging Date : 22nd August, 2014 Report Date : 13th October, 2014 Submitted by: Farrukh Hamza Phone: +1(281)871-3048 10200 Bellaire Blvd, Houston, Texas-77072 Email: farrukh.hamza@halliburton.com HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF BP Exploration Alaska Production Array Log Analysis 1 TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY ............................................................................................................................. 2 2.0 BACKGROUND AND OBJECTIVES .......................................................................................................... 3 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT ............................................................ 4 4.0 PRODUCTION LOG PROCESSING ........................................................................................................... 7 4.1 FLOWING SURVEY ...................................................................................................................................... 9 4.2 SHUT-IN SURVEY ...................................................................................................................................... 23 BP Exploration Alaska Production Array Log Analysis 2 1.0 EXECUTIVE SUMMARY Production logging was done in Well 11-04A on August 22nd, 2014 in flowing and shut- in conditions with the objective of identifying the feasibility of water shut off treatment. In order to accurately quantify the flow of water, an array production logging suite was run. The flowing PL analysis showed 92% of the oil production to be coming from 3rd set of perforations (9080’ – 9096’). The 1st, 3rd and 5th perforations account for 54%, 19% and 23% of the water production respectively. Gas production is mainly coming from the 3rd perforation. During the shut-in passes, a cross flow was observed from 3rd, 4th and 5th perforations into 2nd and 1st (the top two) perforations. The reported rates are 8,467 STB/D water, 288 STB/day oil and 7600 Mscf/D gas. Interpreted rates for water, oil and gas are higher by 12%, higher by 4% and lower by 16% respectively. Perforations Water Rate Oil Rate Gas Rate From, ft To, ft STB/D % STB/D % Mscf/D % 9022 9043 5187 54.2 0 0.0 0 0.0 9051 9064 0 0.0 0 0.0 637 10.0 9080 9096 1785 18.7 272 91.9 5705 90.0 9108 9118 280 2.9 24 8.1 0 0.0 9128 9149 2149 22.5 0 0.0 0 0.0 9170 9184 167 1.7 0 0.0 0 0.0 9568 296 6342 BP Exploration Alaska Production Array Log Analysis 3 2.0 BACKGROUND AND OBJECTIVES The objective for running the PL was to allocate oil, gas and water in producing zones and identity the feasibility of water shut off treatment. BP Exploration Alaska Production Array Log Analysis 4 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT Well 11-04A is completed with 7” production liner across which the production log was run. The wellbore schematic is presented in the Figure 1. The tool string diagram used for the PL logged is presented in Figure 2. The tool string consisted of the following production logging sensors: Gamma Ray - Casing Collar Locator – Pressure - Resistance Array Tool – Gas holdup – Caliper – Radioactive Density –Capacitance Water Holdup – Inline Spinner – Temperature – Caged Fullbore Spinner. The data quality is summarized below TOOL USAGE LOG DESCRIPTION LOG QUALITY REMARKS WELL BORE PARAMETERS QP Well bore pressure Good TEMP Well bore temperature Good FLUID TYPE FDR Radioactive density tool uses radioactive source and detector to measure density and is a center sample device Good CWH Uses capacitance to measure the differences between hydrocarbons and water Good Used qualitatively in the interpretation RAT Resistivity Array Tool Good GHT Gas HoldUp Tool Good Used qualitatively in the interpretation FLUID VELOCITY CFB Caged Fullbore Spinner Good ILS Inline Spinner Good Used qualitatively in the interpretation SAT Spinner Array Tool Good . BP Exploration Alaska Production Array Log Analysis 5 Figure 1: Wellbore Schematic BP Exploration Alaska Production Array Log Analysis 6 Figure 2: Production Log Toolstring BP Exploration Alaska Production Array Log Analysis 7 4.0 PRODUCTION LOG PROCESSING The production log data from the flowing were processed using the PLATO software. The software uses a global probabilistic method for the production log analysis. In this method, known as the Maximum Likelihood method, a well flow model is compared to all available data and improved, by optimization, until the best possible match with the data is obtained. By using this method the result is the most likely interpretation. A comparison between the model and the data is shown in this report and allows the analyst or the reader to determine validity of the answer obtained. Potential sources of discrepancies include tool measurement errors, conflicts between the parameters or conditions that make the underlying empirical models (such as flow regimes) less applicable.  The flow regimes were determined, directly from the flow rates and holdups, according to the Taitel- Dukler analytic model.  The profile factors, to calculate the true fluid velocity from the apparent velocity, were based on the Reynolds numbers.  Solution gas in oil was derived from the correlations (Vasquez-Beggs or Øistein- Glaso). The analysis was performed in six steps:  The data preparation to filter the data, compute gradients and error estimates.  The calibration of the array tools and full-bore flow meter.  The computation of the layered holdup and layered flow-rates.  The profile determination to identify the potential producing and/or injecting zones.  The computation of the flow rates by global optimization.  The computation of surface productions and reporting. BP Exploration Alaska Production Array Log Analysis 8 The water density and viscosity were calculated using a salinity of 20,000 ppm. The Craft & Hawkins correlation was used. The oil density and viscosity were calculated using an oil gravity of 32.8 API. The Vasquez & Beggs correlation was used to calculate the solution gas. Viscosity was calculated using the Beggs & Robinson correlation. The P c and Tc parameters were calculated using the Brown et al. correlation. The gas viscosity was calculated using the Lee Gonzales Eakin correlation. The following gas parameters were used: GasType Miscellaneous SPGG UNITY .747 GP-CO2 UNITY .124 GP-H2S UNITY 0 GP-Nitrogen UNITY 0 Utilizing the above fluid information, measured down hole oil density, temperature & pressure, the following fluid properties were calculated at well conditions: Depth Twf Pwf Bwater waterwaterBoil oiloilRsb Bgas gasgas feet °F psi UNITY g/cc cP UNITY g/cc cP ft3/bbl UNITY g/cc cP 8690 182 2987 1.02 0.993 0.365 1.03 0.833 2.84 538 0.00551 0.166 0.0202 8745 182 3003 1.02 0.993 0.365 1.03 0.833 2.84 542 0.00548 0.167 0.0202 8800 182 3019 1.02 0.993 0.365 1.03 0.833 2.84 545 0.00546 0.167 0.0203 8854.5 182 3034 1.02 0.993 0.365 1.03 0.833 2.84 548 0.00543 0.168 0.0204 8909.5 183 3050 1.02 0.993 0.365 1.03 0.833 2.83 552 0.00541 0.169 0.0204 8964.5 183 3066 1.02 0.993 0.364 1.03 0.833 2.83 555 0.00538 0.17 0.0205 9019.5 183 3082 1.02 0.993 0.364 1.03 0.833 2.83 558 0.00536 0.171 0.0205 9074 183 3096 1.02 0.993 0.363 1.03 0.833 2.82 561 0.00534 0.171 0.0206 9129 184 3117 1.02 0.992 0.361 1.03 0.832 2.81 564 0.00532 0.172 0.0207 9184 184 3129 1.02 0.993 0.361 1.03 0.832 2.81 567 0.0053 0.172 0.0207 To estimate the flow rates, the caliper log recorded during the UP and DOWN passes was used to estimate the nominal ID throughout the log. Tool information The following capacitance tool characteristics were used HydroWater Hz 28630 (Downhole measurement) HydroHyd Hz 34542 (Surface Calibration) The following gas holdup tool characteristics were used GasHoldupWater Hz 43699 (Downhole measurement) GasHoldupGas Hz 15592 (Surface Calibration) BP Exploration Alaska Production Array Log Analysis 9 4.1 FLOWING SURVEY The raw data from the flowing survey are presented in Figures 3 to 8. Figure 3 has the data from conventional production logging sensors. Figure 4 has the same data that was presented in Figure 3 with the addition of the station measurements. To generate this plot, Emeraude software was used which allows overlay of the station measurements and the logging passes in the same track. Plato can only plot the station measurement against time. For the interpretation, all the passes have been used. The response from the Resistance Array Tool is presented in Figure 5. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values. Only the active sensors were used in the interpretation. Figure 6 shows only the active RAT sensors along with the station measurements. The response from the Spinner Array Tool is presented in Figure 7. Both fullbore and inline spinners are showing a good response. Figure 8 shows the station measurements. From the raw data, various trends can be observed. Most of the gas production is coming from the third perforation from the top (capacitance increases & density log values drop to about 0.55 g/cc). The inline and fullbore spinners move significantly across 1st, 3rd and 5th perforations. Across the 3rd perforations, temperature and gas hold-up decrease indicating gas inflow. Capacitance data is also responsive, for example, increasing across the 3rd perforation indicating hydrocarbon inflow and decreasing across the 1st perforation indicating water production. From the spinner response, the velocity profile was estimated using the slopes calculated from the spinner calibration (Figures 10 and 11). The calibrated RAT response is presented in Figure 12. The estimated SAT velocities and the RAT holdups are used to calculate the flow profile presented in the Figure 13. The final flow profile, after the global optimization, along with the comparison of the measured and theoretical tool values are presented in Figure 14. The production rates at surface conditions estimated from the production log analysis are presented in Figure 15 and are summarized in the table below: Perforations Q-Water Qp- Water Q-Oil Qp-Oil Q-Gas Qp-Gas From, ft To, ft BFPD BFPD BFPD BFPD MCFD MCFD 9022 9043 5187 9568 0 296 0 6342 9051 9064 0 4381 0 296 637 6342 9080 9096 1785 4381 272 296 5705 5705 9108 9118 280 2596 24 24 0 0 9128 9149 2149 2316 0 0 0 0 9170 9184 167 167 0 0 0 0 BP Exploration Alaska Production Array Log Analysis 10 Raw Data - The figure below summarizes the input data recorded at the well site during flowing passes. - Each pass is shown with a fixed predefined color. Figure 3: Input data from the conventional production logging sensors BP Exploration Alaska Production Array Log Analysis 11 Figure 4: Input data from the conventional production logging sensors along with the station measurements. BP Exploration Alaska Production Array Log Analysis 12 The figure below shows the RAT input data. The first track shows the RAT rotation curves for each pass. The next 06 tracks show the RAT data for 6 active probes. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values and were not used in the interpretation. Figure 5: Input data from the Resistance Array Tool (RAT) BP Exploration Alaska Production Array Log Analysis 13 Figure 6: Input data from the Resistance Array Tool (RAT) showing just the active sensors along with station measurements BP Exploration Alaska Production Array Log Analysis 14 The figure below shows the SAT input data. The first track shows the SAT rotation curves for each pass. The next tracks show the array spinner data: A curve for each pass for each of the 6 array spinners and for the fullbore spinner (ASpinner07) and the inline spinner (Aspinner08). Figure 7: Input data from the Spinner Array Tool (SAT) and conventional spinners. BP Exploration Alaska Production Array Log Analysis 15 Figure 8: Input data from the Spinner Array Tool (SAT) and conventional spinners along with the station measurements. BP Exploration Alaska Production Array Log Analysis 16 Pre- Processing Figure 9: All the passes have been used in the interpretation BP Exploration Alaska Production Array Log Analysis 17 Calibration of Spinner Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and measured Array Tool responses. Track 2: Line-speed for each pass. Track 3: 'Unwrapped' rotation curve for each pass. Track 4: Normalized layered velocity profile. This profile is optimized by comparing the measured and theoretical SAT response for each pass of each spinner. Tracks 5-10: Measured and theoretical SAT responses for each spinner. Track 11: Measured and theoretical responses for the full-bore spinner. Track 12: Measured and theoretical responses for the inline spinner. Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. Figure 10: Velocity profile from SAT data BP Exploration Alaska Production Array Log Analysis 18 The image below displays cross plots for the Inline and fullbore spinners. The estimated slopes are used for converting the spinner response to flow velocities. Figure 11: Spinner cross plot BP Exploration Alaska Production Array Log Analysis 19 Calibration of Resistance Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and the measured RAT responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered RAT profile. This profile is optimized by comparing the measured and theoretical RAT response for each pass for each probe. Tracks 4-9: Measured and theoretical RAT responses for each probe. Below are the results from the calibration of the RAT data. The determination of this calibration is a layered resistivity profile. To obtain this profile, calibrations for water/ hydrocarbon were entered for each probe. Figure 12: Calibrated RAT response BP Exploration Alaska Production Array Log Analysis 20 Holdup and Velocity Profile: Shown on the image below from left to right: Track 3: Layered velocity profile. Track 4: Layered water holdup profile. Track 5: Layered oil holdup profile. Track 6: Layered gas holdup profile Track 7: Total holdup. Track 8: Cumulative flow rates Track 9: Density of fluid Track 10: Apparent Velocity from Fullbore Spinner Track 11: Apparent Velocity from Inline Spinner Figure 13: Holdup and velocity profile BP Exploration Alaska Production Array Log Analysis 21 Flow Profile The quantitative production rates were determined by comparing the well flow model with all available data. The figure below is provided to verify the agreement of the flow model with the data. In this figure the data is represented by the blue curves, while the calculated tool values are shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. Capacitance and gas holdup are used qualitatively. The small fluctuations around the data are to be expected, since the tools have intrinsic errors. Large sustained discrepancies indicate problems with the data, conflicts between parameters or conditions that make the underlying empirical models less applicable. To the right of the figure the flow regimes are shown. Within the transition zones several regimes can exists intermittently. Figure 14: Flow profile at reservoir conditions BP Exploration Alaska Production Array Log Analysis 22 The production rates at surface conditions are presented in the figure below: Figure 15: Flow profile at surface conditions BP Exploration Alaska Production Array Log Analysis 23 4.2 SHUT-IN SURVEY The data from the shut-in survey are presented in the Figures 16 - 28. For the interpretation, all the passes have been used except fastest ‘up’ SAT pass. Figure 21 shows the spinner data with stationary measurements. The response of fullbore and inline spinners suggest cross-flow taking place across perforations. During the shut-in passes, a cross flow was observed from 3rd, 4th and 5th perforations into 2nd and 1st (the top two) perforations. This was determined qualitatively and quantitatively from spinner, density and capacitance data. Gas is produced from 4th (9108’ – 9118’) and 5th perforations (9128’ – 9149’) while gas and water are injected into the first two perforations. Across the 4th and 5th perforations, the (CFB and ILS) spinners increase, density decreases to ~0.6 g/cc, capacitance increases and gas hold-up decreases indicating gas production while this trend is reversed across the top two perforations. The gas production during shut-in from the 4th and 5th perforation is not supported by the flowing interpretation. In the flowing interpretation, there is only a very slight deflection in density and capacitance. Acorss the 3rd perforation (9080’ – 9096’), spinners increase, density increases, capacitance decreases and gas hold-up increases indicating water production. Perforations Water Rate Oil Rate Gas Rate From, ft To, ft STB/D STB/D Mscf/D 9022 9043 -271 0 -72 9051 9064 -589 0 -363 9080 9096 199 0 0 9108 9118 0 0 233 9128 9149 654 0 242 9170 9184 0 0 0 BP Exploration Alaska Production Array Log Analysis 24 Raw Data - The figure below summarizes the input data recorded at the well site. - Each pass is shown with a fixed predefined color. Figure 16: Input data from the conventional production logging sensors BP Exploration Alaska Production Array Log Analysis 25 Figure 17: Input data from the conventional production logging sensors along with the station measurements. BP Exploration Alaska Production Array Log Analysis 26 The figure below shows the RAT input data. The first track shows the RAT rotation curves for each pass. The next 06 tracks show the RAT data for 6 active probes. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values and were not used in the interpretation. Figure 18: Input data from the Resistance Array Tool (RAT) BP Exploration Alaska Production Array Log Analysis 27 Figure 19: Input data from the Resistance Array Tool (RAT) showing only the active sensors along with station measurements BP Exploration Alaska Production Array Log Analysis 28 The figure below shows the SAT input data. The first track shows the SAT rotation curves for each pass. The next track shows the linespeed for each pass. The remaining tracks show the array spinner data: A curve for each pass for each of the 6 array spinners and for the fullbore spinner (ASpinner07) and the inline spinner (Aspinner08). Figure 20: Input data from the Spinner Array Tool (SAT) and conventional spinners. BP Exploration Alaska Production Array Log Analysis 29 Figure 21: Input data from the Spinner Array Tool (SAT) and conventional spinners along with the station measurements. Last track shows SAT rotation in degrees. BP Exploration Alaska Production Array Log Analysis 30 Pre- Processing Figure 22: Passes showing a consistent response have been used in for averaging out the measurements. BP Exploration Alaska Production Array Log Analysis 31 Calibration of Spinner Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and measured Array Tool responses. Track 2: Line-speed for each pass. Track 3: 'Unwrapped' rotation curve for each pass. Track 4: Normalized layered velocity profile. This profile is optimized by comparing the measured and theoretical SAT response for each pass of each spinner. Tracks 5-10: Measured and theoretical SAT responses for each spinner. Track 11: Measured and theoretical responses for the full-bore spinner. Track 12: Measured and theoretical responses for the inline spinner. Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. Figure 23: Velocity profile from SAT data. BP Exploration Alaska Production Array Log Analysis 32 The image below displays cross plots for the Inline and fullbore spinners. The estimated slopes are used for converting the spinner response to flow velocities. Figure 24: Spinner cross plot. BP Exploration Alaska Production Array Log Analysis 33 Calibration of Resistance Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and the measured RAT responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered RAT profile. This profile is optimized by comparing the measured and theoretical RAT response for each pass for each probe. Tracks 4-9: Measured and theoretical RAT responses for each probe. Below are the results from the calibration of the RAT data. The determination of this calibration is a layered resistivity profile. To obtain this profile, calibrations for water/ hydrocarbon were entered for each probe. Figure 25: Calibrated RAT response BP Exploration Alaska Production Array Log Analysis 34 Holdup and Velocity Profile: Shown on the image below from left to right: Track 3: Layered velocity profile. Track 4: Layered water holdup profile. Track 5: Layered oil holdup profile. Track 6: Layered gas holdup profile Track 7: Total holdup. Track 8: Cumulative flow rates Track 9: Density of fluid Track 10: Apparent Velocity from Fullbore Spinner Track 11: Apparent Velocity from Inline Spinner Figure 26: Holdup and velocity profile BP Exploration Alaska Production Array Log Analysis 35 Shut-In Profile The quantitative production rates were determined by comparing the well flow model with all available data. The figure below is provided to verify the agreement of the flow model wi th the data. In this figure the data is represented by the blue curves, while the calculated tool values are shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. The small fluctuations around the data are to be expected, since the tools have intrinsic errors. Large sustained discrepancies indicate problems with the data, conflicts between parameters or conditions that make the underlying empirical models less applicable. To the right of the figure the flow regimes are shown. Within the transition zones several regimes can exist intermittently. Figure 27: Flow profile at reservoir conditions BP Exploration Alaska Production Array Log Analysis 36 The production rates at surface conditions are presented in the figure below: Figure 28: Flow profile at surface conditions