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Home My WebLink About194-014MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC H-31 PRUDHOE BAY UNIT H-31 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 H-31 50-029-22444-00-00 194-014-0 W SPT 8457 1940140 2114 798 800 793 794 29 28 28 29 4YRTST P Kam StJohn 9/3/2024 4 Year AOGCC MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT H-31 Inspection Date: Tubing OA Packer Depth 45 2755 2709 2698IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240904123901 BBL Pumped:3 BBL Returned:3.2 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 99 9 9999 9 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 15:47:02 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor 2e -j'4 4 ql/ jllzww FROM: Guy Cook Petroleum Inspector Well Name PRUDHOE BAY UNIT H-31 Insp Num: mitGDC200912160101 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 15, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC H-31 PRUDHOE BAY UNIT H-31 Src: Inspector Reviewed By: n� P.I. Supry —�?, Comm API Well Number 50-029-22444-00-00 Inspector Name: Guy Cook Permit Number: 194-014-0 Inspection Date: 9/12/2020 Packer Depth Pretest Well 11-31 ' Ty e Ip nj W `,TVD 8457 Tubing i, 932 PTD 1940140 Type Test SPT Test psi 2114 IA 372 BBL Pumped: 2.7 ,BBL Returned: 3 OA 10 Interval 4YRTST - P/F P Notes: Testing completed with a Little Red Services pump truck and calibrated gauges.. Initial 15 Min 30 Min 45 Min 60 Min 934 934 934 2560 2550 2546 7 7 7 Tuesday, September 15, 2020 Page I of I • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 14,2016 TO: Jim Regg �/ P.I.Supervisor lOj Y ier SUBJECT: Mechanical IntegriTy Tests I ( BP EXPLORATION(ALASKA)INC. H-31 FROM: Bob Noble PRUDHOE BAY UNIT H-31 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv ' NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT H-31 API Well Number 50-029-22444-00-00 Inspector Name: Bob Noble Permit Number: 194-014-0 Inspection Date: 9/13/2016 Insp Num: mitRCN160913180719 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well H-31 - !Type Inj W8457 • Tubing 846 845 850 - 849 - PTD 1940140 Type Test SPT iTest psi 2114 - IA 19 2600 - 2576 - 2571 Interval 4YRTST 1P/F P ✓ OA 28 28 35 40 - Notes: ---- --- -- SCANNED ,JUN 2 0 20.'r Wednesday,September 14,2016 Page 1 of 1 • • P BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 q Lfr - 0 ( L Mr. Jim Regg Alaska Oil and Gas Conservation Commission ;� � AUG 2012 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB H -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 11-02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 1 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 11-06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 1408 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 H -11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18 /2010 H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18 /2010 11-15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 11-16 2000650 50029205920200 0 NA NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 1-1-18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 H -20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 H -25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/28/2010 H -26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 11-28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 11-30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 - -, 1431 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 H -33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 H -34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 H -35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 H -36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 H -38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 MEMORANDUM , State of Alaska • Alaska Oil and Gas Conservation Commission TO: ~ DATE: Thursday, October 09, 2008 Jim Regg 1(i Z !d P.I. Supervisor ~~Z%`J ~I ~ SUBJECT: Mechanical Integrity Tests l 1 BP EXPLORATION (ALASKA) INC H-31 FROM: John Crisp PRUDHOE BAY Uiv`IT H-31 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~~~~--- NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT H-31 Insp Num: mitJCr081008114121 Rel Insp Num: API Well Number so-oz9-zzaaa-oo-oo Permit Number: 19a-ota-o ~ Inspector Name: John Crisp Inspection Date: 10~2~2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well H-3I '!Type Inj. ~ W TVD ~ 8339 ~ IA 460 2300 2280 2270 P T I9aotao ~TypeTest SPT i Test psi zoaa.~s pA o 0 0 0 ~ I Interval RQITAL p/F, P Tubing ~ I Iso ~ I Iso ~ ~ Iso I Iso ~ NOtes• 2.4 bbl's pumped for test. 5~~~t~ ~ ~';~ ~ ~. 2aG Thursday, October 09, 2008 Page I of 1 STATE OF ALASKA ~ z AKA OIL AND GAS CONSERVATION CO~SSION REPORT OF SUNDRY WELL OPERATIONS` ~~ ~~ ~ ~ ti ,, 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing , ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 194-014- 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22444-00-00 7. KB Elevation (ft): 75 9, , 9. Well Name and Number: PBU H-31' 8. Property Designation: 10. Field /Pool(s): ADL 028283- Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11330' ~ feet true vertical 9236'- feet Plugs (measured) None Effective depth: measured 11249' feet Junk (measured) None true vertical 9155' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 110' 110' 1490 470 Surface 3550' 10-3/4" 3582' 3097' 5210 2480 Intermediate 10751' 7-5/8" 10778' 8693' 8180 5120 Production Liner 727' 5-1/2" 10603' - 1 1 330' 8520' - 9235' 7740 6280 ~~ gy L~c~ra~,~6~~' ~J~~ ~ ~W. Z~d~ Perforation Depth MD (ft): 10864' - 11050' Perforation Depth TVD (ft): 8777' - 8959' 4-1/2", 12.6# L-80 10602' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7-5/8" x 4-1/2" Baker'S-3' packer; 10419'; 7-5/8" x 4-1/2" Baker Perm Packer ~t~~ 10539' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut, pull and dress tubing to 10508'. Cut, pull and dress 7-5/8" casing to 3075'. Run 7-5/8" tieba ck to 3077', cement with 137 Bbls 769 cu ft / 657 sx . Run new tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ®WAG ^ GINJ ^ WINJ ^ WDSPL 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: Contact Howard West, 564-5471 308-263 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: ~ 7 .Signature Phone 564-4628 Date Terrie Hubble, 564-4628 Form 10-404 Revised~4/2006 E Submit Original my ~~~' • • H-31, Well History (Pre Rig Work) Date Summary 07/12/08 T/I/0= 700/450/0 MIT-IA to 4000 psi PASS fPRE RWOJ,Pumped 8 bbls 60/40 meth down tubing to reach 2000 psi. Pumped 7.5 bbls 60/40 meth down IA to reach test pressure. IA lost 110 psi in 15 min's, 30 psi in 2nd 15 min's, for a total loss of 140 psi in 30 min's. bled back 7 bbls from IA, gas from tubing. Annulus casing valves open to gauges, SSV, Swab valves closed, IA/ Wing valves tagged on departure. FW H P's=700/400/0 07/13/08 WELL S/I ON ARRIVAL. PULLED "P" PRONG FROM PLUG BODY C~ 10589' MD. TROUBLESHOOT TIGHT SPOTS BETWEEN 3400' - 3700' SLM W/ VARIOUS DRIFTS (ALL CLEAR). PULL 4-1/2" PXN PLU~C~ODY FROM 10.589' MD (TWO SMALL PIECES OF PACKING MISSING). DRIFT TBG W/ 3.70" CENT, S-BAILER. WELL LEFT S/I, DSO NOTIFIED. 07/14/08 INITIAL T/IA/OA: 140/375/0 PSI. RIH WITH HALIBURTION FAS DRILL PLUG, MAX OD = 3.66". ,~. PLUG MID ELEMENT AT 10578' TOP OF PLUG AT 10576.5'. CUT TUBING WITH 3.65" SLB POWERCUTTER AT 10500'. FINAL T/I/O = 300 / 400 / 0 PSI. JOB COMPLETE. 07/15/08 T/I/0= 170/400!0+. Temp= SI. T, IA FL (for E-line). Fluid visible in conductor 10" from flutes T FL C~ 500' (7.6 bbls). IA FL C~ surface. E-line took control of well. 07/15/08 T/I/0=140/360/20 Temp = S/I -Assist E-line, MIT T PASSED to 3500 psi (RWO expense,). Pumped 12.6 bbls of meth down TBG to reach 3500 psi for MIT TBG. 1st test 1st 15 min lost 170 psi 2nd 15 min lost 75 psi for a total of 245 psi in 30 min. Bleed TBG psi down bleed back aprox 4 bbls Final Whp's=200/400/20. Casing valves open to gauges. 07/18/08 T/I/0= SSV/300/0, Temp=S1. PPPOT-IC (PASS), Pre RWO. TBG hanger tested good, LDS functioned 5- 21-08. PPPOT-IC: Stung into test port (50 psi), bled to 0 psi. Function LDS, all move freely. Pump through void, clean returns. Pressure void to 3500 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. 07/19/08 T/I/O = 200/260/0 Temp = S/I -Circ Out Well, CMIT TxIA to 3500 psi (RWO prep) -Pumped 5 bbls 60/40 meth/water followed by 138 bbls 90° 9.3# brine down TBG taking returns up IA to H-32 flowline. 07/20/08 Circ out, CMIT TxIA PASSED to 3500 psi (RWO prep) -Pumped 513 bbls (651 total) 90° 9.3# brine down TBG taking returns up IA to H-32 flowline. Pumped 25 bbls diesel down TBG, let U-tube for freeze protect. CMIT TxIA -Pressured up TxIA to 3500/3520 psi w/4.1 bbls diesel. (2nd test) TxIA lost 20/70 psi in 1st 15 min and 20/10 psi in 2nd 15 min for a total loss of 40/80 psi in 30 min test. Bled WHP's to 0 psi. Freeze protect hardline w/2 bbls diesel. FWP's = 0/0/0 FO notified of all valve positions: (H-31) Swab closed, master open, wing closed, SSV closed, IA open, OA open (H-32) Swab closed, master closed, SSV closed, IA open, OA open. 07/21/08 T/I/O=Vac/0/0. Set 4-1/i6 CIW "H" BPV #145 thru tree., pre rig 1-2' ext used, tagged C~ 98". No problems. 08/13/08 T/I/0=0/0/0; Pull 4-1/16" CIW "H" BPV #145 thru tree for Doyon 14 De-completion; 1-2' ext. used, tagged ~ 102". 08/14/08 T/1/0=0/0/0; Pull 4-1/16" CIW "H" TWC #200 thru stack for Doyon 14; 4-5' ext. & Centralizer used, tagged ~ 90". Page 1 of 1 • • BP EXPLORATION Page 1 of 11 Operations Summary Report Legal Well Name: H-31 Common Well Name: H-31 Spud Date: 2/7/1994 Event Name: WORKOVER Start: 8/13/2008 End: 8/23/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/23/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 8/13/2008 08:00 - 09:00 1.00 MOB P PRE PJSM... -Skid Rig floor into moving position. 09:00 - 11:00 2.00 RIGU P PRE Move Rig off well H-11. -Turn Tires sideways. -Move & spot Rig over well H-31. Shim rig in place. 11:00 - 12:00 1.00 RIGU P PRE Skid Rig floor into working position. 12:00 - 13:00 1.00 RIGU P PRE Spot & berm Rock washer. 13:00 - 13:30 0.50 RIGU P PRE RU Rig floor. 13:30 - 17:00 3.50 WHSUR P DECOMP Fabricate & install Hurculite liner in cellar. -Seal seems in Hurculite w/ Heat gun. -Install "-Katch Kan" cellar drip pan. 17:00 - 18:00 1.00 WHSUR P DECOMP Install secondary valve on IA. -RU OA for pressure monitoring & bleed off operations. 18:00 - 19:30 1.50 WHSUR P DECOMP _eti~.++o~+ r~ inn nei fnr r. minn4ee _ Paee 19:30 - 21:00 1.50 WHSUR P 21:00 - 23:00 2.00 WHSUR P 23:00 - 00:00 I 1.001 WHSUR I P 8/14/2008 00:00 - 00:30 0.50 WHSUR P 00:30 - 02:00 1.50 WHSUR P 02:00 - 06:00 4.00 WHSUR P 06:00 - 07:00 1.00 WHSUR P 07:00 - 11:30 4.50 WHSUR P -rwi orv wi uam icawi. DECOMP RU lines & hoses for displacement of freeze protection. -Test lines to 3500 psi -Pass. DECOMP Displace diesel from well. -Pump: 20 bbls down annulus out Tbg. -Pump: 75 bbls down Tbg out annulus. -Wait 30 minutes for diesel to migrate up. -Pump: 30 bbls down Tbg out annulus. -Pump rate 210 gpm / 1800 psi. DECOMP D -Test from below to 1000 si f/ 10 minutes -Pass. -Test from above 3500 psi f/ 10 minutes. -All tests charted. DECOMP Continue to Tesf TWC from above to 3500 psi f/ 10 minutes. -All tests charted. -Pass DECOMP Suck out Tree. -ND Tree & Adaptor flange. Remove same from cellar. -Check Hanger threads = NSCT ~ 6.5 turns. DECOMP NU Spacer spool & BOP stack. -NU Choke and Flow lines. DECOMP MU XO on test Jt. Screw into Hanger. -RU to test BOP's. DECOMP Te t B P' ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. Test BOP and related equipment. -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 4,000 psi high x 5 min each on chart. -Test Hydril w/ 4" test jt. to 3,500 psi. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. Printed: 9/8/2008 11:12:52 AM 5~ BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: H-31 Common Well Name: H-31 Spud Date: 2/7/1994 Event Name: WORKOVER Start: 8/13/2008 End: 8/23/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/23/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT ' Phase I Description of Operations 8/14/2008 07:00 - 11:30 4.50 WHSUR P DECOMP -TIW & Dart valves. -Test top and bottom rams w/ 4" test joint and 4-1/2" test joint. -All tests Pass. -37 seconds for 200 psi build up. -2 minutes 52 seconds for full 3300 psi. -4 bottles X 2200 psi. -Perform accumulator test. -All tests witnessed by WSL and Toolpusher. -Test witness waived by Chuck Sheve - AOGCC. 11:30 - 12:00 0.50 WHSUR P DECOMP RD test equipment. 12:00 - 15:00 3.00 PULL P DECOMP RU Lubricator. -Test to 500 psi for 5 minutes -Pass. -Pull TWC. RD Lubricator. 15:00 - 16:00 1.00 PULL P DECOMP MU S ear for pulling Tbg hanger to Rig floor. -4 1/2" Spear packo assy, 4 1 2" Itco pear, -Spear extension & 4 1/2" "C" Dim. Tbg Spear. -Pull Tb han er to Floor., -PUW = 180k to break free. 16:00 - 17:30 1.50 PULL P DECOMP Circulate Safe-Surf-O and Safe-Scav pills. -Pump pills surface to surface. -Pump rate 335 gpm / 1700 psi. 17:30 - 18:00 0.50 PULL P DECOMP LD Spear and Tbg Hanger. 18:00 - 19:30 1.50 PULL P DECOMP RU to LD 4.5", 12.6#, 13Cr-80 Tbg. -Utilize Compensator. 19:30 - 22:00 2.50 PULL P DECOMP LD 4 1/2" Tba.to SSSV ~ 2,104' md. -Recovered 12 SS-Bands and 23 Clamps. 22:00 - 22:30 0.50 PULL P DECOMP RD & LD Control line spooler. 22:30 - 00:00 1.50 PULL P DECOMP Continue to LD 4 1/2" Tbg to 7,000' md. 8/15/2008 00:00 - 07:00 7.00 PULL P DECOMP Continue to LD 4 1/2", 12.6#, 13 Cr-80 Tbg. -LD tbg from 7,000' to surface. -LD: 264 Jts, 1-SSSV, 5- GLM's, 1- X nipple, -3 pups ~ 6.16', 6.18', 7.38'. 1-cut Jt ~ 12.65'. -Flare on cut Jt = 4 7/8". 07:00 - 07:30 0.50 PULL P DECOMP RD Tbg running equipment. 07:30 - 08:00 0.50 PULL P DECOMP Clear Rig floor. -LD Tbg running equipment. 08:00 - 09:00 1.00 CLEAN P DECOMP Clean Rig floor. 09:00 - 09:30 0.50 CLEAN P DECOMP Install Wear ring. 09:30 - 10:00 0.50 CLEAN P DECOMP PU Dress off BHA to Floor. 10:00 - 12:00 2.00 CLEAN P DECOMP MU -6 3/4 "Dress off shoe. 4 X Extensions. Tbg Mill. -Washover Boot basket. Double Pin sub. -2 X Boot baskets. 7 5/8" Csg scraper. Bit sub. -LBS. OII Jar. Pumpout sub. To 340' md. 12:00 - 13:30 1.50 CLEAN P DECOMP RIH w/ 4" D.P. from Derrick 340' to 4,130' md. 13:30 - 18:30 5.00 CLEAN P DECOMP PU & Rabbit 4" D.P. 1 X 1 from pipe shed. -PU f/ 4,130' to 10,400' md. -Work Cs scra er over Packer setti , -Continue to PU D.P, f/ 10,400' to 10,481' md. 18:30 - 21:30 3.00 CLEAN P DECOMP Obtain parameters; PUW 225k, SOW 135k, ROT wt 164k, -RPM 40, Tq 9k, 300 gpm / 1700 psi. Printed: 9/8/2008 11:12:52 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: H-31 Common Well Name: H-31 Event Name: WORKOVER Start: 8/13/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/23/2008 Rig Name: DOYON 14 Rig Number: Page 3 of 11 ~ Spud Date: 2/7/1994 End: 8/23/2008 Date From - To Hours ~ Task ~ Code NPT Phase i Description of Operations 8/15/2008 18:30 - 21:30 3.00 CLEAN ~ P DECOMP -Work down, tagged Stub ~ 10 507' md. -Work over Tbg Stub W/O rotary - OK. 21:30 - 23:00 1.50 CLEAN P DECOMP Pump Hi Vis (47 YP) surface to surface. -Sand & small metal flakes in sweep. -Flow check well - OK. -Pump dry job. Blow down Top Drive. 23:00 - 00:00 1.00 CLEAN P DECOMP POH w/ Dress off Assy on 4" D. P. -POH f/ 10,500' to 8,590' md. 8/16/2008 00:00 - 03:00 3.00 CLEAN P DECOMP Continue to POH w/ Dress off Assy on 4" D. P. -POH f/ 8,590' to 339' md. 03:00 - 04:00 1.00 CLEAN P DECOMP Stand back D.C's & 4" HWDP. -LD Oil jars, Bumper sub, Pump out sub, Bit sub, Csg scraper. -LD XO's, Boot baskets, Inside Mill, Washover extensions. -LD Dress off Mill. -Inside Mill showed good wear pattern form outside to inside. -Dress off mill showed outter wear grooves. -2 cups of sand and metal shavings in Boot baskets. 04:00 - 04:30 0.50 CLEAN P DECOMP Clear Rig floor of Vendor tools. 04:30 - 05:30 1.00 CLEAN P DECOMP Spot & RU SLB E-line services equipment. -RU line wiper. 05:30 - 07:30 2.00 CLEAN P DECOMP RIH w/ E-line USIT to to 3 750' md; -Log up from 3,750' md. in - GR / CCL /USIT mode. 07:30 - 09:30 2.00 CLEAN P DECOMP RD SLB E-line. -LD E-line tools & equipment 09:30 - 11:00 1.50 CLEAN P DECOMP PU & MU HES RBP. & running tool. -RIH w/ RBP on 4" D.P. to 3,147' md. 11:00 - 11:30 0.50 CLEAN P DECOMP Obtain parameters: PUW 90k, SOW 88k. -Set top of RBP ~ 3 180' md. -Set down 15k. PU 10k Over to confirm set. -PU 5'. 11:30 - 12:00 0.50 CLEAN P DECOMP Pump 40 bbl H V Sweep (48 YP). -Displace well over to 9.8 ppg NaCI. -Pump rate 420 gpm / 760 psi. 12:00 - 13:00 1.00 CLEAN P DECOMP RU to test 7 5/8" Cs . -Test Cs to 2000 si / 15 minutes on chart -Pass. -RD test equipment. Rack back 1 Std. to 3,081' md. 13:00 - 14:00 1.00 CLEAN P DECOMP Dump 1380 Ibs of 20/40 Sand down D.P. -Pump 1/2 of D. P. volume. 14:00 - 15:30 1.50 CLEAN P DECOMP -Let Sand settle for 1 hour. -Cut & slip 59.5' of 1 1/4" Drlg line while waiting on Sand. 15:30 - 17:30 2.00 CLEAN P DECOMP PU 1 Std. RIH to 3,129' md. and Taa Sand. -POH f/ 3,129' to 14' md. 17:30 - 18:00 0.50 CLEAN P DECOMP LD HES RBP runnin tool. -M B Baker Csg cutter tools to Rig floor. -MU Csg cutter BHA: 5 1/2" Multi-String cutter. -6 5/8" Stabilizer. 1 Std of 4 3/4" D.C's. XO. to 104' md. 18:00 - 20:00 2.00 CLEAN P DECOMP RIH w/ Cutter Ass on 4" D.P. -RIH f/ 104' to 3,077' md. -Pipe running rate C~ 1.5 to 2 minutes per Std. 20:00 - 21:30 1.50 CLEAN P DECOMP Top Drive up. Obtain parameters: -PUW 92k, SOW 88k, 147 gpm / 420 psi. -Work pipe slowly up and down to confirm collar locations. Printed: 9/8/2008 11:12:52 AM • BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: H-31 Common Well Name: H-31 Spud Date: 2/7/1994 Event Name: WORKOVER Start: 8/13/2008 End: 8/23/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/23/2008 Rig Name: DOYON 14 Rig Number: ~ l ' "Phase Description of Operations Date From - To NPT Hours Task Code 8/16/2008 21:30 - 22:00 0.50 CLEAN P DECOMP PJSM on cutting Csg. -C t 7 5/8" 29.7 # Cs ~ 3 074' md. -250 gpm / 880 psi. Free Tq 1 k @ 70 RPM. -Pump pressure dropped to 380 psi. Work pipe to confirm cut. 22:00 - 22:30 0.50 CLEAN P DECOMP Pressure test lines to 3500 psi / 5 minutes -Pass. -Establish circulation to outside Ti er Tank. -Pump 35 bbls of 9.8 ppg NaCI. -210 gpm / 1520 psi. 22:30 - 00:00 1.50 CLEAN P DECOMP PJSM w/ Hot Oil on Fluid transfers and pumping diesel. -RU Hot Oil. Test Hot Oil lines to 2500 psi / 5 minutes -Pass. -Pump diesel 84 gpm / 600 psi ~ start. -At 50 bbls away 84 gpm / 1500 psi. 8/17/2008 00:00 - 00:30 0.50 CLEAN P DECOMP Continue w/ Hot Oil pumping diesel. Total diesel pumped was 95 bbls / 120 degrees. -84 gpm / 1500 psi. -Rig pumps 33 bbl HV Sweep (48 YP). -147 gpm / 980 psi. 00:30 - 02:30 2.00 CLEAN P DECOMP Let hot diesel soak in 7 5/8" X 10 3/4" annulus. 02:30 - 04:30 2.00 CLEAN P DECOMP Displace diesel out of annulus w/ -40 bbls of 9.8 ppg NaCI / 40 bbls of 9.8 HV Sweep. -Chase with 207 bbls of 9.8 ppg NaCI brine. 04:30 - 05:30 1.00 CLEAN P DECOMP Pump Dry job. -POH w/ cutter Assy on 4" D. P. -POH f/ 3,074' to BHA ~ 104' md. 05:30 - 06:00 0.50 CLEAN P DECOMP Stand back D.C's. -make service breaks on tools. -LD Csg cutter. 06:00 - 06:30 0.50 CLEAN P DECOMP Drain BOP stack of 9.8 ppg NaCI. -Pull Wear ring. 06:30 - 08:30 2.00 CLEAN P DECOMP Cs Sear Assembl . -Engage Hanger. BOLDS. -Pull Hanger to Rig floor. Max PUW 180k. 08:30 - 09:30 1.00 CLEAN P DECOMP Pump Safe-Kleen pill surface to surface. -Soap sweep to ensure clean Csg. -Pump rate 504 gpm / 150 psi. 09:30 - 10:30 1.00 CLEAN P DECOMP Release Spear. -LD: Spear, XO, 1 Jt of D.P. -LD Csg Hanger. 10:30 - 12:00 1.50 CLEAN P DECOMP POH with & LD 7 5/8" 29.7# -LD Csg from 3,074' to 1,400' md. 12:00 - 13:30 1.50 CLEAN P DECOMP Continue to LD 7 5/8" Csg. -LD Csg from 1,400' to surface. -Total Cs recovered: 73Jts & 1 cut Jt C~3 20.39'. 13:30 - 16:00 2.50 CLEAN P DECOMP Drain BOP stack of 9.8 ppg NaCI. -Clear Rig floor. C/O Elevators. MOB Spear to Rig floor. -PU 1 Std of 4" D.P, and Crank case Spear. -Retrieve 220' of "CARS" hose . -(Casing annulus remediation system). -LD: Spear & XO. Rack back 1 Std of 4" D.P. 16:00 - 18:30 2.50 CLEAN P DECOMP MOB Baker Tools to Rig floor. -Install Wear ring. Printed: 9/8/2008 11:12:52 AM .~ ! • BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: H-31 Common Well Name: H-31 Spud Date: 2/7/1994 Event Name: WORKOVER Start: 8/13/2008 End: 8/23/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/23/2008 Rig Name: DOYON 14 Rig Number: Date ~~~ From - To I Hours Task Code NPT Phase Description of Operations 8/17/2008 16:00 - 18:30 2.50 CLEAN P DECOM - -Dress off Shoe, Extension, Dress off Mill, Tricon Bushing, -Double Pin Sub, 2 X Boot baskets, Bit Sub, Double Pin Sub, -10 3/4" Csg Scraper, Bit Sub, LBS, XO & 9- 4 3/4" D.C's. -PU BHA to 321' md. 18:30 - 19:00 0.50 CLEAN P DECOMP RIH w/ Dress off BHA on 4" D.P. -RIH from 321' to 794' md. -Top Drive up. Circulate bottoms up. -Monitor wellbore. Leave night TP on Rig. 19:00 - 20:00 1.00 CLEAN P DECOMP 1 hour B.P. Safety Stand Down. -Discuss incidents from the past week. -Discuss the potential meaning of an increase in incidents. -Discuss ADW statistics and the safety Pyramid. -Discuss how we can play a roll in ensuring we trend downwards. 20:00 - 23:00 3.00 CLEAN P DECOMP RIH w/ 4" D. P. f/ 794' to 3,068' md. -CBU every 800' looking for Arctic Pac. 23:00 - 00:00 1.00 CLEAN P DECOMP Obtain parameters: -PUW 95k, SOW 90k, ROT wt 94k, Tq 1-2k ~ 40 RPM. -386 gpm / 840 psi. -Ta u @ 3 074' md. Be in Millin . -1-3k Tq ~ 60 RPM. Mill to 3,075' and -Work pipe to Dress off Csg stub. -Dress off assembly able to slide back over stub W/O rotation. 8/18/2008 00:00 - 01:00 1.00 CLEAN P DECOMP Circulate Hi Vis Sweep (YP 49) surface to surface. -399 gpm / 800 psi. 01:00 - 02:00 1.00 CLEAN P DECOMP POH w/ Dress off assembly on 4" D.P. -POH f/ 3,075' to BHA ~ 320' md. 02:00 - 03:00 1.00 CLEAN P DECOMP Stand back D.C's. -LD: Csg Scraper, Boot baskets, Dress off Mill, Extension & Shoe. -Inner Mill showed good /light wear pattern. -Shoe was marked on bottom and on inside lip. 03:00 - 03:30 0.50 CLEAN P DECOMP Clear Rig floor of Vendor Tools: - Csg Scraper, Boot baskets, Dress off Mill, Extension & Shoe. 03:30 - 05:00 1.50 CLEAN P DECOMP 1 hour B.P. Safety Stand Down. -Discuss incidents from the past week. -Discuss the potential meaning of an increase in incidents. -Discuss ADW statistics and the safety Pyramid. -Discuss how we can play a roll in ensuring we trend downwards. 05:00 - 05:30 0.50 CLEAN P DECOMP MU &RIH w/ HES RTTS. to 480' md. on 4" D.P. 05:30 - 06:00 0.50 CLEAN P DECOMP Circulate 1 D.P. volume of 9.8 ppg NaCI. -Set RTTS ~ 480' md. 06:00 - 07:30 1.50 CLEAN P DECOMP RU test equipment. -Test Cs below RTTS to 2000 si / 10 minutes -Pass. -Function Top Rams (3 1/2" X 6" Variables). -Test above RTTS to 500 psi / 10 minutes: r in 10 minutes - No fluid into cellar. -Rd test equipment. 07:30 - 08:00 0.50 CASE P DECOMP PU Csg Tools to Rig Floor. -PU Cement equipment to Rig Floor. Printed: 9/8/2008 11:12:52 AM • n BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: H-31 Common Well Name: H-31 Spud Date: 2/7/1994 Event Name: WORKOVER Start: 8/13/2008 End: 8/23/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/23/2008 Rig Name: DOYON 14 Rig Number: i i Date From - To ', Hours Task. ;Code. NPT Phase r Description of Operations 8/18/2008 08:00 - 08:30 0.50 CASE P DECOMP Pull Wear ring. 08:30 - 10:00 1.50 CASE P DECOMP RU to run 7 5/8", 29.7#, L-80, Vam Top HC Csp., 10:00 - 12:00 2.00 CASE P DECOMP PJSM. -MU 7 5/8" Csg Patch, Pup, ECP, Pup, -ES Cementer & XO jt. to 100' md. -Run 7 5/8" Csg. Torque Turn every connection. -Use "Jet Lube Seal Guard" thread compound. -Optimum make up torque is 14,450 fUlbs. -Baker Lok every connection below ES Cementer. -One floating centralizer per Jt except jt in Wellhead. 12:00 - 17:30 5.50 CASE P DECOMP Continue running 7 5/8" Csg from 100' to 3,072' md. -Run 7 5/8" Csg. Torque Turn every connection. -Use "Jet Lube Seal Guard" thread compound. -Optimum make up torque is 14,450 fUlbs. -Baker Lok every connection below ES Cementer. -One floating centralizer per Jt except jt in Wellhead. 17:30 - 20:00 2.50 CASE P DECOMP PU - 5'4" Pup Jt, 4" X 4 1/2" XO & 4 1/2" X 7 5/8" XO. -MU Top Drive. Rotate down slowly until taking wt. Stop rotation. -Set down 35k off SOW of 1 Ok -PU 35k over PUW of 126k (161 k). -Slack off to 65k. -PU to 300k to confirm make u . -RD Pup & XO's. C/O Bales and Elevators. -PU 3', 7 5/8" X 7 5/8" Buttress XO, Cement head and XO. -MU cement line & valves. 20:00 - 20:30 0.50 CASE P DECOMP Pressure test Csg to 1000 psi / 10 minutes -Pass. -Stage up in 200 psi increments. -Open Delayed Inlet shear ~ 1800 psi. -Pressure dropped 200 psi. Hold for 5 minutes. -Test to 2000 si / 10 minutes -Pass. -Pressure up to 3500 psi to open ES Cementer. 20:30 - 21:00 0.50 CASE P DECOMP Circulate hot 9.8 ppg NaCI brine until returns are 85 degrees. -210 gpm / 70 psi. Stage up to 321 gpm / 230 psi. 21:00 - 23:00 2.00 CASE P DECOMP PJSM on cement job. -Maintain 100k overpull on Csg throughout job. -Pressure test cement lines to 4500 psi-Pass. -Pump: -137 bbls of 15.8 class "G" Tail cement w/ GasBlok. -Drop plug & kick out w/ 5 bbls fresh water. -Displace w/ Rig pumps. Caught pressure ~ 500 stks. -250 gpm / 650 psi. Stop pump ~ 1140 stks and close Bag. -Divert returns to outside tank. - Continued to pump ~ 102 gpm / 1100 psi. -At 1280 stks slowed pump to 21 gpm / 1000 psi. -Bump plug ~ 1315 stks. Increase pressure to 2200 psi. -Hold pressure or 5 minutes. CIP ~ 22:47 hrs. - 7.5 bbls of cement returns to outside tank. 23:00 - 00:00 1.00 CASE P DECOMP Flush return line to outside tank. Flush BOP stack. -Drain stack. RD cement equipment. 8/19/2008 00:00 - 00:30 0.50 CASE P DECOMP Clear Rig floor of all Vendor Tools: -LD Csg & Cementing equipment. 00:30 - 01:00 0.50 CASE P DECOMP Blow down lines. Printed: 9/8/2008 11:12:52 AM • ~' BP EXPLORATION Page 7 of 11 Operations Summary Report Legal Well Name: H-31 Common Well Name: H-31 Spud Date: 2/7/1994 Event Name: WORKOVER Start: 8/13/2008 End: 8/23/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/23/2008 Rig Name: DOYON 14 Rig Number: i Date ~ From - To Hours Task Code NPT .Phase Description of Operations 8/19/2008 00:30 - 01:00 0.50 CASE P DECOMP -Suck out landing Jt & BOP stack. 01:00 - 03:00 2.00 CASE P DECOMP ND: Flow line, Riser & Choke line. -Split BOP stack below Tbg spool. 03:00 - 05:30 2.50 CASE P DECOMP FMC: Set Emer enc sli s w/ 100k over ull on 7 5/8" cs . -Slack off to 3k overpull. -Cut 7 5/8" 29.7#, L-80, Vam Top HC Csg. w/ WACHS cutter. -LD cut Jt (28.73') -Install Pack-off. -Test Pack-off to 3800 psi / 30 minutes -Pass. 05:30 - 09:30 4.00 CASE P DECOMP Attempt to set Pack off. - No success. -Stand back BOP stack. Inspect cut & Pack off. -Pack off is too tall. C/O Junk ring. -Re-install Pack off. -Test Pack-off to 3800 si / 30 minutes -Pass. 09:30 - 11:30 2.00 CASE P DECOMP NU BOP stack, Choke line, Riser & Flow line. 11:30 - 12:00 0.50 CASE P DECOMP Install test plug. -RU to test breaks on BOP stack & equipment. 12:00 - 14:00 2.00 CASE P DECOMP Continue to RU to test breaks on BOP stack & e ui ment. -Test breaks ~ 250 low psi / 4000 high psi. -Pass. -RD test equipment. Install Wear ring. -Blow down Choke line & Kill line. -LD Pack off running tool. 14:00 - 15:00 1.00 CASE P DECOMP W.O.C. MOB Baker Tools to Rig floor. -MU: Jars, LBS, Bit sub, 2 X Boot baskets & 6 3/4" Bit. 15:00 - 15:30 0.50 CASE P DECOMP W.O.C. Service Rig. 15:30 - 16:00 0.50 CASE P DECOMP W.O.C.MU Pump out sub, XO & D.C's. to 310' md. 16:00 - 17:00 1.00 CASE P DECOMP R I n -RIH f/ 310' to 2,973' md. 17:00 - 21:30 4.50 CASE P DECOMP Obtain parameters: PUW 95k, SOW 90k, ROT wt 94k, -RPM 70 ~ 1 k free Tq. 399 gpm / 950 psi. -RIH tag cements 2,973' md, -Drld Cmt to to of ES Cementer ~ 3 038' md. -Control Drld down to 3,100' md. -WOB 5-8k. Tq while Drlg 0.75k. -Pump Hi Vis Sweeps as needed. 21:30 - 00:00 2.50 CASE P DECOMP DROPPED OBJECT INCIDENT. -Shut down Rig and notify proper personnel. -Begin incident investigation. -Complete a thorough derrick inspection. -INCIDENT: IR- 2753571 8/20/2008 00:00 - 01:30 1.50 CASE P DECOMP Safety stand down for dropped object. -Discuss with new crew what had happened. -Complete incident investigation. -Repair Top Drive. 01:30 - 03:00 1.50 CASE P DECOMP Rig up to test 7 5/8", 29.7#, L-80, Vam Top HC Csg. -Test 7 5/8" Cs to 4000 si / min -Rig down test equipment. 03:00 - 04:30 1.50 CASE P DECOMP PU 1 Std of 4" D.P. Tag ~ 3,101' md. -PUW 95k,SOW 89k, ROT wt 93k, RPM 70 w/ Tq 1 k. -WOB 5-10k, 420 gpm / 1140 psi. -Drld Cmt f/ 3,101' to 3,129' md. Printed: 9/8/2008 11:12:52 AM • BP EXPLORATION Page 8 of 11 Operations Summary Report Legal Well Name: H-31 Common Well Name: H-31 Spud Date: 2/7/1994 Event Name: WORKOVER Start: 8/13/2008 End: 8/23/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/23/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code ~I NPT ~ Phase ~ Description of Operations 8/20/2008 04:30 - 05:00 0.50 CASE P DECOMP Pump Hi Vis Sweep surface to surface. -420 GPM / 1140 psi. 05:00 - 05:30 0.50 CASE P DECOMP Drill sand and funk from 3,129' to 3,138' md. -bt gpm / au psi. -Dry Drld f/ 3,138 to 3,139' md. 05:30 - 06:00 0.50 CASE P DECOMP Pump Hi Vis Sweep (47 YP) surface to surface. -420 gpm / 1140 psi. -Flow check well -static. 06:00 - 07:00 1.00 CASE P DECOMP POH w / Cleanout BHA on 4" D.P. f/ 3,139' to 310' md. 07:00 - 08:00 1.00 CASE P DECOMP Stand back 4 3/4" D.C's. -Break off Bit. -LD & clean out Boot baskets. -Recovered: Sand & metal shavings in Boot baskets. 08:00 - 08:30 0.50 CASE P DECOMP MU: RCJB, 7 .625" Csg scraper, Boot baskets, XO's, -Oil jars, Bumper sub, Pump out sub & 4 3/4" D.C's. to 319' md. 08:30 - 09:30 1.00 CASE P DECOMP RIH w/ RCJB BHA f/ 319' to 2,972' md. 09:30 - 10:00 0.50 CASE P DECOMP Obtain parameters:PUW 96k, SOW 90k, ROT wt 95K, -462 gpm / 1760 psi. Wash down f/2,972' to 3,065' md. -Drop Ball. Wash down, tag sand ~ 3,138' md. -Noted pump pressure increase 2210 psi / 420 gpm. -Rotate & wash sand f/ 3,138' to 3,148' md. 10:00 - 11:00 1.00 CASE P DECOMP Pump Hi Vis Sweep (48 YP) surface to surface. -420 gpm / 2210 psi. 11:00 - 11:30 0.50 CASE P DECOMP Observe well -static. -POH w/ RCJB BHA on 4" D. P. -POH f/ 3,148' to BHA ~ 319' md. 11:30 - 12:00 0.50 CASE P DECOMP Stand back 4 3/4" D.C's. -LD: RCJB, Boot baskets, Csg scraper, Oil jars, -Bumper sub & pump out sub. -Recovered: -1 small iece of brass & 5 small feces of aluminum in RCJB. 12:00 - 13:00 1.00 CASE P DECOMP Service break Baker Tools. -Clear Rig floor of all Tools not being used. -MOB HES retrieval tool. -MU retrieval tool & 1 stand of 4" D.P. to 106' md. 13:00 - 14:30 1.50 CASE P DECOMP RIH w/ retrieval tool on 4" D.P. f/ 106' to 3,062' md. -Tagged up ~ 3,063' md. -Rotate 1/2 turn, wt fell off, slack off to 3,074' md. -Rotate 1/2 turn wt fell off. 14:30 - 15:30 1.00 CASE P DECOMP Wash down from 3,074'to 3,180' md. -PUW 92k, SOW 87k. -Slack off to 75k. PU to 105k. Slack off to 95k. -Pump Hi Vis Sweep (49 YP) surface to surface. -Rotate 1 turn & hold Tq. PU let element relax. -Pull up, rack back 1 std. 15:30 - 17:30 2.00 CASE P DECOMP Blow down Top Drive. Monitor well -static. -POH w/RBP on 4" D.P. from 3,180'to 14' md. 17:30 - 18:30 1.00 CASE P DECOMP Pull & LD HES RBP. 18:30 - 19:00 0.50 CASE P DECOMP Drain BOP stack. Pull Wear ring. 19:00 - 20:00 1.00 CASE P DECOMP RU to test BOP's. 20:00 - 20:30 0.50 CASE P DECOMP Safety stand down w/ BP personnel. -Inspect Top Drive. Printed: 9/8/2008 11:12:52 AM BP EXPLORATION Page 9 of 11 Operations Summary Report Legal Well Name: H-31 Common Well Name: H-31 Spud Date: 2/7/1994 Event Name: WORKOVER Start: 8/13/2008 End: 8/23/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/23/2008 Rig Name: DOYON 14 Rig Number: Date ~I From - To ~ Hours Task Code NPT Phase Description of Operations 8/20/2008 20:30 - 00:00 3.50 CASE P DECOMP Test BOP's: 250 psi low / 4000 psi high. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. Test BOP and related equipment. -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 4,000 psi high x 5 min each on chart. -Test Hydril w/ 4" test jt. to 250 / 3,500 psi. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test top and bottom rams w/ 4" test joint and 4-1/2" test joint. - All Pass. -Perform accumulator test. Test witnessed by WSL and Toolpusher. -Test witness waived by John Crisp AOGCC. - Note: 30 secs for 200 psi build up 2 Min & 45 secs for full PSI 4 bottles X 2300 psi. 8/21/2008 00:00 - 00:30 0.50 CASE P DECOMP Continue to test bottom Rams w/ 4 1/2" test Jt. -All BOP tests -Pass. -Test witness waived by John Crisp AOGCC. 00:30 - 01:00 0.50 CASE P DECOMP RD test equipment. -Pull test plug. 01:00 - 01:30 0.50 CASE P DECOMP Install Wear ring. 01:30 - 02:00 0.50 CASE P DECOMP MOB: 2 7/8" Millin assembl BH 02:00 - 03:30 1.50 CASE P DECOMP MU: Shear pin mandrel, Shear pin bushing & Convex Mill. MU: Extension & Guide. PU: 4 Jts of 2 7/8" PAC D. P. from pipe shed. -MU: Oil jars & Lubricated Bumper sub. -RIH on 4 3/4" D.C's. to 432' md. 03:30 - 07:00 3.50 CASE P DECOMP RIH w/ Cutlip Mill assembly on 4" D.P. -RIH from 432' to 10,472' md. 07:00 - 09:00 2.00 CASE P DECOMP Pump Hi Vis Sweep (45 YP). -Displace well from 9.3 ppg NaCI to 8.5 ppg Seawater. -294 gpm / 1970 psi 09:00 - 11:00 2.00 CASE P DECOMP Obtain parameters: PUW 230k, SOW 136k, Rot wt 170k, -1 k Tq ~ 60 RPM, 252 gpm / 1340 psi. -Wash down Ta stub ~ 10 508' m . W wn Ta P 1 - 'Il Drill Plu w/ 5k B. P h Plu 14' 11:00 - 11:30 0.50 CASE P DECOMP Pull up 40' & monitor well. Lost 7 bbls / 10 minutes (42 bph). -Stand back 2 stands. 11:30 - 12:00 0.50 CASE P DECOMP POH. -LD 4" D.P. f/ 10,479' to 10,300' md. Printed: 9/8/2008 11:12:52 AM • BP EXPLORATION Page 10 of 11 Operations Summary Report Legal Well Name: H-31 Common Well Name: H-31 Spud Date: 2/7/1994 Event Name: WORKOVER Start: 8/13/2008 End: 8/23/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/23/2008 Rig Name: DOYON 14 Rig Number: Date .From - To Hours Task Code NPT Phase I Description of Operations 8/21/2008 11;30 - 12:00 0.50 CASE P DECOMP 12;00 - 16:30 4.50 CASE P 16:30 - 17:00 I 0.501 CASE I P 17:00 - 21:00 4.00 CASE P 21:00 - 23:00 2.00 CASE P 23:00 - 23:30 0.50 CASE P 23:30 - 00:00 0.50 CASE P 8/22/2008 00:00 - 02:00 2.00 02:00 - 12:00 10.00 12:00 - 17:00 ~ 5.00 ~ RUNCO 17:00 - 20:30 I 3.501 RUN 20:30 - 00:00 ~ 3.50 Total loss for Tour = 19 bbls. DECOMP Continue to LD 4" D.P. -POH from 10,300' to 4,794' md. DECOMP Perform D-1 and Post drill review. -RIH from derrick from 4,794' to 4,983' md. -Service Rig. DECOMP Continue to POH. -LD 4" D.P. from 4,983' to 432' md. DECOMP LD: Baker BHA -Oil jars & Lubricated Bumper sub. 2 7/8" PAC D. P. - Shear pin mandrel, Shear pin bushing & Convex Mill. Extension & Guide. DECOMP Clear Rig floor of Vendor Tools. DECOMP Pull Wear ring. -Fluid losses for tour = 264 bbls. -Total losses to well 283 bbls. RUNCMP C/O to long bales. -RU to run 4 1/2" 12.6#, L-80, TC-II Tbg. RUNCMP PJSM :Run 4 1/2", 12.6#, L-80, T -II Tbg. -Torque Turn each connection. -Use single Jt compensator & stabbing guide. -Utilize "Jet Lube Seal Guard" thread compound. -Optimum Tq 3900 fUlbs. -Baker Lok all connections below Baker S-3 Packer. -Run Tbg to 6,150' md. -Fluid losses for tour = 310 bbls. -Total losses to well 593 bbls. RUNCMP Continue to run 4 1/2" Tbg -Run 4 1/2" from 6,150'to 10,461' md. -Torque Turn each connection. -Use single Jt compensator & stabbing guide. -Utilize "Jet Lube Seal Guard" thread compound. -Optimum Tq 3900 Wlbs. RUNCMP Ta ed Tb stub ~ 10 508' md. -First shear ~ 4-5k. -Second shear ~ 5-6k -No-Go f~ 10,508' and w/ 12k on stub. -LD Jt # 256. PU 10' pup. -RU to circulate. Circulate: 126 gpm / 70 psi. -Start over Tbg stub, pressure increase to 140 psi. -No-Go pressure up ~ 330 psi. -LD: circulating equipment, 10' pup, Jts 255 & 254. -PU 10' pup & Jt 254. -PU Hanger & Landing Jt w/ circulating head. RUNCMP PJSM. RU to reverse circulate Seawater. -Reverse in 160 bbls of clean Seawater. -126 gpm / 290 psi. -Reduce rate to 42 gpm / 40 psi. -Waiting for Diesel for freeze protection. Printed: 9/8/2008 11:12:52 AM r~ BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: H-31 Common Well Name: H-31 Spud Date: 2/7/1994 Event Name: WORKOVER Start: 8/13/2008 End: 8/23/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 8/23/2008 Rig Name: DOYON 14 Rig Number: Date From- To ~ Hours Task !~ Code 'NPT Phase Description of Operations ', 8/22/2008 20:30 - 00:00 3.50 BUNCO RUNCMP -2-ES stuck in road /LRS unable to get diesel to location. -Fluid losses for tour = 323 bbls. -Total losses to well 916 bbls. 8/23/2008 00:00 - 03:00 3.00 03:00 - 03:30 0.50 03:30 - 04:00 0.50 04:00 - 06:00 I 2.001 RUN 06:00 - 07:00 I 1.001 RUN RUNCMP Reverse in Seawater w/ corrosion inhibitor. -Pump 280 bbls ~ 8.5 ppg. RUNCMP Land Tbg Hanger. -RILDS. RUNCMP PJSM. RU LRS to IA. -Pressure test lines to 2500 psi -Pass. -LRS -Pump 50 bbls diesel down !A. -105 gpm / 950 psi. FCP = 900 psi. RUNCMP RU LRS to Tbg through cement line. -Pressure test lines to 4500 psi. -Pump 30 bbls diesel down Tbg. -147 gpm / 600 psi. FCP = 800 psi. RUNCMP Drop_Ball & Rod. Pressure up Tba to 4000 07:00 - 08:30 08:30 - 09:00 09:00 - 09:30 09:30 - 10:30 1.50 0.50 0.50 1.00 BUNCO BUNCO BUNCO BUNCO RUNCMP RUNCMP RUNCMP RUNCMP -Chart & test Tb to 4000 si / 30 minutes -Pass. RU to IA. -Chart & test IA to 4000 si / 30 minutes -Pass. RD test equipment MU Dry Rod. -In tall TWC. RU test equipment. -Chart & test TWC to 4000 si / 10 minutes -Pass. 10:30 - 11:00 0.50 BUNCO RUNCMP RD test equipment. -Blow down Choke, Kill & Hole fill lines. -LD Mouse hole. Vacuum out BOP stack. 11:00 - 12:00 1.00 BUNCO RUNCMP PJSM - ND Flow line, Riser & Choke line. -ND BOP's. 12:00 - 20:00 8.00 BUNCO RUNCMP Continue to ND BOP's. -NU Adaptor flange and Tree. -Test Flange to 5000 psi / 30 minutes -Pass. -Test Adaptor and Tree to 5000 psi / 10 minutes -Pass. -Test lubricator to 500 psi -Pass. -Pull TWC. Install BPV. -Secure well. Release Rio. -Waiting on 2 ES to finish Rig move. -Waiting on mats to move. ---T /I /O = 0 /0 /0 --- Printed: 9/8/2008 11:12:52 AM SAFETY NOTES: 4-1/2" GHROMETBG &LNR. NOTE: WELLHEAD = 11" 5M FMC P LY/NO M I INJECTION ALLOWED*** ACTUATbR = BAKER ~ ~ ~ 1 UPDATE: CARS PROJECT=200° 112" HOSE IN KB: ELEV = 75.9' OA NORTH FACING VR PROFILE. MAX OAP = 200 PSI, BF. ELEV = 45.5' ***NOTE: 12 JOINTS J-55 CSG BURST POINT`~* KOP - 1489' Max Angle = 53 @ 3984' Datum MD = 10965' 2100' 4-1/2" HES X NIP, ID = 3.813" Datum TVD = 8800' SS 7 5!8" CSG, 29.7#, L-80 BTC, ID = 6.875" 3077' 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 3582' Minimum ID = 3.725" @ 10589' 4-1 /2" OTIS XN NIPPLE 4-1/2" HES X NIP, ID = 3.813" 10419' --~ 7 5/8" X 4-1 /2" BKR S-3 PKR, ID = 3.87" 10442' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" I-I 10503' 4-1/2" TBG STUB (XXtXX;XX} 4-1/2" TBG, 12.6#, 13CR-80 NSCT, I~ 1 .0152 bpf, ID = 3.958" TOP OF 5-1/2" LNR I~ 10604' 7-5/8" CSG, 29.7#, NT-95HS, ID = 6.875" ~-j 10778, PERFORATION SUMMARY REF LOG: ATLAS BRCS ON 02/21/94 ANGLE AT TOP PERF: 13 @ 10864' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10864 - 10900 O 03/25/94 3-3/8" 6 10978 - 10988 O 03/06/94 3-3/8" 6 10992 - 11017 O 03/06/94 3-3/8" 6 11030 - 11050 O 06/08/94 PBTD 11249' i-1/2" LNR, 17#, 13CR-80, .0232 bpf, ID = 4.892" 11330' 7 5/8" X 4-1/2" UNIQUE OVERSHOT 7-5/8" X 4-1/2" BKR PERM PKR, ID = 3.875" 10572' I~ 4-1 /2" OTIS X NIP, ID = 3.813" 4-1/2" OTIS XN NIP, ID = 3.725" 10602' -~4-1/2" WLEG, ID = 3.958" I 10600' ELMD TT LOGGED 03/06/94 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/06/94 ORIGINAL COMPLETION 08/26/08 PJC DRLG CORRECTIONS WELL: H-31 03/01/01 SIS-LG FINAL PERMff No: 1940140 08/23/08 D14 RWO API No: 50-029-22444-00 07/18/01 RN/TP CORRECTIONS SEC 21, T11 N, R13E, 3552' FSL & 1265' FEL 07/15/03 CMO/TLP KB ELEVATION CORRECTION 06/25!08 SWC/SV SET PXN (06/16/08) BP Exploration (Alaska) oa/2s/o8 ~~~ribepg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wpu .i~ti ~ N0.4843 Company: State of Alaska ;~~~ ~~ ~ ~ ~~~~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~~ ~_ H-31 11999035 USIT ~} G- I L 08/16/08 v 1 ~. 1 14-22A 11999036 PPROF W/FSI - 08/17/08 1 1 13-34 11676963 USIT a - 08/18/08 1 1 H-35 11970840 RST .. , / 3 08/12/08 1 1 G-16 11982438 RST ~ 06/21/08 1 1 L1-09 12017501 CH EDIT (SONIC SCANNER) r ~ 06/06/08 1 1 -"--' --.-.-_ -____~_ ..~_~.. ... ............. ....v ..r.. vnw~~aa vnc vvr ~ main ~ v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~, ;~. .~ ~ ~. 900 E. Benson Blvd. Anchorage, Alaska 99508 l~ Date Delivered: A! IC` ~ ~ ~Q~$Vj ~I~SKFt ()i0 cx ~adS lrC1tIS. {.~(..>1Tl(ill ySlGll ,!~11C~1©I'~~]G Alaska Data & Consulting Services 2525 GambeN Street, Suite Anchorage, AK 99503-2838 ATTN: Beth Received by: • r: i • • ~ ~ ~ ~ ~ SARAH PAL/N, GOVERNOR c~as[a~78A O~ Ally ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'1'IO1K COMl~'IIS51O1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 ~~N~~ JUL G 9 ZD08 ~ ~ (~ Anchorage, AK 99519-6612 ~ ~,~. ~^ Re: Prudhoe Bay Field, Frudhoe Bay Oil Pool, PBU H-31 Sundry Number: 308-263 Dear Mr. Reem: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90~ 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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 ff the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. _ /f Chair DATED this ~ day of July, 2008 Encl. STATE OF ALASKA ~~-~~ ' ~~'`~~ ~ ~~~`~'Li ALA O1L AND GAS CONSERVATION COMII~ION ~ ~~J1 ~. 1~1~~ ~ N APPLICATION FOR SUNDRY APPROVAL ~(:~~ ~-~ 20 AAC 25.280 ~,~53~>8 "~' N 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Ext rfsibn ® Alter Casing - ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pult Tubing _ ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Exploratory 194-014 3. Address: Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 .jJ~ 50-029-22444-00-00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU H-31- Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028283 ~ 75.9' - Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11330' - 9236' - 11249' 9155' 10589' None Casin Len th Siz MD TVD Burst Colla se Structural C nductor 80' 2 110' 110' 1490 470 Surface 3550' 10-3/4" 3582' 3097' 5210 2480 Intermediate 10751' 7-5/8" 10778' 8693' 8180 5120 Production Liner 727' 5-1/2" 10603' - 11330' 8520' - 9235' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 10864' - 11050' 8777' - 8959' 4-1/2", 12.6# 13Cr 10602' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker Perm Packer Packers and SSSV MD (ft): 10539' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: August 3, 2008 ~. ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ~ / ~ WAG ^ GINJ ^ WINJ ^ WDSPL J Commission Representative: ' ~ 18. I hereby certi that the foregoing is true and correct to the best of my k owledge. Contact Howard West, 564-5471 Printed Na avid R m Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date ~. ~¢ d8 Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: g. Conditions of approval: Notify Commission so that a representative may witness _ ^ Plug Integrity ~OP Test ~~echanical Integrity Test ^ Location Clearance ''~K Other: ~5~ ~~` ~~~ .~~.~- Subsequent Form Required: APPROVED BY ~? ~/ A roved B COMMISSIONER THE COMMISSION Date [s (~ Form 10 403 ~~ t~6,(2 ~ Submit In Duplicate ~..~ ~ `~, i ~ ~ ~ ~ S ~~~ ~Ul,. ~ ~ 2006 • by c,~~,, H-31 i Expense Rig Workover Scope of Work: Pull 4-'h" completion, cut and pull 7 5/s" casing, run and cement 7 5/e" premium threaded casing to surface, run 4-'/z" L-80 tubing with Baker S-3 packer set at 10,400' MD. MASP: 2300 psi Well Type: WAG Injector Estimated Start Date: Aug 3, 2008 Production Engineer: Jennifer Starck Intervention Engineer: Howard West Pre-ria prep work: F 1 MITIA to 4000 si. Kee 2000 si on tubin while casin is bein ressure tested S 2 Drift for 4.5" jet cutter and Fas-drill. Pull PXN plug at 10589. Set Fas-drill plug at 10,580' MD, test to 1000 si. E 3 Power Jet cut 4-'h" 13Cr-80 tubing at 10500' MD, in the top third of the 1S full joint above the Baker aaker. Reference tubin tall dated 02/25/94. F 4 Circulate well with seawater and diesel thru the cut. CMIT TxIA to 4000 si W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU Doyon 14. ND tree. NU and test ROPE pipe rams to 4000 psi. Test annular preventer to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Retrieve 4-~h" tubing string down to the tubing cut. 3. Run USIT log to determine top of cement in the 7 5/8" casing. 4. Set and test 7 s/8" RBP approximately 100' below estimated TOC. Note: The VBRs in the BOPs will NOT be changed over to 7-6/a" pipe rams as the barriers to the reservoir will be the tested 7 5/8" RBP and Fas-drill plug in the 4 ~/z" tubing. 5. Cut and pull 7-5/8' above TOC. 6. Run and fully cement 7 5/a' casing to surface. 7. Pressure test new casing to 4000 psi. 8. Drillout 7 s/6" shoe track. 9. Retrieve 7-5/8" RBP. 10. Drill .out Fas-drill plug set at --10,580'. 11. Run 4-~/z" L-80 tubing with Baker S-3 packer set at 10,400' MD. 12. Displace the IA to packer fluid and set the packer. 13. Test tubing and IA to 4000 psi. Freeze protect to 2200' MD. 14. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = 4" 5M CHR CAMERON WELLHEAp = 11" 5M FMC ACTUATOR = M~TBAKER KB. ELEV = 75.9' BF. ELEV = 45.5' KOP = 1489' Max Angle = 53 @ 3984' Datum MD = 10965' Datum TVD = 8800' SS ~ H-31 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 3582' Minimum ID = 3.725" @ 10589' 4-1 /2" OTIS XN NIPPLE 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" ~ 10602' TOP OF5-1/2"LNR 10604' 7-5/8" CSG, 29.7#, NT-95HS, ID = 6.875" ~-j .10778' PERFORATION SUMMARY REF LOG: ATLAS BRCS ON 02/21/94 ANGLE AT TOP PERF: 13 @ 10864' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sgz DATE 3-3/8" 6 10864 - 10900 C 03/25/94 3-3/8" 6 10978 - 10988 C 03/06/94 3-3/8" 6 10992 - 11017 C 03/06/94 3-3/8" 6 11030 - 11050 C 06/08/94 PBTD 5-1/2" LNR, 17#, 13-CR-80, .0232 bpf, ID = 4.892" -{ ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3872 3208 50 CAM KBMG-M BK 4 7424 5493 40 CAM KBMG-M BK 3 9653 7510 13 CAM KBMG-M BK 2 10030 7880 11 CAM KBMG-M BK 1 10452 8295 10 CAM KBMG-M BK 10477' 4-1/2" OTIS X NIP, ID = 3.813" 10539' 7-5/8" X 4-1/2" BKR PERM PKR, ID = 3.875" 10572' 4-1/2" OTIS X NIP, ID = 3.813" 10589' 4-1/2" OTIS XN NIP, ID = 3.725" 10589' 4-1/2" PXN PLUG (06/16/08) 10602' 4-112" WLEG, ID = 3.958" 10600' ELMD TT LOGGED 03/06/94 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/06/94 ORIGINAL COMPLETION 12/20/04 RDJ/PAG WAVER SAFETY NOTE REV2 03/01/01 SIS-LG FINAL 11/08/06 SKB/TLH CARS PROJECT=SAFETY NO 07/18/01 RNITP CORRECTIONS 02/11/07 RPWPAG WANERSAFETY NOTEREV3 07/15/03 CMO/TLP KB ELEVATION CORRECTION 06/25/08 /SV WAVER SAFETY NOTE 11/28/03 KDGPAG WAVER SAFETY NOTE 06/25/08 SWC/SV SET PXN (06/16/08) 04/19/04 TJP/KAK WAVER SAFETY NOTE REV PRUDHOE BAY UNIT WELL: H-31 PERMIT No: 1940140 API No: 50-029-22444-00 SEC 21, T11 N, R13E, 3552' FSL & 1265' FF1 BP Exploration (Alaska) S Y NOTES: CHROMETBG. ***SURF CSG LEAK. I~PWI ONLY/NO MI INJECTION ALLOWED'""' 11/08/06 UPDATE CARS PROJECT=200' 1/2" HOSE IN OA NORTH FACING VR PROFILE MAX OAP = 200 PSI. ***NOTE 12 JOINTS J-55 CSG BURST POINT*** **CHROME TUBING & LINER** 2104' 4-1/2" OTIS X NIP, ID = 3.813" GAS LIFT MANDRELS TREE = 4" SM CHR CAMERON WELLHEAD = 11" SM FMC H -31 i _ ACTUAT,O = BAKER ~ KB, EL'EV = 75.9' Pr oposed Complet BF. ELEV = 45.5' KOP = 1489' fi Max Angle = 53 @ 3984' Datum MD = 10965' Datum TVD = 8800' SS ;~; 7 5/8" 29.7# TGII Casing 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" ~~ 3582' Minimum ID = 3.725" @ 10589' 4-1/2" OTIS XN NIPPLE 4-1/2" TBG, 12.6#, L-80 Vam Top HC -~ 4-1/2" TBG, 12.6#, 13-CR .0152 bpf, ID = 3.958" 10602' TOP OF 5-1 /2" LNR 7-5/8" CSG, 29.7#, NT-95HS, ID = 6.875" ~ PERFORATION SUMMARY REF LOG: ATLAS BRCS ON 02/21/94 ANGLE AT TOP PERF: 13 @ 10864' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10864 - 10900 C 03/25/94 3-3/8" 6 10978 - 10988 C 03/06/94 3-3/8" 6 10992 - 11017 C 03/06/94 3-3/8" 6 11030 - 11050 C 06/08/94 PBTD 1-1 11249' ~ 5-1/2" LNR, 17#, 13-CR-80, .0232 bpf, ID = 4.892" ~ SAFETY NOTES: CHROMETBG. ***SURFCSG LEAK. NI ONLY/NO MI IWECTION ALLOWED"*" 11 UPDATE CARS PROJECT=200' 1/2" HOSEIN OA NORTH FACING VR PROFILE MAX OAP = 200 PSI. ***NOTE 12 JOINTS J-55 CSG BURST POINT*'* "CHROME TUBING & LINER"" 4-1/2" HES X NIP, ID = 3.813" 7 5/8" X 4-1/2" BAKER S-3 PKR 4-1/2" HES X NIP, ID = 3.813" 4-1/2" HES XN NIP, ID = 3.725" 10539' 7-5/8" X 4-1/2" BKR PERM PKR, ID = 3.875" 10572' 4-1/2" OTIS X NIP, ID = 3.813" 10589' 4-1/2" OTIS XN NIP, ID = 3.725" 10602' 4-1/2" WLEG, ID = 3.958" 10600' ELMD TT LOGGED 03/06/94 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/06/94 ORIGINAL COMPLETION 12/20/04 RDJ/PAG WANER SAFETY NOTE REV2 03/01/01 SIS-LG FlNAL 11/08/06 SKB/TLH GARS PROJECT=SAFETY NOTE 07/18/01 RN/TP CORRECTIONS 02/11/07 RPWPAG WANER SAFETY NOTE REV3 07/15/03 CMO/TLP KB ELEVATION CORRECTION 06/25/08 /SV WANER SAFETY NOTE 11/28/03 KDGPAG WANER SAFETY NOTE 06/25/08 SWGSV SET PXN (06/16/08) 04/19/04 TJP/KAK WANERSAFETY NOTE REV PRUDHOE BAY UNff WELL: H-31 PERMff No: 1940140 API No: 50-029-22444-00 SEC 21, T11 N, R13E, 3552' FSL 8 1265' FEL BP Exploration (Alaska) 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): ') STATE OF ALASKA ) RECEIVED REP~~~~~ ~~:~~;S~~~~N ~~M~~~c;IOt-ÆC 2 9 2004 Alaska Oil & Gas Cons. Commission Stimulate D AnchoráWEfrOO Cancel Sundry Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 194..0140 6. API Number 50-029-22444-00-00 Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Plug Perforations D Perforate New Pool D Perforate D WaiverO 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 75.90 8. Property Designation: ADL-0028283 11. Present Well Condition Summary: 4. Current Well Class: Development D Stratigraphie D 9. Well Name and Number: H-31 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Exploratory 0 Service ŒJ Total Depth measured 11330 feet measured 11249 feet Plugs (measured) Junk (measured) None true vertical 9235.5 feet Effective Depth None true vertical 9155.4 feet Casing CONDUCTOR LINER PRODUCTION SURFACE Length 80 726 10751 3552 Size 20" 91.5# H-40 5-1/2" 17# 13Cr80 7-5/8" 29.7# NT-95HS 10-3/4" 45.5# L-80 MD TVD Burst 1490 7740 8180 5210 Collapse 470 6280 5120 2480 31 111 31.0 - 111.0 10604 - 11330 8521.3 - 9235.5 27 - 10778 27.0 - 8692.8 30 - 3582 30.0 - 3097.2 Perforation depth: Measured depth: 10864 -10900,10978 -10988,10992 -10997,10997 -11017,11030 -11050 True vertical depth: 8776.95 - 8812.06,8888.36 - 8898.17,8902.09 - 8907,8907 - 8926.64,8939.41 - 8959.08 Tubinç¡ ( size, ç¡rade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 25 10602 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 5-1/2" Baker Type H Packer @ 5363- @ 5394- 5367 5398 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure SCANNED JAN 0 6 2.005 13 Oil-Bbl Tubing Pressure Prior to well operation: Subsequent to operation: Copies of Logs and Surveys run - Daily Report of Well Operations - ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD Service ŒJ 14. Attachments: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron J<f~G~ rY^ R£~ WAG ŒJ GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: 303-320 Title Production Technical Assistant Signature Phone 564-4657 Date 12/22/04 ~~ Form 10-404 Revised 4/2004 BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp October 12, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: H-31 (PTD 1940140) Application for Sundry Approval Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well H-31. This request is for approval to continue water injection in well with a Surface Casing Leak. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or me at (907) 659-5102. Sincerely, Joe Anders, P.E. Well Integrity Coordinator Attachments 1) Application for Sundry Approval form 10-403 2) Description Summary of Proposal 3) Wellbore Schematic RECEIVED OCr ;l ZOE Alaska Oil & Gas Cons. Commissio~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon D Suspend r-] Operation Shutdown E] Perforate~-] variance. AnnuarDisposalr-~ Alter Casing D Repair Well D Plu.q Perforations D Stimulated Time Extensionrl Otherr'-I Change Approved Program [-'l Pull Tubin.q D Perforate New Pool D Re-enter Suspended WellD H20 INJ VARIANCE 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development r"] Exploratory[-] 194-014 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic[--~ Service. 50-029-22444-00-00 7. KB Elevation (ft): 9. Well Name and Nu/mber: RKB 64.00 H-31 r 8. Property Designation: 10. Field/Pool(s): ADL 028280 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft):l 1330 ITotal Depth TVD ('t): I Effective Depth MD (ft): I Effective Depth TVD ('t): I Plugs (measured): IJunk (measured):9237 11110 9018 None None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 110 20" 31' - 141' 31' - 141' 40K 520 Surface 3551 10-3/4" 31' - 3582' 31' - 3097' 80K 4020 Intermediate 10747 7-5/8" 31' - 10778' 31' - 8693' 80K 4790 Sidetrack Liner 727 5-1/2" 10603' - 11330' 8520' - 9236' 80K 6280 Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: I Tubing Grade: Tubing MD (ft): 10864' - 11050'I 8701' - 8883' 4-1/2" 12.6#I 13CR-80 10602 Packers and SSSV Type: Packers and SSSV MD (ft): 7-5/8" x 4-1/2" BKR Perm PKR, Otis X Nipple PKR @ 10539', Nipple @ 2104' 12. Attachments: Description Summary of Proposal, 13. Well Class after proposed work: Detailed Operations Program r"] BOP Sketch [-] Exploratoryr-] Development[-'~ Service~ 14. Estimated Date for 10/12/2003 15. WeoIlil~.~tus afte(~aPrsOr~OSed W;iuk:gged[_.l Commencing Operation: , Abandonedr'l 16. Verbal Approval: Date: wAGF'~ GINJr-] WINJB WDSPLr"] Commission Representative: Prepared by DeWayne R. Schnorr 564-5174, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders Printed Name Joe Anders Title Well Inte~lrity Coordinator Signature ,~/r.~0 ~~J.A/~ Phone (907) 659-5102 Date 10/12/03 jv Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP TestD Mechancial Integrity TestD Location ClearanceD Subsequent Form Required: Alaska 0il & Gas Cons. Cornmissk~ Anchorage ~..~,,~ BY ORDER OF Approved by:~_~ ~ - '"~""~ ~ ~ COMMISIONER THE COMMISSION Date: / Form 10-403 Revised 2/2003 n !GINAL SUBMIT IN DUPLICATE H-31 Description Summary of Proposal 10/12/03 Problem: Injector with Surface Casing Leak Well History and Status: Well H-31 (PTD 1940140) is a produced water injector that exhibits a Surface Casing Leak. This sundry request is to allow for continued water injection, Recent Events: > 09/29/02: > 09/21/03: MIT IA to 3000 Passed. MIT OA to 3000 Failed, broached to surface. At ,-" 1200 psi fluid came up the flutes.--X-' MIT-IA to 3000 psi passed. Fluid rose to flutes of conductor while bleeding IA, fluid stopped rising as OAP fell 4~'Ywith IA bleed. This sundry request is to allow for continued water injection only. The following supports this request: · A MIT-IA passed to 3000 psi on 09/21/03, demonstrating competent tubing and production casing. · The TIO plots do not indicate T x IA communication. /'' · An MIT-IA will be conducted every 2 years to monitor tubing and production casing competency. Proposed Action Plan: 1. Allow well to continue water injection only. 2. Record wellhead pressures and injection rates daily. 3. Submit monthly report of daily pressures and injection rates. 4. Perform MIT-IA every 2 years. 5. Stop injection and notify the AOGCC if there is any indication of loss of tubing and production casing integrity. ACTUATOR = BAKER KB. ELEV = 75.9' BF. ELEV = 45.5' KOP = 1489' Max Angle = 53 @ 3984' Datum MD= 10965' I 2104' H4.1/2,, OTIS X NIP, ID = 3.813" DatumTVD= 8800' SS O I J 10-3/4" CSG, 45.5#, L80, D =9.953" H 3582' ~-~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3872 3208 50 CAM KBMG-M BK 4 7424 5493 40 CAM KBMG-M BK L 3 9653 7510 13 CAMKBMG-M BK 2 10030 7880 11 CAM KBMG-M BK Minimum ID 3.725" ~ ~ 10589' 1 10452 8295 10 CAM KBMG-M BE 4-1/2" OTIS XN NIPPLE I,' ~1 10477' H4-1/2"OTISXNIP, ID:3.813" J ~ X I 10539' H7-5/8"X4-1/Z'BKRPERMFKR, ID=3.875" J I I B. i 10572' H4-1/2"OTISXNIR1D=3.813'' I · I 10589' H 4-1/2" OTIS XN NIP, ID=3.725"I · I I--t · I 1o602' I--t4-1/2"WLEG,,D:3.958"I I 7-5/8" CSG, 29.7#, NT-95HS, ID = 6.875" I--I 107'78' PERFORATION SUIVIVIARY REF LOG: ATLAS BHCS ON 02/21/94 ANGLE AT TOP PERF: 13 @ 10864' Note: Refer to Production DB for historical perf data SEE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10864 - 10900 O 03/25/94 3-3/8" 6 10978 - 10988 O 03/06/94 3-3/8" B 6 10992 - 11017 O 03/06/94 3-3/8" 6 11030 - 11050 O 06/08/94 I H I I~-~,~,, LNR, 17#,' 3-CR-80, .0232 bpf, ID: 4.8gz' I-I ~330' I I DATE REV BY COMIVENTS DATE REV BY COIVIVIID, ITS PRUDHOE BAY UNIT 03106/94 ORIGINAL COMPLETION WB.L: H-31 02/16/01 SIS-SLT CONVERTED TO CANVAS FERIVIT No: 1940140 03101101 SIS-LG = FNAL APINo: 50-029-22444--00 07/18/01 RN/'rP CORRECTIONS SEC 21, T11N, R13E 3552'FSL& 1265' FEL 07/15/03 CMO/TLP KB ELEVATION CORRECTION BP Exploration (Alaska) PERFORATION SUIVIVIARY REF LOG: ATLAS BHCS ON 02/21/94 ANGLE AT TOP PERF: 13 @ 10864' Note: Refer to Production DB for historical perf data SEE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10864 - 10900 O 03/25/94 3-3/8" 6 10978 - 10988 O 03/06/94 3-3/8" 6 10992 - 11017 O 03/06/94 3-3/8" 6 11030 - 11050 O 06/06/94 DATE REV BY COMIVENTS DATE REV BY COrvtVII~ITS 03106/94 ORIGINAL COMPLETION 02/16/01 SIS-SLT CONVERTEDTOCANVAS 03/01/01 SIS-LG FNAL 07/18/01 RNfrP CORRECTIONS 07/15/03 CMO/TLP KB ELEVATION CORRECTION STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate_ SCH MOO-B-GONE Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora[le, AK 99519-6612 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X 4. Location of well at surface 1727' FNL, 1265' FEL, Sec. 21, T11N, R13E, UM At top of productive interval 2691' FNL, 1250' FEL, Sec. 20, T11N, R13E, UM At effective depth 2703' FNL, 1272' FEL, Sec. 20, TllN, R13E, UM At total depth 2704' FNL, 1306' FEL, Sec. 20, T11N, R13E, UM (asp's 643333, 5959061) (asp's 638090, 5957999) (asp's 638068, 5957987) (asp's 638034, 5957985) 12. Present well condition summary Total depth: measured true vertical 11330 feet Plugs (measured) 9237 feet Effective depth: measured true vertical Casing Length Conductor 110' Surface 3551' Production 10747' Liner 727' 11110 feet Junk (measured) 9018 feet 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number H-31 9. Permit number / approval number 194-014 10. APl number 50-029-22444-00 11. Field / Pool Prudhoe Field / Prudhoe Pool TD Tag @ 11110' (01/10/1999) Size Cemented Measured Depth True Vertical Depth 20" 260 sx Arcticset 141' 141' 10-3/4" 1180 sx CS III, 320 sx 3582' 3097' Class 'G' 7-5/8" 265 sx Class 'G' 10778' 8693' 5-1/2" 120 sx Class 'G' 10603' - 11330' 8520' - 9236' Perforation depth: measured Open Perfs 10864'-10900', 10978'-10988', 10992'-11017', 11030'-11050' true vertical Open Perfs 8701 '-8736', 8890'-8900', 8904'-8929', 8864'-8883'~'::;~!'~'~'}~"~' ~"* ~ ~' ? F [} Tubing (size, grade, and measured depth) 4-1/2" 12.6~ 13CR TBG ~ 10602'. Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" Baker Perm Packer ~ 10539' MD. Otis X Nipple ~ 2104' MD. A~as~(~ 0d ~ ~a~s C~i';S. OOi'il~TiJSSiO~ 13. Stimulation or cement squeeze summa~ ,anchorage Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 05/17/02 Subsequent to operation 05/24/02 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 5897 6369 Tubing Pressure 1144 2655 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended _ Service WAG INJECTOR 17. I hereby certify that the foreg_oing~s t~e and correct to the best of my knowledge. DeWayne R. Schnorr Date June 28, 2002 Prepared by DeWayne R. Schnorr 564-51 Form 10-404 Rev 06/15/88 · SCANNED JUL .t. 0 20 02 SUBMIT IN DUPLICATE H-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/22/2002 SCMOO-B-GONE--SBG' SCMOO-B-GONE EVENT SUMMARY 05/22/02 SCHMOO-B-GONE TREATMENT FROM WELL HEAD. Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( O TESTS) 172 SCHMOO-B-GONE 172 TOTAL Page I 5CANNED J U L ~L 0 20 02: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Camille O. Taylor~T' DATE: September 1, 2001 Chair _ _~SUl SUBJECT: Mechanical Integrity Tests Tom Maunder ~'~~ BPX P.I. Supervisor c~~ W-P & H Pads W-42 P-24 & H-31 John Crisp Prudhoe Bay Unit Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. "w~,I w~ I Type,nj.! . i~.v.~. I~ I Tub, ngl~o I ~ I ~ I I,m~a,I o P.T.D.I 1880570 ITypetesti P ITestpsil 2078 JCasingJ 0 J 3OOO I 2720 !, I P/F I'F Notes: Converted from Producer. Li.'.P.T.D.I 'm70540 ITypete~I P IT~psil 2~ I Casml 700 I 2,~0 I 2,~ I 2,~ I P~= I ~ Notes: "w'~'l "-~ i~"e'n~-I ~ !~'v'~- I~ I~u~"~ I~ I~° '1 ~ I~° i"~'1 ~ ' P.T.D.I '~,0140 IT~petesq P ITestpsil 2114 l C~ngl 700 I 247S I 2:~0 I 2~0 I P.~ I ~P " WellJ , P.T.D.I we, J l ~,e,.j. II T.V.O. I I ~uU.g II I I I~nterva~l Type testI !TMpsi l ICasingI I ! I I P~: ! Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Itraveled to BP's Prudhoe Bay Field to witness MIT's on W-P & H Pads. These MIT's were spread out over the Field causing longer than normal test & travel times. One failure witnessed, W-42. Kevin Yeager was BP Rep. in charge of testing. Testing was conducted in a safe & efficient manner. As always, Kevin was a pleasure to work with. M.I.T.'s performed: 3_ Attachments: Number of Failures: 1_ Total Time during tests: _6 cc: MIT report form 5/12/00 L.G. MIT PBU W-P & H Pads 9-01-01jc.xls 9/4/01 H-3 li Cement Bond Log Subject: H-31i Cement Bond Log Date: Wed, 23 Dec 1998 16:41:22 -0500 From: "Schmoyer, Al" <SchmoyAL2~bp.com> To: "'blair_wondzell~admin.state.ak.us"' <blair_wondzell@admin.state.ak.us> CC: "McCorkle, Frank A." <McCorkFA~BP.com>, "Rathmann, Mike P" <RathmaMP~BP.com> Blair, H-31i was completed as an injector in 1994. At that time we were running Cement Bond logs on an "as-needed" basis; when cementing/completion operations indicated a potential problem. H-31 was converted to injection in Q4 97. I can find no record of a CBL having been run when the well was initially completed or prior to conversion to injection. The open perfs are from 10,864' to 11,050' The tubing tail is at 10,600' We tagged TD at 11,111' with a 3.625" drift on June 8 of this year. We should be able to run a CBL if that is deemed necessary. Lets discuss at you conveniance and decide a way forward. Thanks, A1 1 of 1 12/23/98 1:26 PM STATE OF ALASKA -!" ALASKA AND GAS CONSERVATION COM, ,~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [--I Operation Shutdown [--I Pull Tubing 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3552' NSL, 1265' WEL, SEC. 21, T11N, R13E At top of productive interval 2589' NSL, 1250' WEL, SEC. 20, T11N, R13E At effective depth At total depth 2577' NSL, 1315' WEL, SEC, 20. T11N, R13E [~] Stimulate [] Plugging r-I Perforate I--IAIter Casing []Repair Well [] Other Convert to Injector 5. Type of well: I~1 Development [] Exploratory [~ Stratigraphic [~ Service 6. Datum Elevation (DF or KB) 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number H-31 (33-20-11-13) 9. Permit Number / Approval No. 94-14 10. APl Number 50-029-22444 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 11330' feet Plugs (measured) 9237' feet 11249' feet Junk (measured) 9157' feet Length Size Cemented Structural Conductor 110' 20" 260 sx Arcticset Surface 3506' 10 3-4" 1180 sx CS 111/320 sx Intermediate 10702' 7 5/8" 265 sx Class "G" Production Liner 727' 5 1/2" 120 sx Class "G" MD TVD 184' 184' 3582' 3097' 10778' 8693' 10603'-11330' 8520'-9236' Perforation depth: measured true vertical 8701'-8736'; 8890'-8900'; 8904'-8909';8909'-8929';8864'-8883' 10864'-10900'; 10978'-10988'; 10992'-10997'; 10997'-11017'; 11030'- 11050' Tubing (size, grade, and measured depth) 4-1/2", 13CR80 @ 10602' Packers and SSSV (type and measured depth) Packer @ 10539' SSSV @ 2104' ORIG NAL 13. Stimulation or cement squeeze summary Intervals treated (measured) Converted to injector on October 13, 1997 Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil I--I Gas [] Suspended [] Daily Report of Well Operations i7. I hereby certif,~thabthe f~g. oing is true. acd correct to the best of my knowledge Service Convert to Injector Title Technical Assistant III Prepared By Name/Number: Form 10-404 Rev. '06/15/88 Submit In Duplicate H-31 Converted to Injector PERFORM MIT TEST ON WELL. ON OCTOBER 13, 1997 WELL HAS BEEN CONVERTED FROM PRODUCER TO INJECTOR. INITIAL PRESSURES · SIWHP = 1300 lAP = 0. RIG UP HB&R TO INNER ANNULUS AND PUMP DIESEL DOWN BACK SIDE. AT 13:45 SIWHP = 1350 lAP = 2700 HOLD FOR PRESSURE TEST. AT 14'15 SIWHP = 1350 lAP = 2600. GOOD PRESSURE TEST. BLEED BACK INNER ANNULUS PRESSURE TO 500 PS! AND RIG DOWN. WELL PASSED MIT TEST. AOGCC WITNESSED BY MR. CHUCK SCHEVE. PERMIT DATA AOGCC individual Well Geological Materials inventory 94-014 94_01 r~ ~,-- ~ o 1/4 0 , 94-014 ~LY WELL OP 94 ~ ~ ~ 94-014 ~FL/GR/SP 94~014 94-014 94~-014 T 10114-11316, OH-DIFL/AC R COHP DATE' 03/06/94 R 02/05/94-02/26/94 R 100-10715 L 10772-11288 L 10441-1~3~6 · .iUPJFC/GR/CCL (JWL) L 10850-11120 G/~PC/GR/OL L i0740-10955 U/P_~-'FC/GR/'CL L I0900-i1!~7 ~Ls (STATiC/TEHP L '10856-11228 aw/gROD L 10750-11120 ~VD ~ ~ ~ ~ 10114-~1316 Page' 1 Date' 10/'1_3/95 RUN DATE_RECVD 1 03/09/94 04/~1/9¢ 04/11/94 04/11/94 1 03/30/94 1 03/30/94 1 04/28/94 ! 04/29/94 1 06/24/94 1 04/28/94 1 08/25/94 1 03/30/94 yes ~~.nd received? Are dry ditch samples required'> Was the well cored-? yes ~~nalysis & describe-ion received? Are well tests required? ~\~yes Received? yes no Well is in compliance !ni%ial COHMENTS yes no ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 23 August 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION ECC No. ~-[~( C-24 (14-19-11-14) 1 PL/GASENTRY FINAL BL i PL/GASENTRY RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run ~ 1 2621.06 Run # 1 Run ~ 1 3457.05 Run # 1 1 PL/GASENTRY FINAL BL 1 PL/GASENTRY RF SEPIA Run # 1 3564.01 Run # 1 '~-~% E-06 (33-6-1!-14) ¢~-77 w-37 (24-21-11-12) 1 CN/GR FINAL BLUELINE 1 CN/GR FINAL RF SEPIA 1 PL/GASENTRY FINAL BL 1 PL/GASENTRY RF SEPIA Run # 1 Run # 1 3573.02 Run $ 1 5010.03 Run # 1 1 PL/LEAKDET. FINAL BL Run ~ 1 1 PL/LEAKDET. RF SEPIA Run ~ 1 5025.02 1 GR/CCL JEWL.FINAL BL 1 GR/CCL JEWL.RF SEPIA Run # 1 Run ~ 1 5157.02 1 PL/PROFILE FINAL BL 1 PL/PROFILE RF SEPIA Run # 1 Run # 1 5602.02 I PL/PROFILE FINAL BL 1 PL/PROFILE RF SEPIA Run # 1 Run ~ 1 6158.05 Cont/ Please sign end return ~o: Petrotechnical Data Cente~ BP Exploration (Alaska) Ino 900 East Benson Boulevard Anchorage, ~ ~9908 Received bF Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Re c e ived b~./ _//~ _~./// /j~-/ ~ a t e: RECEIVED JUN 2 4 i994 Alaska Oil & Gas Oons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Dear Sir/Madam, Date: 15 June 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Enclosed, please find the data as described below: WELL # DESCRIPTION R-10 F-34 (44-35-12-13) //1 PLS PRESURE FINAL BL 1 PLS.PRESURE RF SEPIA PLS PRESURE FINAL BL 1 PLS PRESURE RF SEPIA ECC No. Run ~ 1 5823.01 Run # 1 Run # 1 Run # 1 61~1.02 H-13 /1 PFC/GR/PERF FINAL BL 1 PFC/GR/PERF RF SEPIA Run ~ 1 6090.01 Run # 1 C-30 /~ PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 3983.01 Run ¢ 1 H-25 /1 PFC/GR/PERF FINAL BL 1 PFC/GR/PERF RF SEPIA Run ¢ 1 5666.02 Run # 1 H-19 (22-15-11-13) ~ PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 3448.01 Run # 1 R-27 P-23 (41-32-11-13) //1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 5670.03 Run # 1 Run # 1 6043.03 Run # 1 H-32 (42-20-11-13) /I PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 6170.04 Run # 1 H-31 /1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 6158.04 Run # 1 N-21 ,/1 DTEMP/GR FINAL BL 1 DTEMP/GR RF SEPIA Run # 1 5630.01 Run # 1 C-ll /! DTEMP FINAL BL 1 DTEMP FINAL RF SEPIA Run # 1 5942.01 Run # 1 Cont/ PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA_PLUS Page: 1 Date: 05/03/94 RUN DATE_RECVD 94-014 94-014 94-014 94-014 94-014 BHC/AC/GR L 10772-11288 DIFL/GR/SP L 10441-11316 PFC/GR/CCL (JWL) L 10850-11120 PFC/GR/CL L 10740-10958 PLS (STATIC/TEMP L 10856-11228 94-014 SSTVD 94-014 407 94-014 DAILY WELL OP 94-014 SURVEY 94-014 6022 L 10114-11316 1 R COMP DATE: 03/06/94 R 02/05/94-02/26/94 R 100-10715 T 10114-11316, OH-DIFL/AC 1 03/30/94 03/30/94 04/28/94 04/29/94 04/28/94 03/30/94 04/11/94 04/11/94 04/11/94 03/09/94 Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance Initial yes no yes no Comments STATE OF ALASKA ALASI'C'~OIL AND GAS CONSERVATION COMMISSIC-!---- REPORT (.. SUNDRY WELL OPE,".ATIONS 1. Operations performed: Operation shutdown Stimulate, Plugging Pull tubing__ Alter casing __ Repair well Perforate X Other × 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 3552' NSL, 1265' WEL, SEC. 21, T11N, R13E At top of productive interval 2589' NSL, 1250' WEL, SEC. 20, T11N, R13E At effective depth At total depth 2577'NSL, 1315' WEL, SEC. 20, T11N, R13E 12. Present well condition summary Total depth: measured true vertical MAY 17 1995 Ngska 0il & Gas Cons. Commission AflCnOl~," 11330 feet Plugs (measured) 9237 feet 6. Datum elevation (DF or KB) KBE=75.9 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number H-31(33-20-11-13) 9. Permit number/approval number 94-14 / 10. APl number 50- 029-22444 11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 11249 feet Junk (measured) 9157 feet Casing Length Structural -- Conductor 110' Surface 3506' Intermediate 10702' Production -- Liner 727' Perforation depth: measured Size Cemented Measured depth 20" 260 sx Arcticset 184 '0 3/4" 1180 sx CS 111/320 sx "G" 3582 7 5/8" 265 sx Class "G" 10 778 5 1/2" 120 sx Class "G" 10603-11330 10864'- 10900', 109 78'- 10988', 10992'- 1099 7', 1099 7'- 11017' True vertical depth BKB 184 3097 8693 8520-9236 true vertical subsea 8701'-8736', 8890'-8900', 8904'-8909', 8909'-8929' Tubing (size. grade, and measured depth) 4 1/2", 13CR80 @ 10602' Packers and SSSV (type and measured depth) Packer @ 10539'and SSSV @2104' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 883 1749 15 2040 776 1557 671 2000 Tubing Pressure 2O2 222 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations. 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true andcorrect to the best of my knowledge. Signed k~~,,~(~' // ~/f~,~,~" Title SeniorTechnicalAssistantll Form 10-4~4[ Rev 06/15/88 ~'- ORIGINAL Date SUBMIT IN DUPLICATE 3/23/94 3~5~4 3/27/94 6/08/94 3495 WELL H-31(33-20-11-13) Addperf/Hydraulic Fracture Operation Performed a Hydraulic Fracture(IVISHAK) using the following fluids: FLUIDS PUMPED DOWNHOLE 1040 bbls TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME 70 Diesel to IA, tubing, or GC 80 Diesel Recovered (not downhole) 150 Total Diesel PETREDAT WINDOW NONE FLUID ADDITIVES BJ SPECTRA FRAC G4000 FLUID SYSTEM with 15 PPT silica flour and 40 PPG adomite regain in pad. No ESL. The following additional imerval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 10864' - 10900' MD Performed a Hydraulic Fracture(Sag) using the following fluids: Operational problems Engine quit on sand king, had to go to backup powerpack. Had short duration drop in sand conc, but acceptable. Comments 10 min after pad on perfs during frac, saw definite signs of containment. Looked like TSO started about on time, 60 min vs 62 design, but formation looked real stiff. All in all, should be ok, with 117 bbls of 8# behind pipe. No treesaver rubber left in hole. with 15 PPT silica flour and 40 PPG adornite regain in pad. No ESL. FLUIDS PUMPED DOWNHOLE INJ TEST: 384 Bbls DATA FRAC: 693 Bbls FRAC: 2418 Bbls TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME 150 Diesel to IA, tubing, or GC 0 Diesel Recovered (not downhole) 150 Total Diesel FLUID ADDITIVES BJ SPECTRA FRAC G4000 FLUID SYSTEM with 15 PPT silica flour and 40 PPG adomite regain in pad. No ESL. The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 11030' - 11050' MD ALASKA OIL & GAS CONS 'ATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA -' Date ! 23 April 1994 RE: Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION ~R~_ I~_ X-34ST (34-1-10-14) PLS STATIC FINAL BL PAS S~%~IC RF SEPIA X-35 (11-12-10-13) ECC No. A-9 Run # 1 6122.03 Run # 1 G-02 (22-07-11-14) 1 PFC/PERF FINAL BL Run W 1 6168.01 /1 PFC/PERF RF SEPIA Run ~ 1 X-27 (13-32-11-14) 1 PLS STATIC FINAL BL /1 P~.S s~ RF SEPIA 1 PL STATIC FINAL BL /1 PL STATIC RF SEPIA D-21 (31-25-11-13) i PLS STATIC FINAL BL /1 PLa ST~~RF SEPIA Run ~ 1 5694.02 Run ~ 1 Run ~ 1 4608.03 Run $ 1 Run ~ 1 5853.02 Run ~ 1 Run ~ 1 6158.03 Run # 1 Run ~ 1 6074.02 Run ~ 1 1 PFC/PERF FINAL BL /1 PFC/PERF RF SEPIA Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Sonya Wallace (MB 3-3) ~ Received by: Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 ~~~~~0 Date: "4/'~'~/f'~ O';/ 9 /994 ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT . 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 19 April 1994 RE: Transmittal of Data Sent by: ANCH. EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. 1 PLS PROFILE FINAL BL Run # 1 1 PLS PROFILE RF SEPIA Run # 1 5746.02 B-29 (32-3-1-11-14) 1PLS STATIC FINAL BL PLS STATIC RF SEPIA 'Run # 1 Run # 1 5818.02 D-22 (42-23-11-13) _fl PLS STATIC FINAL BL 1PLS STATIC RF SEPIA Run # 1 Run ~ 1 6091.03 G-16 (44-11-11-13) ~ PLS STATIC FINAL BL 1 PLS STATIC RF SEPIA Run # 1 Run # 1 1130.03 G-17 (12-18-11-14) j 1 PLS STATIC FINAL BL 1 PLS STATIC RF SEPIA Run # 1 Run ~ 1 1113.04 c-38 (41-18-11-14) 1PLS STATIC FINAL BL PLS STATIC RF SEPIA Run # 1 Run ~ 1 5785.01 9%-\\7_ P-23 (41-32-11-13) . . 1 PLS STATIC FINAL BL 1 BA~'STATICRF SEPIA /1 PLS STATIC FINAL BL 1 PLS STATIC RF SEPIA Run # 1 Run Run Run 6043.02 6158.01 ./1 PL STATIC FINAL BL 1 PL STATIC RF SEPIA Run ~ 1 Run # 1 3267.01 Cont/ ALASKA-OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 18 April 1994 RE: Transmittal of Data Sent by: ANCH. EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION 1 CN/GR/CCL FINAL BL CN/GR/CCL RF SEPIa 1DIFF.TEMP. FINAL BL DIFF.TEMP, RF SEPIA ~-~<~ Y-18 (14-22-11-13) ~G-26 /i PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA /~CCL/PERF FINAL BL 1 CCL/PERF RF SEPIA /1 GAMMA RAY FINAL BL 1 GAMMA RAY RF SEPIA ~J~5 G-14 (12-12-11-13) ~ CN/GR FINAL BL 1 CN/GR RF SEPIA qq- I~ H-31 - . ~ -t$~7- E-24 /~PFC/PERF FINAL BL PFC/PERF RF SEPIA i PFC/PE~ R~ SEPIa ~ PFC/PERF FINAL BL 1 PFC/PERF RF-SEPIA ~_~d~ D-20 / 1 CN/GR FINAL BL 1 CN/GR RF SEPIA %0-O~ B-01 (23-31-1!-14) /1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA W-OS (11-26-11-12) /1 PDK-100/GR FINAL BL 1 PDK-100/GR RF SEPIA ECC No. Run # 1 3076.02 Run # 1 Run # 1 493.02 Run # 1 Run # 1 3788.02 Run # 1 Run ~ 1 2621.05 Run # 1 Run # 1 2621.04 Run # 1 Run $ 1 5653.04 Run # 1 Run # 1 6158.02 Run # 1 Run # 1 . " 5978.'02 Run # 1 Run # 1 -' 6122.02. Run # i Run ~ 1 4928.01 Run # 1 Run # 1 5618.02 Run # 1 Run ~ 1 4117.01 Run # 1 cont/ %q -o9 ~-~ K-07 (23-33-12-14) ~0~-0'~. W-08 (11-26-11-12) ~'~ A-39 (31-35-11-13) /1 DIFF.TEMP. FINAL BL 1 DIFF.TEMP. RF SEPIA ~ PDK/GR/CCL FINAL BL 1 PDK/GR/CCL RF SEPIA CN/CR FINAL sr. 1 CN/GR RF SEPIA /1 GR JEWELRY FINAL BL 1 GR JEWELRY RF SEPIA 1 GR/CCL FINAL BL / 1 GR/CCL FINL.RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 Run # Run # 1 Run # 1 Run # 1 Run ~ 1 Run # 1 4528.04 3089.01 3770.02 4117.02 5999.02 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Sonya Wallace (~ 3-3) Petrotechnical Data Center .. o -. BP Exploration (Alaska) Inc... 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/~adam, Enclosed, please find the data as described below: WELL ~/~Z G-16 (44-11-11-13) ~ (-~g B-16 (21-32-11-14) G-09 B-08 (43-30-11-14) C-32 H-31 K-l! (32-33-12-14) x-08 ~~ ~-20a DESCRIPTION 1 PLS FINAL BL+RF 1 CN FINAL BL+RF 1 PLS FINAL BL+RF 1 CN FINAL BL+RF 1 PDK FINAL BL+RF 1 PLS FINAL BL+RF 1 CCL FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run ~ 1 1130.06 Run # 1 4041.04 Run # 1 4528.06 Run # 1 5842.05 Run # 1 6020.02 Run # 1 6158.06 Run # 1 6189.03 Run # 1 6234.04 Run # 1 6624.01 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Received by: Anchorage, AK 99518 o (907) 563-7803 Date: Rece J.~,ed b~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION coMMIsSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] ~ [] ABANDONED [] SERVICE [] 2. Name of OperatOrBp Exploration 0 R I G INA L 7. Permil Number94.14 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22444 4. Location of well at surface ~; ....... · ....... 9. Unit or Lease Name '-~-' . -:- '-:1 1727' SNL, 1265' WEL, SEC. 21, T11N, R13E~ ::'~';~r~':':~: ~:,'.'~' ~ [ Prudhoe Bay Unit :' !"\i'~:: I 'i 10, Well Number At Top Producing Interval:.:'~' -~'~ H-31 (33-20-11-1 3) At Total Depth - ~~.,,~~ Prudhoe Bay Fiold/Prudhoe Bay Pool 2709'SNL, 1296' WEL, SEC. 20, T11N, R13E ' "~ .... : 5. Elevation in feet (indicate KB, DF, etc.) ~. Lease Designation and Serial No. KBE = 75.9' I ADL 28283 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ]15. Water Depth, if offshore 116. No. of Completions 2/7/94 2/21/94 3/6/94I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey p0. Depth where SSSV set ~21. Thickness of Permafrost / 11330'MD/9237'TVD 11249'MD/9157'TVD YES [] NO [] 2104'feet MD ! 1900'(Approx.) 22. Type Electric or Other Logs Run GR/BHCS/DIL/MWD 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5t/ H-40 30' 110' 30" 260 sx Arcticset (Approx.) 10-3/4" 45.51/ NT-8OLHE 32' 3582' 13-1/2" 1180 sx CS 111/320 sx "G" 7-5/8" 29. 71/ NT-95HS 27' 10778' 9-7/8" 265 sx Class "G" 5-1/2" 17t/ 13CR80 10603' 11330' 6-3/4" 120 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Boltom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET(MDI Gun Diameter 3-3/8" 6 spf 4-1/2", 13CR80 10602' 10539' MD TVD 109 78'- 10988' 8890'-8900' 10992'-10997' 8904'-8909' z6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10997'-11017' 8909'-8929' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethed of Operation (Flowing, gas lift, etc.) 3/6/94 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL ~,S-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence et oil, gas or water. Submit core chips. /APR ~'-'.lasKa uii & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE. SIDE ! 29. 30. GEOLOGIC MARKERS F~RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravily, MEAS. DEP71-1 TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 10864' 8701' Shublik 10894' 8730' Top Sad/erochit 109 78' 8812' HOT 11152' 8984' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed t. ~'-/" ~' '~. ,/:- · !//" ..... Title Drilling Engineer Supervisor Date 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". R ~L C E IV ~ Form 10-407 Gas Cons. Commission Anchorage BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: H-31 NORTH SLOPE PRUDHOE BAY PRUDHOE BAY ACCEPT: 02/07/94 04:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 18E WO/C RIG: NABORS 18E 02/05/94 ( 1) TD: 0'( 0) 02/06/94 ( 2) TD: 0'( 0) 02/07/94 ( 3) TD: 0'( 0) 02/08/94 ( 4) TD: 950' ( 950) 02/09/94 (5) TD: 2600'(1650) R/U ON H-31, PREP F/ REPAIR MW: 0.0 VIS: 0 MOVE RIG COMPONENTS TO H-PAD. CLEAR SNOW FROM AROUND H-31, LAY HERCULITE AND MATTING BOARDS AROUND WELL, N/U DIVERTER, SET SUB AND COMPLEXES, R/U NEW MUD LINE IN PUMP ROOM, BUILD WIND SHELTER AROUND DAMAGED DERRICK LEG, HEAT DERRICK LEG ENCLOSURE. MOVE CAMP/SHOP TO H-PAD. R/U ON H-31 MW: 0.0 VIS: 0 PREP DERRICK FOR REPAIRS TO LEG. INSTALL CATHEAD BACK BREAKK, CHANGE VALVES/SEATS IN #2 PUMP, INSTALL BEAVER SLIDE F/ REPAIRS, WELD ON NEW MUD LINE IN PUMP ROOM, INSTALL NEW DRAWWORKS BRAKES AND ADJUST. ASSEMBLE SHOCK HOSE AND INSTALL 4" DEMCO IN NEW MUD LINE. INSTALL NEW VALVES/SEATS IN #1 MUD PUMP. TAKE ON WATER/MIX MUD MW: 0.0 VIS: 0 MOVE SUB TO PAD CENTER AND UNPIN WHEELS. REPIN WHEELS/INSTALL FROG. LOAD DERRICK ON TRUCKS, TRANSPORT TO SUB. OFFLOAD. SET DERRICK, SPOOL LINE. INSTALL BOARD AND WINDWALLS. RAISE DERRICK, SPOT SUB AND COMPLEXES. GET STEAM AND WATER TO RIG, R/U FLOOR. ACCEPT RIG AT 0400 HRS ON 02/07/94. TAKE ON WATER IN PITS, PREP TO PICK UP TOOLS AND MIX MUD. DRILLING MW: 8.8 VIS:305 MIX SPUD MUD, P/U KELLY. N/U SURFACE BOP, MIX MUD, P/U STRAP BHA, FUNCTION TEST DIVERTER, KNIFE VALVES, BREAK DOWN, CHANGE MOTOR ANGLE, FILL HOLE TEST NEW MUD LINE, ORIENT. WASH OUT ICE PLUGS F/ 70-110'. DRILL F/ 110-170'. CHANGE SWAB/LINER IN %2 PUMP. DRILL F/ 170-950' DRILLING 13 1/2" HOLE MW: 9.2 VIS:200 DRILLING F/ 950-977'. SHORT TRIP TO 110'. HOLE SLICK. DRILLING F/ 977-1999' START KICKOFF OF WELL AT +/-990' CIRC 15 MIN AND SHORT TRIP TO 1000' NO PROBLEMS. DRILLING F/ 1999-2600' NO PROBLEMS. SLOWLY BRING MUD VIS DOWN. RECEIVED 0~1 & Gas f;or~s. 6omrnissio,, WELL : H-31 OPERATION: RIG : NABORS 18E PAGE: 2 02/10/94 ( 6) TD: 3595' ( 995) 02/11/94 ( 7) TD: 3595'( 0) 02/12/94 ( 8) TD: 5525' (1930) 02/13/94 ( 9) TD: 6580' (1055) 02/14/94 (10) TD: 7923' (1343) 02/15/94 (11) TD: 8238' ( 315) RUN 10 3/4" CSG MW: 9.6 VIS:162 DRLG 13 1/2" HOLE F/ 2600-3077'_ CIRC. SHORT TRIP TO 1400' HOLE OK. DRLG F/3077-3595'. CIRC FOR SHORT TRIP. MADE il STD SHORT TRIP TO 690'. HOLE IN GOOD SHAPE - NO FILL. CIRC AND CONDITION MUD AND HOLE FOR 10 3/4" CSG. DROP SURVEY - BLOW DOWN KELLY. POH. LD BHA. NO SURVEY. RU CASERS. RUN 10 3/4" SURFACE CASING - 65 JTS IN HOLE. RIH MW: 9.5 VIS: 46 FINISHED RUNNING TO 10 3/4" SURFACE CSG. TIGHT @ 2560' WASHED AND SPUDDED TO 2565' RAN TO BTTM W/ CSG. PU HANGER AND LANDING JT. RU BJ. CIRC AND RECIPICATE. FLUTED HANGER HUNG UP IN HYDRIL AND BROKE FLOW LINE. REPAIR BROKEN SECTION OF FLOWLINE. CIRC AND COND MUD AND HOLE FOR CMT JOB. TEST LINES. LD LANDING JT. WASH OUT DIVERTER. ND DIVERTER. RAN 1" PIPE TO 110'. BJ DID TOP JOB. REMOVE DIVERTER RISER. INSTALL 13 5/8" - 5K UNIVERSAL SPLIT SPEED HEAD. NU 13 5/8" - 5K BOPS REPAIR FLOWLINE. TEST SSH. CLEAN OFF RIG FLOOR. INSTALL TEST PLUG. TEST ALL BOPE RAMS AND VALVES. PU BHA, ORIENT, SHALLOW TEST MOTOR AND MWD, RIH. DRILLING MW: 9.8 VIS: 40 PU KELLY - BREAK CIRC - TAG PLUGS @ 3501' TEST CSG. DRLG PLUG, FC @3105', GOOD CMT, SHOE @3581', AND 10' NEW HOLE F/ 3595-3605' CIRC AND COND MUD. PERFORM LEAK-OFF TEST. FORMATION HELD. DRILLING F/ 3605-4620'. SHORT TRIP TO SHOE - INTERMENTENT SWABBING THROUGHOUT DRILLING F/ 4620-5525'. DRILLING MW:10.0 VIS: 49 DRILLING 9 7/8" HOLE F/ 5525-5635'. SHORT TRIP TO 4605' DRLG F/ 5635-6377' HIGH TORQUE LAS 200' DRILLED. PUMPED LO-HI VIS SWEEP AROUND. DROP SURVEY. POH. WORK PIPE THROUGH TIGHT AND SWABBING HOLE F/ 6300-5300' LD MWD AND LEAD DC. PU NEW BIT AND MWD. ORIENT TOOLS. RIH W/ BHA. SHALLOW TEST MOTOR AND MW/). CUT DRLG LINE AND SERVICE BLOCKS. RIH - FILL PIPE @ 10 3/4" SHOE. HOLE TIGHT @ 6267' PU KELLY AND REAM F/ 6267-6377' DRLG F/ 6377-~580'. DRILLING MW:10.0 VIS: 44 DRLG F/ 6580-6930'. CHANGE SWAB AND LINER IN #1 PUMP. DRLG F/ 6930-7419'. SHORT TRIP TO 6300'. NO PROBLEMS. DRLG F/ 7419-7923'. DRILLING MW:10.0 VIS: 41 PHASE 3 WEATHER CONDITIONS. PUMP LO-HI VIS SWEEP AROUND. SLUG DP. POH W/ 46 STDS DP TO 10 3/4" SHOE, HOLE IN GOOD SHAPE. CIRC @ 10 3/4" SHOE. WAIT ON WEATHER TO IMPROVE. RIH. HOLE IN GOOD SHAPE. DRLG 9 7/8" HOLE F/ 7923-8238' RECEIVED Al: i-! ! '1 1,994 Alaska Oil a Gas Cor~$. Corr, missior~, WELL : H-31 OPERATION: RIG : NABORS 18E PAGE: 3 02/16/94 (12) TD: 8845' ( 607) 02/17/94 (13) TD: 9908' (1063) 02/18/94 (14) TD:10792' ( 884) 02/19/94 (15) TD:10792' ( 0) 02/20/94 (16) TD: 10792' ( 0) 02/21/94 (17) TD:ll050' ( 258) DRILLING MW:10.0 VIS: 43 DRILLING F/ 8238-8457' CIRC BTTMS UP - DROP SURVEY - SLUG DP. POH. LD JARS, MUD MOTOR AND BIT. NO SURVEY. PU NEW BIT AND MUD MOTOR, ORIENT TOOLS. PU JARS AND SHALLOW TEST MOTOR AND MW/). RIH W/ BIT #4. BENCH MARK TELECO @ 6295'. RIH. REAM F/ 8385-8457'. HOLE IN GOOD SHAPE. DRILLING F/ 8457-8566' WORK ON PUMPS AIR - LOCKED. DRILLING F/ 8566-8845'. HAVING A HARD TIME SLIDING W/ PDC BIT - WALL STICKING. DRILLING MW:10.0 VIS: 43 DRILL F/ 8845-9498'. SHORT TRIP 11 STDS. NO PROBLEMS. DRILL F/ 9498-9530'. XO SWAB AND LINER IN #1 PUMP. DRILL F/ 9530-9908' SHORT TRIP TO HWDP MW:10.1 VIS: 50 DRILLING F/ 9908-10505'. SHORT TRIP. HOLE TIGHT @ 10475'. L/D 1 JT. REAM TIGHT HOLE F/ 10475-10505'. DRILLINF F/ 10505-10792' CIRC/COND AT TD, DROP SURVEY. PUMP DRY JOB. POH TO HWDP, STRAP OUT. RUN 7 5/8" CSG MW:10.1 VIS: 52 POH TO HWDP STRAP OUT, NO CORRECTION. RETRIEVE SINGLE SHOT W/ OVERHOT. RECOVER GOOD SURVEYS. RIH FILL PIPE AT 6500'. TAG BRIDGE AT 9708' PU KELLY. REAM TIGHT HOLE F/ 9708-9780' RIH TO 10717'. HIT TIGHT SPOT. REAM TIGHT HOLE F/ 10%17-10792' CIRC SWEEPS, PUMP PILL, BLOW DOWN KELLY. POH L/D 5" DP, BHA. PULL WEAR RING, XO TOP/BTM RAMS TO 7 5/8", TEST. R/U AND RIH W/ CSG. HOLD PREJOB SAFETY MEETING. P/U 3 1/2" DP AND RIH MW:10.1 VIS: 58 RIH W/ 7 5/8 CSG, PU CSG HANGER AND LAND CSG. MU CMT HEAD, CIRC CASING AND ATTEMPT TO RECIPROCATE PIPE. NO UPWARD MOOVEMENT TO 500K. GOOD CIRCULATION/FULL RETURNS. CIRC/COND MUD, RU BJ AND CEMENT. BACK OUT LANDING JT, R/D CASERS, INSTALL PACKOFF TEST. INSTALL TEST PLUGG, CHANGE RAMS (TOP/BTM) TO 3 1/2" R/U AND TEST BOPE. P/U STRAP BHA, PU 3 1/2 DP AND RIH. CUT/SLIP DRILLING LINE. XO KELLY. P/U 3 1/2 DP AND RIH. DRILLING 6.75" HOLE MW: 9.0 VIS: 42 TIH AND PU 3.5 DP. TAG CMT AT 10615. DRILL CMT F/10615-10693. TAG FLOAT COLLAR. TEST CSG TO 3500 PSI OK. DRILL FC/CMT/FS AND 10' NEW HOLE TO 10802. CIRC AND COND MUD DRILL F/10802 - 11050' TOP OF SAG AT 10877. SHUBLIK AT ~0895 AND SADLEROCHIT AT ~0978' (EST). RECEIVED Oas (,;oi~s. Oorrlmissio~, Ar','choracle, WELL : H-31 OPERATION: RIG : NABORS 18E PAGE: 4 02/22/94 (18) TD:l1330' ( 280) 02/23/94 (19) TD:l1330' ( 0) 02/24/94 (20) TD: 0 PB: 0 02/25/94 (21) TD: 11330 PB: 9236 02/26/94 (22) TD:l1330 PB: 9236 POOH F/5.5" LINER MW: 9.0 VIS: 39 DRILLING F/11050 T/11330 TD. CBU. SHORT TRIP TO 7-5/8" SHOE. CIRC LO/HI VIS SWEEPS AROUND. DROP EMS- PUMP DRY JOB. POOH FOR LOGS. RETRIEVE EMS. RU ATLAS AND RUN GR/BHCS/DIL. LOGGER TD AT 11320. RD ATLAS. PU BHA TIH TO 11330. 10' FILL. CIRC SWEEP AROUND, PUMP PILL, BLOW DN KELLY. DROP RABBIT. TOH FOR 5-1/2" LINER. P/U 2 7/8 DP FOR CLEANOUT MW: 8.9 VIS: 35 POH L/D BHA. PULL WEAR BUSHING, INSTALL TEST PLUG, XO BTM RAM TO 5.5", TEST. R/U RUN 5.5" LINER. CIRC PIPE VOLUME AT 7625' SHOE. RIH P/U CMT HEAD. CIRC/COND MUD, WORK PIPE TO 11330'. HAD 6' SOFT FILL ON BOTTOM. R/U BJ AND CEMENT LINER. R/U AND REV OUT. CIRC/COND MUD. PUMP DRY JOB. L/D CMT HEAD, POH CHAIN OUT, L/D RUNNING TOOLS. PULL WEAR BUSHING, INSTALL PLUG. PULL PLUG INSTALL WEAR BUSHING. P/U 4.75" MILL, 2 1/8" DC, 2 7/8" DP. RUNNING 4 1/2" TUBING MW: 0.0 RIH W/ 4 3/4" MILL AND 7" CSG SCRAPER AND 3 1/2" DP TO 10603'. C. O. CMT INSIDE 5 1/2" F/ 10605-10608'. RIH TO 11249' PBTD AND TAG LANDING COLLAR - 5' SOFT CMT. CIRC AND COND MUD. CBU. CLEAN SHAKERS. SIPLACE HOLE W/ FILTERED SEAWATER ADDING INHIBITOR. TEST 5 1/2" LINER AND 7" CASING. POH - LD 3 1/2" & 2 7/8" AND 3 1/8" DC'S, CASING SCRAPER AND MILL. PULL WEAR RING AND TEST PLUG. RU TO RUN 4 1/2" CHROME TBG. SETTING PACKER MW: 0.0 RUN 4 1/2" 13 CR TBG. MUKE UP OTIS SSSV AND CONTROL LINES. TEST. RUN 4 1/2" TBG. TAGGED UP @ 10604'. SPACED OUT TBG. MAKE UP TBG HANGER W/ BPV CONNECT AND TEST CONTROL LINES. CLEAR RIG FLOOR. CHANGE RAMS TO 5". ND BOPS. HOOK UP SSSV CONTROL LINES TO TBG SPOOL. TEST. RU LUBRICATOR AND PULL 2-WAY BACK PRESSURE VALVE. PRESSURE UP ON TBG TO 4000 PSI TO SET PACKER AND TEST TBG. RELEASED RIG MW: 0.0 SET PKR @ 10538' TEST TBG. TEST PKR AND 7 5/8" CSG. RD CIRC EQUIP - INSTALL BPV. CLEAN PITS. RELEASED RIG @ 1200 HRS 02/25/94. SIGNATURE: (drilling superintendent) DATE: RECEIVED Cas Cor~$. Corr~mission ~.. BAKER HUGHES INTEQ H - 31 S U RVEYS COMMENTS 0.00 - 10715.00 BP EXPLORATION (Alaska) Inc. Pad H 31 slot #31 Prudhoe Bay North Slope, Alaska S U R V E Y L I S T I N G by Baker Hughes INTEQ Your ref : PMSS <0-10715'> Our ref : svy4237 License : Date printed : 29-Mar-93 Date created : 29-Mar-93 Last revised : 29-Mar-93 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on n70 18 1.316,w148 49 44.895 Slot location is n70 17 44.330,w148 50 22.378 Slot Grid coordinates are N 5959060.625, E 643308.453 Slot local coordinates are 1727.00 S 1286.00 W Reference North is True North BP EXPLORATION (ALaska) inc. Pad H~31 Prudhoe Bay,North SLope, Alaska Measured Azimuth True Vert. R E C T A N G U L A Depth Degrees Depth C 0 0 R D I N A T E SURVEY LISTING Page 1 Your ref : PMSS <0-10715'> Last revised : 29-Mar-93 R GRID COORDS GEOGRAPH I C S Easting Northing C 0 0 R D ! N A T E S 0.00 0.00 0.00 0.00 N 0.00 E 643308.45 5959060.62 n70 17 44.33 w148 50 22.38 100.00 58.20 100.00 0.09 N 0.15 E 643308.60 5959060.72 n70 17 44.33 w148 50 22.37 197.00 25.90 197.00 0.33 N 0.37 E 643308.81 5959060.96 nTO 17 44.33 w148 50 22.37 291.00 42.80 291.00 0.54 N 0.49 E 643308.94 5959061.18 n70 17 44.34 w148 50 22.36 381.00 26.20 381.00 0.88 N 0.68 E 643309.12 5959061.52 n70 17 44.34 w148 50 22.36 473.00 51.90 473.00 1.37 N 1.08 E 643309.51 5959062.01 nTO 17 44.34 w148 50 22.35 565.00 46.60 564.99 1.78 N 1.57 E 643309.98 5959062.44 n70 17 44.35 w148 50 22.33 658.00 44.20 657.99 2.24 N 2.03 E 643310.44 5959062.90 n70 17 44.35 w148 50 22.32 750.00 46.60 749.99 2.69 N 2.48 E 643310.88 5959063.36 n70 17 44.36 w148 50 22.30 840.00 30.10 839.99 3.18 N 2.87 E 643311.26 5959063.86 n70 17 44.36 w148 50 22.29 933.00 7.60 932.98 3.70 N 3.07 E 643311.45 5959064.38 n70 17 44.37 w148 50 22.29 1026.00 289.90 1025.97 4.38 N 1.88 E 643310.24 5959065.04 n70 17 44.37 w148 50 22.32 1117.00 283.90 1116.89 5.43 N 1.78 W 643306.57 5959066.02 n70 17 44.38 w148 50 22.43 1210.00 280.80 1209.65 6.81N 8.28 W 643300.04 5959067.28 n70 17 44.40 w148 50 22.62 1304.00 279.40 1303.15 8.49 N 17.80 W 643290.50 5959068.77 nTO 17 44.41 w148 50 22.90 1395.00 273.70 1393.33 9.80 N 29.83 W 643278.44 5959069.85 n70 17 44.43 w148 50 23.25 1489.00 262.80 1485.93 9.10 N 45.90 W 643262.39 5959068.84 nTO 17 44.42 w148 50 23.72 1581.00 262.10 1575.80 6.50 N 65.40 W 643242.94 5959065.86 n70 17 44.39 w148 50 24.28 1675.00 262.80 1666.96 3.50 N 88.10 W 643220.30 5959062.43 n70 17 44.36 w148 50 24.94 1769.00 256.20 1757.04 1.55 S 114.43 W 643194.08 5959056.88 nTO 17 44.31 w148 50 25.71 1861.00 252.30 1843.62 10.05 S 144.32 W 643164.36 5959047.80 nTO 17 44.23 w148 50 26.58 1955.00 253.00 1930.74 20.56 S 178.00 W 643130.89 5959036.64 n70 17 44.13 w148 50 27.56 2048.00 251.90 2014.44 32.80 S 216.56 W 643092.57 5959023.67 nTO 17 44.01 w148 50 28.69 2140.00 251.60 2094.31 47.10 S 259.92 W 643049.51 5959008.54 n70 17 43.87 w148 50 29.95 2235.00 255.50 2174.70 61.37 S 308.46 W 643001.26 5958993.34 n70 17 43.72 w148 50 31.37 2329.00 257.60 2251.84 73.82 S 360.70 W 642949.27 5958979.88 nTO 17 43.60 w148 50 32.89 2419.00 256.90 2323.23 85.92 S 414.13 W 642896.09 5958966.76 n70 17 43.48 w148 50 34,45 2509.00 258.60 2392.53 98.09 S 470.24 W 642840.22 5958953.51 nTO 17 43.36 w148 50 36.08 2603.00 256.90 2462.88 111.34 S 531.16 W 642779.57 5958939.10 nTO 17 43.23 w148 50 37.86 2696.00 258.30 2530.22 125.10 S 593.79 W 642717.22 5958924.14 nTO 17 43.10 w148 50 39.68 2787.00 258.30 2594,17 138.22 S 657.19 W 642654.10 5958909.80 n70 17 42.97 w148 50 41.53 2879.00 259.00 2656.20 151.58 S 723.79 W 642587.77 5958895.16 nTO 17 42.84 w148 50 43.47 2971.00 259.70 2714.72 164.69 S 793.55 W 642518.28 5958880.71 n70 17 42.71 w148 50 45.50 3064.00 261.10 2772.10 176.90 S 865.71W 642446.38 5958867.12 n70 17 42.59 w148 50 47.61 3157.00 261.80 2829.36 187.79 S 938.18 W 642374.13 5958854.84 n70 17 42.48 w148 50 49.72 3250.00 262.80 2887.00 197.57 S 1010.50 W 642302.02 5958843.66 n70 17 42.38 w148 50 51.83 3342.00 262.80 2944.71 206.55 S 1081.58 W 642231.12 5958833.32 n70 17 42.30 w148 50 53.90 3436.00 263.20 3004.06 215.44 S 1153.94 W 642158.96 5958823.04 n70 17 42.21 w148 50 56.01 3520.00 262.80 3057.49 223.34 S 1218.27 W 642094.80 5958813.91 nTO 17 42.13 w148 50 57.88 3616.00 261.80 3119.07 233.20 S 1291.25 W 642022.02 5958802.64 nTO 17 42.03 w148 51 00.01 3708.00 261.40 3178.45 243.47 S 1360.77 W 641952.72 5958791.04 nTO 17 41.93 w148 51 02.04 3799.00 261.80 3237.55 253.58 S 1429.22 W 641884.48 5958779.62 nTO 17 41.83 w148 51 04.03 3892.00 261.40 3297.88 263.91S 1499.23 W 641814.69 5958767.94 nTO 17 41.73 w148 51 06.07 3984.00 263.90 3355.34 273.07 S 1570.48 W 641743.64 5958757.41 nTO 17 41.64 w148 51 08.15 4075.00 263.90 3410.36 280.77 S 1642.55 W 641671.73 5958748.33 nTO 17 41.56 w148 51 10.25 4168,00 262.80 3466.59 289.35 S 1716.13 W 641598.34 5958738.34 n70 17 41.48 w148 51 12.39 4260.00 263.20 3522.08 298.29 S 1788.96 g 641525.70 5958727.99 nTO 17 41.39 w148 51 14.52 4353.00 262.50 3578.38 307.51S 1862.41W 641452.44 5958717.37 nTO 17 41.30 w148 51 16.66 4445.00 262.50 3634.38 317.03 S 1934.77 W 641380.28 5958706.45 nTO 17 41.21 w148 51 18.77 4535.00 260.70 3688.99 327.49 S 2005.54 W 641309.73 5958694.64 nTO 17 41.10 w148 51 20.83 All data is in feet unless otherwise stated Coordinates from slot #31 and TVD from wellhead (76.00 Ft above mean sea level). Vertical section is from N 0.00 E 0.00 on azimuth 259.65 degrees. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Declination is 0.00 degrees, Convergence is 1.10 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. Pad H,31 Prudhoe Bay, North Slope, Alaska Measured Azimuth True Vert. R E C T A N G U L A Depth Degrees Depth C 0 0 R D I N A T E SURVEY LISTING Page 2 Your ref : PMSS <0-10715'> Last revised : 29-Mar-93 R GRID COORD S GEOGR S Easting Northing C 0 0 R D APHIC INATES 4627.00 259.30 3744.74 340.19 S 2077.61W 641237.92 5958680.55 nTO 17 40.98 w148 51 22.93 4721.00 259.30 3802.09 354.02 S 2150.79 W 641165.03 5958665.32 n70 17 40.84 w148 51 25.06 4813.00 258.60 3858.61 367.93 $ 2222.04 W 641094.07 5958650.04 nTO 17 40.70 w148 51 27.14 4906.00 257.90 3916.25 382.80 S 2293.50 W 641022.92 5958633.81 n70 17 40.56 w148 51 29.22 4999.00 257.90 3974.21 398.04 S 2364.61W 640952.11 5958617.20 nTO 17 40.41 w148 51 31.29 5091.00 257.90 4031.92 413.06 S 2434.67 W 640882.36 5958600.84 n70 17 40.26 w148 51 33.33 5183.00 257.90 4090.06 428.00 S 2504.38 W 640812.96 5958584.55 nTO 17 40.11 w148 51 35.37 5273.00 258.30 4147.07 442.37 S 2572.53 W 640745.10 5958568.89 nTO 17 39.97 w148 51 37.35 5366.00 258.30 4206.16 456.93 S 2642.85 W 640675.08 5958552.97 n70 17 39.83 w148 51 39.40 5458.00 257.90 4265.05 471.50 $ 2712.01W 640606.22 5958537.07 n70 17 39.68 w148 51 41.42 5550.00 259.00 4324.13 485.62 S 2781.11W 640537.41 5958521.63 nTO 17 39.54 w148 51 43.43 5643.00 258.60 4383.97 499.45 S 2850.94 W 640467.86 5958506.46 n70 17 39.41 w148 51 45.46 5738.00 259.30 4445.29 513.36 S 2922.16 W 640396.93 5958491.19 n70 17 39.27 w148 51 47.54 5830.00 260.00 4504.73 525.97 S 2991.23 ~ 640328.12 5958477.25 n70 17 39.15 w148 51 49.55 5924.00 260.00 4565.46 538.43 S 3061.89 W 640257.72 5958463.43 nTO 17 39.02 w148 51 51.61 6018.00 260.00 4626.64 550.82 S 3132.17 ~ 640187.69 5958449.69 nTO 17 38.90 w148 51 53.66 6112.00 260.00 4688.49 563.12 S 3201.88 W 640118.24 5958436.06 n70 17 38.78 w148 51 55.69 6207.00 258.60 4749.30 576.68 S 3273.58 W 640046.82 5958421.12 n70 17 38.64 w148 51 57.78 6305.00 259.70 4809.90 591.18 S 3349.22 W 639971.48 5958405.17 nTO 17 38.50 w148 51 59.99 6399.00 259.70 4868.10 604.38 S 3421.85 W 639899.12 5958390.58 n70 17 38.37 w148 52 02.10 6494.00 259.70 4927.37 617.65 S 3494.90 W 639826.35 5958375.90 n70 17 38.24 w148 52 04.23 6589.00 259.70 4987.41 630.82 $ 3567.33 W 639754.19 5958361.35 nTO 17 38.11 w148 52 06.34 6684.00 258.60 5048.22 644.55 S 3639.01W 639682.79 5958346.24 n70 17 37.98 w148 52 08.43 6778.00 257.90 5109.27 659.11S 3708.99 W 639613.11 5958330.34 nTO 17 37.83 w148 52 10.47 6872.00 257.20 5171.86 674.22 S 3777.47 W 639544.94 5958313.91 nTO 17 37.68 w148 52 12.46 6967.00 257.20 5236.89 689.56 S 3845.00 ~ 639477.73 5958297.28 nTO 17 37.53 w148 52 14.43 7060.00 256.90 5301.96 704.45 S 3909.75 W 639413.27 5958281.15 nTO 17 37.38 w148 52 16.32 7152.00 257.20 5367.58 718.90 S 3972.59 W 639350.73 5958265.49 n70 17 37.24 w148 52 18.15 7246.00 256.50 5435.93 733.58 S 4035.43 W 639288.19 5958249.61 n70 17 37.10 w148 52 19.98 7342.00 257.20 5506.99 748.27 S 4098.28 W 639225.64 5958233.71 n70 17 36.95 w148 52 21.81 7436.00 256.90 5577.93 762.08 S 4158.38 W 639165.82 5958218.74 nTO 17 36.82 w148 52 23.56 7531.00 256.90 5651.18 775.79 S 4217.29 W 639107.18 5958203.90 nTO 17 36.68 w148 52 25.28 7626.00 256.90 5725.68 789.15 S 4274.70 W 639050.05 5958189.44 nTO 17 36.55 w148 52 26.95 7719.00 257.60 5799.86 801.54 S 4329.42 W 638995.59 5958176.01 nTO 17 36.43 w148 52 28.55 7815.00 257.60 5877.91 813.54 S 4383.99 ~ 638941.25 5958162.96 nTO 17 36.31 w148 52 30.14 7908.00 258.60 5955.01 824.27 S 4434.88 W 638890.59 5958151.25 n70 17 36.20 w148 52 31.62 8002.00 260.00 6034.46 833.61S 4484.22 W 638841.44 5958140.97 nTO 17 36.11 w148 52 33.06 8097.00 260.70 6116.40 841.68 S 4531.61W 638794.22 5958131.99 nTO 17 36.03 w148 52 34.44 8193.00 260.70 6201.00 849.01S 4576.38 W 638749.60 5958123.80 nTO 17 35.96 w148 52 35.74 8286.00 260.00 6284.54 855.85 S 4616.64 W 638709.48 5958116.19 nTO 17 35.89 w148 52 36.92 8380.00 259.00 6370.45 862.79 S 4654.16 W 638672.11 5958108.53 nTO 17 35.82 w148 52 38.01 8477.00 260.70 6460.16 869.30 S 4690.46 W 638635.94 5958101.32 n70 17 35.76 w148 52 39.07 8571.00 259.30 6547.71 875.23 S 4724.16 W 638602.36 5958094.74 nTO 17 35.70 w148 52 40.05 8665.00 260.40 6635.78 881.03 $ 4756.49 W 638570.16 5958088.33 n70 17 35.64 w148 52 40.99 8760.00 260.00 6725.36 886.41S 4787.66 W 638539.10 5958082.35 nTO 17 35.59 w148 52 41.90 8855.00 260.40 6815.34 891.59 S 4817.67 W 638509.19 5958076.59 n70 17 35.54 w148 52 42.78 8949.00 259.30 6904.72 896.72 S 4846.34 W 638480.63 5958070.91 nTO 17 35.49 w148 52 43.61 9040.00 261.40 6991.92 901.10 S 4871.96 W 638455.10 5958066.04 n70 17 35.44 w148 52 44.36 9136.00 260.40 7084.63 905.04 S 4896.58 W 638430.57 5958061.63 n70 17 35.40 w148 52 45.08 9230.00 260.40 7175.72 908.91S 4919.47 W 638407.76 5958057.32 nTO 17 35.37 w148 52 45.74 All data is in feet unless otherwise stated Coordinates from slot #31 and TVD from wellhead (76.00 Ft above mean sea level). Vertical section is from N 0.00 E 0.00 on azimuth 259.65 degrees. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Declination is 0.00 degrees, Convergence is 1.10 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. Pad H,31 Prudhoe Bay,North Slope, Alaska Measured Azimuth True Vert. R E C T A N Depth Degrees Depth C 0 0 R D I SURVEY LISTING Page 3 Your ref : PMS$ <0-10715'> Last revised : 29-Mar-93 GULAR GRID COORDS GEOGRAPHIC N A T E S Easting Northing C O O R D I N A T E S 9327.00 259.30 7269.91 912.98 S 4942.24 W 638385.06 5958052.81 nTO 17 35.33 w148 52 46.41 9421.00 259.00 7361.36 917.08 S 4963.64 W 638363.75 5958048.30 nTO 17 35.28 w148 52 47.03 9515.00 257.60 7452.87 921.43 S 4984.66 W 638342.82 5958043.54 nTO 17 35.24 w148 52 47.64 9610.00 260.00 7545.40 925.61S 5005.77 W 638321.79 5958038.96 n70 17 35.20 w148 52 48.26 9705.00 259.00 7637.97 929.51S 5026.78 W 638300.86 5958034.66 n70 17 35.16 w148 52 48.87 9800.00 258.60 7730.75 933.47 S 5046.80 W 638280.93 5958030.32 nTO 17 35.12 w148 52 49.45 9894.00 256.90 7822.94 937.34 S 5064.72 W 638263.09 5958026.10 nTO 17 35.08 w148 52 49.98 9989.00 258.60 7916.32 941.05 S 5081.79 W 638246.09 5958022.06 n70 17 35.05 w148 52 50.47 10082.00 258.60 8007.70 944.46 S 5098.72 W 638229.23 5958018.32 nTO 17 35.02 w148 52 50.96 10175.00 257.90 8099.08 947.98 S 5115.62 W 638212.40 5958014.48 nTO 17 34.98 w148 52 51.46 10269.00 259.00 8191.53 951.39 S 5132.33 W 638195.77 5958010.75 nTO 17 34.95 w148 52 51.94 10364.00 259.30 8285.00 954.59 S 5149.01W 638179.15 5958007.23 nTO 17 34.92 w148 52 52.43 10460.00 258.30 8379.48 957.89 S 5165.69 W 638162.54 5958003.61 nTO 17 34.88 w148 52 52.92 10556.00 258.60 8474.02 961.23 S 5182.02 W 638146.28 5957999.96 nTO 17 34.85 w148 52 53.39 10650.00 260.40 8566.65 964.15 S 5197.75 W 638130.61 5957996.74 nTO 17 34.82 w148 52 53.85 10715.00 261.10 8630.74 965.89 S 5208.45 W 638119.95 5957994.79 nTO 17 34.80 w148 52 54.16 All data is in feet unless otherwise stated Coordinates from slot #31 and TVD from wellhead (76.00 Ft above mean sea level). Vertical section is from N 0.00 E 0.00 on azimuth 259.65 degrees. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Declination is 0.00 degrees, Convergence is 1.10 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. Pad H,31 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 4 Your ref : PMSS <0-10715'> Last revised : 29-Mar-93 Comments in wellpath MD TVD Rectangular Coords. Comment 10715.00 8630.74 965.89 S 5208.45 W LAST MWD STATION All data is in feet unless otherwise stated Coordinates from slot #31 and TVD from wellhead (76.00 Ft above mean sea level). Bottom hole distance is 5297.25 on azimuth 259.49 degrees from wellhead. Vertical section is from N 0.00 E 0.00 on azimuth 259.65 degrees. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Declination is 0.00 degrees, Convergence is 1.10 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BAKER HUGHES INTEQ H-31 EMS SURVEYS COMMENTS 10803.00 - 11330.00 BP EXPLORATION (Alaska) Inc. Pad H 31 slot #31 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : EMS <10803-11330'> Our ref : svy4238 License : Date printed : 29-Mar-93 Date created : 29-Mar-93 Last revised : 29-Mar-93 Field is centred on 708179.340,5930615.440~999.00000~N Structure is centred on n70 18 1.316~w148 49 44.895 Slot location is n70 17 44.330~w148 50 22.378 Slot Grid coordinates are N 5959060.625, E 643308.453 Slot local coordinates are 1727.00 S 1286.00 W Reference North is True North BP EXPLORATION (Alaska) Inc. Pad H,31 Prudhoe Bay,North Slope, Alaska Measured Azimuth True Vert. R E C T A N Depth Degrees Depth C 0 0 R D I SURVEY LISTING Page 1 Your ref : EMS <10803-11330'> Last revised : 29-Mar-93 GULAR GRID COORDS GEOGRAPHIC N A T E S Easting Northing C 0 0 R D I N A T E S 10803.00 262.05 8717.36 968.16 S 5223.81 10818.00 263.64 8732.07 968.52 S 5226.70 10849.00 264.13 8762.34 969.23 S 5233.33 10944.00 264.20 8855.06 971.33 S 5253.91 11037.00 265.97 8946.30 972.89 S 5271.86 11129.00 267.43 9036.92 973.81 S 5287.65 11224.00 267.37 9130.72 974.50 S 5302.72 11286.00 270.07 9192.00 974.71 S 5312.12 11294.00 271.63 9199.91 974.70 S 5313.30 11330.00 271.63 9235.53 974.55 S 5318.56 638104.63 5957992.23 638101.75 5957991.81 638095.14 5957990.98 638074.60 5957988.48 638056.69 5957986.57 n70 17 34.78 w148 52 54.61 nTO 17 34.78 w148 52 54.70 n70 17 34.77 w148 52 54.89 n70 17 34.75 w148 52 55.49 nTO 17 34.73 w148 52 56.01 638040.92 5957985.35 638025.86 5957984.37 638016.47 5957983.98 638015.29 5957983.97 638010.03 5957984.02 n70 17 34.72 w148 52 56.47 nTO 17 34.72 w148 52 56.91 nTO 17 34.72 w148 52 57.18 n70 17 34.72 w148 52 57.22 n70 17 34.72 w148 52 57.37 All data is in feet unless otherwise stated Coordinates from slot #31 and TVD from wellhead (76.00 Ft above mean sea level). Vertical section is from S 0.00 E 0.00 on azimuth 259.65 degrees. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Declination is 0.00 degrees, Convergence is 1.10 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ BP EXPLORATION (Alaska) Inc. SURVEY LISTING Page 2 Pad H,31 Your ref : EMS <10803-11330'> Prudhoe Bay,North Slope, Alaska Last revised : 29-Mar-93 Comments in wellpath MD TVD Rectangular Coords. Comment 10803.00 8717.36 968.16 S 5223.81 W FIRST EMS SURVEY 11330.00 9235.53 974.55 S 5318.56 W PROJECTED SURVEY TO TD All data is in feet unless otherwise stated Coordinates from slot #31 and TVD from wellhead (76.00 Ft above mean sea level). Bottom hole distance is 5407.11 on azimuth 259.62 degrees from wellhead. Vertical section is from S 0.00 E 0.00 on azimuth 259.65 degrees. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid DecLination is 0.00 degrees, Convergence is 1.10 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ L ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Dear Sir/Madam, Reference: BP H-31 PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Date: 15 March 1994 RE: Transmittal of Data ECC #: 6158.00 Data: OH-LDWG Prints/Films: Sent by U.S. MAIL DIFL/GR/SP FINAL BL BHC/AC/GR FINAL BL SSTVD/MWD FINAL BL DIFL/GR/SP RF SEPIA BHC/AC/GR RF SEPIA SSTVD/MWD RF SEPIA Run # 1 Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 3 March 1994 RE: Transmittal of Data ECC #: 6158.00 Data: OH-LDWG Dear Sir/Madam, Reference: oBP H-31 PRUDHOE BAY Enclosed, please find the data as described below: Tapes/Diskettes: Sent by U.S. MAIL DIF~A~6L~WG TAPE+LST Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson MEMORANDUM TO: THRU: David Johnsto ~,/~ Chairmar~.-~~ Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 21, 1994 FILE NO: QINJBUBD.DOC FROM: Lou Grimaldi,~.~- ~~ SUBJECT: Petroleum Inspector Rig/BOPE inspection Nabors 18E BPX well #H-31 PrudhoeBayField PTD #94-14 Monday, February 21, 1994: I traveled to BPX H pad to make a Rig Bope inspection on Nabors rig. # 18-E. The rig had reached T.D.'and was Standing by for a logging run. A walk through showed all BOP equipment to be in place and in apparent good condition. The area surrounding the rig was neat and provided good access. Summary: I made a Rig/BOPE inspection on Nabors rig 18-E. All equipment appeared to be in compliance. Attachment: QINJBUBD.XLS ~--. STATE OF ALASKA ~T~. ALASK/. ,L AND GAS CONSERVATION CC: ~IISSlON RIG ! BPS INSPECTION REPORT OPERATION: Drilling X Workover ~C°mpl' UIC DATE: '2-21-94 Well Name H-31 PTD# 94-14 Drig Contractor Nabors Rig# 18-E Rep. Don Dubois Operator: BPX Rep. Dave Bum~larner Rig Ph.# 659-4608 Location: Section 21 T. 11N R. R13E M. U INSPECTION ITEMS IN COMPLIANCE INSPECTION ITEMS IN COMPLIANCE (A.) B.O.P. STACK YES NO NIA (C.! MUD SYSTEM YES NO NIA 1 Wellhead fig wkg press X 29 Pit level floats installed X 2 Stack wkg press X 30 Flow rate sensor X 3 Annular preventer X 31 Mud gas separator X 4 Pipe rams X 32 Degasser X 5 Blind rams X 33 Separator bypass X 6 Stack anchored X 34 Gas sensors X 7 Chke/kill line size X 35 Choke line connections X 8 All turns targeted ( chke &'kill Ln.) X 36 Trip tank X 9 HCR valves (chke & kill Ln.) X INSPECTION ITEMS IN COMPLIANCE 10 Manual valves (chke & kill Ln.) X (D.) RIG FLOOR YES NO NIA 11 Connections (Flgd, Whd, Clamped X 37 Kelly cocks (upper, lower, IBOP) X 12 Drilling spool X 38 Floor valves (dart, ball, ect.) X 13 Flow Nipple X 39 Kelly & floor valve wrenches X 14 Flow monitor X 40 Drillers console (flow monitor, X 15 Control' lines fire protected X flow rate indicator, pit level X INSPECTION ITEMS IN COMPLIANCE :indicators, gauges) X (B.) CLOSING UNIT YES NO NIA 41 Kill sheet up-to-date X 16 Working pressure X 42 Gas detection monitors X 17 Fluid level X (H2S & methane) N/A 18 Operating pressure X 43 Hydraulic choke panel X 19 Pressure gauges X 44 Choke manifold X 20 Sufficient valves X INSPECTION ITEMS IN COMPLIANCE 21 Regulator bypass X (E.) MISC. EQUIPMENT YES NO NIA 22 4-way valves (actuators) X 45 Flare/vent line X 23 Blind rams handle cover X 46 All turns targeted X 24 Driller control panel X (downstream choke lines) X 25 Remote control panel X 47 Reserve pit tankage X 26 Firewall X 48 Personnel protective equip, avail. X 27 Nitrogen power source (backup) X 49 All Drillsite Supervisors Trained X 28 Condition (leaks, hoses, ect.) X For Procedures X 50 H2S probes X 51 Rig housekeeping REMARKS: Ri~l in good shape RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? Yes 2/18/94 Kill Sheet Current? Yes Distribution: orig - Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector AOGCC REP Louis R. Grimaldi OPERATOR REP: QINJBUBD.XLS (Rev. 12/92) ALASKA OIL AND GAS CONSERVATION COM~IISSION February 1, 1994 Terry Jordan Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 'WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 278-7542 Re .' Prudhoe Bay Unit H-31 BP Exploration (Alaska), Inc. Permit No: 94-14 Sur. Loc. 3552'NSL, 1265'WEL, Sec. 21, TllN, R13E, UM Btmhole Loc. 2577'NSL, 1315'WEL, Sec. 20, TllN, R13E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit.to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · . Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game~i'Habitat Section w/o encl. Department of Environmental Conservation w/o eno1. STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la, Type of work Drill [] Redrill ["]llb. Type of well. Exploratoryl-] Stratigraphic Test 1-1 Development Oil [] Re-Entry [] DeepenF'II Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 74.8 feet Prudhoe Bay Fie/d/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6~12 ADL 28283 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(~,, 20 ^AC 25.o25) 3552' NSL, 1265' WEL, SEC. 21, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2589' NSL, 1250' WEL, SEC. 20, T11N, R13E H-31 (33-20-11-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 2577' NSL, 1315' WEL, SEC. 20, T11N, R13E 1/26/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and mVD) propert line [~DL 28284-1315' feet H-12-33'@ 199' MD feet 2560 11340' MD/9233' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~ooo feet Maximum hole angles,.55 o Maximum surface 3330 psig At total depth (TVD) 880o'/4390 psi~ 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) .... 30" 20" 91.5# H-40 Weld 80' 30' 30' 110' 110' 260 sx Arcticset (Approx.) 13-1/2" 10-3/4" 45.5# NT8OLHE Butt 3804' 29' 29' 3833' 3200' 1285 sx PF "E"/320 sx "G"/250 sx PF "C" 9-7/8" 7-5/8" 29.7# NT95HS NSCC 8973' 28' 28' 10844' 8745' 265 sx Class 'G" 6-3/4" 5-1/2" 17# 13CR80 NSCC 650' 10694' 8597' 11340' 9233' 120 sx Class 'G" 19. To be completed for Redrill, Re-entry. and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production ~,!~ ..-.';'.,i"i 'i'" i~ Liner ., .... '..;~-, Oii & '-~0.s Cons. Perforation depth: measured true vertical ~ncho,a9... 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l'2] Drilling fluid program [] Time vs depth plot [] Refraction analysis D Seabed report[] 20 AAC 25.050 requirementsl-i 21. I hereby certify that the. foregoing is true and correct to the best of my knowledge I~ Signed ¢~/' ~ Title Drilling Engineer Supervisor Date Commission Use Only Permit Number IAPI number IApp~roval d,ate ISee cover letter ~z'_/,' ~ 150- ~__. ~- ~_ Z ~//~7" ~7/ I ':::xl"'/'"'~l'' Jfor other requirements Conditior~s of approval Samples required [] Yes ,']:D'No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes ~ No Directional survey required [] Yes [] No Required working pressure for BOPE 1-12M; 1-13M; [~5M; I-IIOM; i-115M; Other: Original Signed By by order of Approved by n~vid W. J0hnstdn Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in (riplicate I Well Name: IH-31 PBU Well Plan Summary I Type of Well (producer or injector): I Producer Surface Location: 3552' FSL 1265' FEL Sec 21 T1 IN R13E UM Target Location' 2589' FSL 1250' FEL Sec 20 T11N R13E UM Bottom Hole Location: 2577' FSL 1315' FEL Sec 20 TllN R13E UM I AFENumber: 14P0555 I I Rig: I Nabors 18-E I I Estimated Start Date: l Jan 26, 1994 I I Operating days to complete: 124 ] IMD: I 11340' I I TVD: 19233' ] [KBE: ]74.8' ] Well Design (conventional, slimhole, etc.): ] Slimhole producer I Formation Markers: Formation Tops MD TVD (BKB) Base Permafrost 2018' 1985' Ugnu Zone 4A 5185' 4115' Top Seabee (CM3) 7666' 5750' Kuparuk/Put River Absent Absent IKRU/LCU 9453' 7375' Top Sag River 10844' 8745' Top Shublik 10873' 8773' Top Sadlerochit 10956' 8855' Target 10956' 8855' Total Depth 11340' 9233' Casing/Tubin Program: Wt/Ft i 'l~ a~ Y Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80' 30'/30' 110'/110' 13 1/2" 10 3/4" 45.5# NT80LHE Butt 3804' 29'/29' 3833'/3200' 9 7/8" 7 5/8" 29.7# NT95HS NSCC 8973' 28'/28' 10844'/8745' 6 3/4" 5 1/2" 17# 13Cr-80 NSCC 650' 10694'/8597 11340'/9233' 4 1/2" 12.6 13Cr-80 NSCT 10617' 27'/27' 10644'/8548 Well Plan Summary Logging Pro Open Hole Logs: 13 1/2" Hole 9 7/8" Hole 6 3/4" Hole Cased Hole Logs: 7 5/8" Casing 5 1/2" Liner ram: None None GR/DIL/BHCS None SBT. (optional Gyro) Mud Program: I Special design considerations I None Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 100 20 15 20 9 15 to to to to to to to 9.5 300 60 60 80 10 25 Intermediate Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 35 10 5 10 9.5 5 tO tO tO tO tO tO tO 10.0 50 15 10 20 10 10 Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.8 30 8 3 7 8 6 tO tO tO tO tO tO tO 9.0 45 13 10 15 9 8 Directional'. IKOP: I1000' I Maximum Hole Angle: [ 51.55 degrees Close Approach Well' ] H-12 at 199' (33' away), H-13 at 1092' (62' away) The above listed wells will be secured during the close approach. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures.r~.~ Diverter, BOPE and drilling fluid system schematics on file with AOGC(?,,~ ,-.. - -.~-,,3~¢~" Page 2 PROPOSED DRILLING AND COMPLETION PROGRAM WELL H-31 [Sec 20-11N-13E] PBU MIRU. NU diverter and function test same. Drill 13-1/2" hole to 3833' MD BKB. Run and cement 10-3/4", 45.5#, NT-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. A formation leak-off test will be performed 10' below the 10-3/4" shoe. Directionally drill 9-7/8" hole to the 7-5/8" casing point above the top of Sag River. Run a 7-5/8", 29.7#, NT-95 NSCC casing string to within 10' of 9-7/8" TD and cement with Class G cement around the 7-5/8" shoe. The annulus will be freeze protected with dead crude oil. Directionally drill the 6-3/4" hole to TD. Run 5-1/2", 17#, 13 Cr-80 NSCC liner from TD to 150' inside 7-5/8" casing shoe and cement using Class G cement. Clean out to 5-1/2" float equipment. Change over to NaCI completion fluid. Test casing and lap to 3500 psi. Run 7-5/8" production packer on the 4-1/2", 12.6#, 13 Cr-80 NSCT tubing. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Freeze protect the tubing and annulus with Diesel from surface to 2100' TVDBKB. Set and test packer. The well will be perforated after the rig has been released. Fluids incidental to the drilling of a well will be injected down CC-2A. Tubing Size: 4-1/2", 12.6 # NT13CR-80 tubing with 5 GLM's. Well Plan Summary Page 3 -T" 10-3/4" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 10-3/4" CIRC. TEMP' 38°F SPACER: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES' retarder WEIGHT: 12.0 ppg APPROX. # SACKS' 1285 YIELD' 2.17 ft3/sx MIX WATER' 11.63 gps THICKENING TIME' Greater than 4 hrs. @ 50°F TAIL CEMENT TYPE: Premium Cement ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg APPROX. # SACKS: 320 YIELD: 1.15 ft3/sx MIX WATER: 5.0 gps THICKENING TIME' Greater than 3-1/2 hrs @ 50°F TOP JOB CEMENT TYPE' Type C Permafrost ADDITIVES' WEIGHT: 15.6 ppg APPROX. # SACKS' 250 YIELD: 0.95 ft3/sx MIX WATER: 3.7 gps CENTRALIZER PLACEMENT: 1. Run one(1 ) bow type centralizer per joint for the first 25 joints. 2. Place the centralizers in the middle of each joint with a stop collar. CEMENT VOLUME: 1. Lead slurry from TD to surface w/100% excess. 2. Tail slurry volume 320 sx (to cover 500' of casing shoe w/100% excess). 3. Top job volume 250 sx. , . . . , : · ::' -' I -',''I,I¢~L Well Plan Summary Page 4 CASING SIZE: 7-5/8" 7-5/8" INTERMEDIATE CASING CEMENT PROGRAM- HALLIBURTON CIRC. TEMP: 140°F SPACER: 50 bbls ARCO Alpha Spacer + 1% S-400, weighted 1 ppg above current mud weight. CEMENT TYPE' PREMIUM ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 0.1% HR-5 WEIGHT: 15.8 ppg APPROX. # SACKS: 265 FLUID LOSS: 100-150 cc YIELD' 1.15 ft3/sx MIX WATER' 5.0 gps THICKENING TIME' 3 1/2-4 1/2 hrs FREE WATER' 0 cc CENTRALIZER PLACEMENT: 1 Turbulator centralizer per joint on the bottom 500' of 7-5/8" casing ( 12 required ). One solid body 7-3/4" x 9-1/4" centralizer or turbolator on first 2 joints inside 10-3/4" surface casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly - batch mix is not necessary. CEMENT VOLUME: 1. Slurry to 1000' MD above casing shoe with 30% excess. 2.80' MD 7-5/8", 29.7# capacity for float joints. Note: No hydrocarbon bearing zones are identified in the Cretaceous interval. Well Plan Summary Page 5 5-1/2" PRODUCTION LINER CEMENT PROGRAM- HALLIBURTON CIRC. TEMP: 140° F BHST: 220° F at 8800' TVDSS. PREFLUSH: 20 bbls ARCO Alpha Preflush (unweighted) SPACER: 70 bbls ARCO Alpha Spacer mixed as per BJ specifications weighted 1.0 ppg above mud weight. \ CEMENT TYPE: PREMIUM ADDITIVES: 0.4% CFR-3, 1.5% Bentonite, 0.5 gps D-AIR, 1.5 gps Latex 2000, 0.25 Stabilizer 434B, 0.1% HR-5 WEIGHT: 15.7 ppg APPROX. # SACKS: 120 YIELD: 1.20 ft3/sx MIX WATER: 3.48 gps THICKENING TIME: 45 min. @ surface + 3-4 hrs @ 140°F FLUID LOSS: less than 50 cc/30 min. @ 140°F FREE WATER: 0 cc at 45° angle. Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencies ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: Run 2 right hand turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 50 cc/30 min. or less. Report actual fluid loss on morning report. Displace @ 6-8 bpm. LINER CEMENT VOLUME: . . Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 5-1/2", 17# casing capacity below landing collar (80'). 250' liner lap (6.875" x 5-1/2") 200' of cement on top of the liner in the 7-5/8" casing. Well Plan Summary Page 6 PRUDHOE BAY DR ILL I NG GROUP <KB> Narker lMent~f~ca[ion ND BKB SECTN INCLN ~) KB 0 0 0 0.00 8) KOP BUILD 2.50/]00 ~000 !000 -0 0.00 C) ENO OF 2.50 BUILD 305~ 27S5 867 51,55 D) KOP DROP ~.507100 6683 5047 3703 5~.55 E) END OF 1.50 OAOP @~53 7375 - 5089 tO.O0 FI TARGET 10956 8855 5350 10.00 H-3 ~ VERTICAL SECTION .......... 1,, ,, , Section at' 259.65 TVD Scale.' J inch = i200 feet VIEW TO ~.J340 9233 5417' JO.O0 Oep Scale ' I inch = ]800 feet. l Drawn ..... : i 2/30/93 )- ] -~E ~-~'f - '~- )_ ,, I , 6000 ' ' 7800 I i I ~, ,~ ¢,~!.- ~ ~ ]- r = = ~ - ~ ~ ~ ~ - - ~ ...... - - - - ~ ..... -~2oo -6oo o ~oo ~2oo ~8oo 2~oo 3ooo ~6oo 4200 ~aoo 5~oo 6oo0 a~oo 7200 Sect ~on Departure PRUDHOE BAY DRILLING Narker ]dent jr icalion NO N/S E/W Al KB 0 0 0 81 KOP MILO 2.5~/100 lO00 0 0 C~ ENO ¢ 2.50 BUILO 3062 156 853 O} KOP ~ ~.5~/~00 6683 865 3642 El ENO ~ 1.50 DROP 9453 914 5006 FJ TARGET 10956 961 5263 G~ TB t~340 973 5329 G'RoUP ,4nadp i ] l Schlumberger H-S! (P4) PLAN V ZE~ CLOSURE .....: 54t7 feet DECLINATION.: 29.760 E :SCALE .......: ~ inch : 700 feet DFIA~IN ....... : ~2/30/93 at Azinluth 259.65 ?'"s ,., 5950 5600 52..5',0 4900 4550 4200 3850 3500 3t50 2800 2450 2100 i750 ]400 1050 700 350 0 350 <- WEST ' EAST -> ,&nadrll] ~193 t131P4 BI.5;J 5:111 PM 1] Anadrill Schlu,~berger Alaska District 1tll East 80t}l ,Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIGNAL WELL P-r,AN for PRUDHOE BAY DRILLING GROUP :Jell ......... : H-Bi Field ........ : PRUDHOE BAY DRILLPAD H Zomputation..: MINI~3/~ CURVATURE ]nits ........ : FEET ~u ....... .~e Lat~.: "-70.2956'4691 N ~u~-~ce Long,: 148.8393t769 W Legal Description 3ttrface ...... : 3552 FSL 1265 FEL Farget ....... : 2589 FSL 1250 FEL ~}{L .......... : 2577 FSL 1315 FEL LOCAT5ONS - ALAS~{ Zone: 4 X-Coord Y-Coord S21 TllN R13E UI,'I 64333~,36 5959060.99 S20 TllN R13E ~4 638090.00 5958000.00 S20 TllN R13E ~ 638024.72 5957986.79 PROPOSED WELL PROFILE Prepared ..... : 12/30/93 Section at...: 259.65 KB elevation.: 74.78 f~ Magnetic Dcln: 29_760 E Scale'Factor.: '0.99992334 Convergence..: +1.09270726 STATION MEAS rNCLN IDENTIFICATION DEPTH ANGLE (B (OP BUILD 2. 50/100 {ASE PE~,~XFROST 0 0.00 1000 0.00 1100 2.50 1200 5.00 1300 7.50 1400 10.00 1500 12.50 1600 15.00 1700 17.50 1800 20.00 1900 22.50 2000 25.00 2018 25.45 2100 27.50 2200 30.00 DIRECTION VERT-DEPTI-IS SECT AZIMUTH BKB SUB-S DIST 0.00 0 -75 0 259.65 1000 925 -0 259.65 1100 1025 2 259.65 1200 1125 9 25~.65 1299 i224 20 259.65 1398 1323 35 259.65 1496 1~21 54 259.65-- 1593 1518 78 259.65 1689 1614 106 259.65 1784 1709 138 259.65 1877 1002 174 259.65 1969 1894 215 259.65 1985 1910 222 259.65 2058 1983 259 259.65 2146 2071 307 RELATIVE-COORDINAT£S FRO~0!- THE - WELLHEAD 0.00 N 0.00 E 0.00 N 0.00 E 0.39 S 2.15 W 1.57 S 8.58 W 3.52 S 19.29 N 6.25 S 34.25 W 9.76 S 53.i4 W 14.03 S 76.82 W 19.05 S 504.35 W 24.82 S 135.97 W 31.33 S 171.62 W 38.57 S 211.24 W 39.94 S 218.75 W 46.51 S 254.74 N 55.15 S 302.05 N STATE - PL~ANE TOOL DL/ X Y FACE 100 643333.36 5959060.99 0.00 643333.36 5959060.99 HS 0.00 643331.22 5959060.56 lIS 2.50 643324.81 5959059.26 }IS 2.50 ..~ 643314.1~ 5959057.10 I{S 2.50 ........ 643299.24 5959054.09 I{S 2.50 643280.12 5959050.22 HS 2.50 643256.82 5959045.50 HS 2.50 643229.40 5950039.95 HS 2.50 643].97.90 5959033.58 ~S 2.50 643162.38 5959026.39 t{S 2.50 643122.91 5959018.41 HS 2.50 643115.43 5959016.89 HS 2.50 6,13079.57 5959009.64 }IS 2.50 643032.44 5959000.10 HS 2.50 {-31 (P,~) 12/30/93 Pa~{e 2 S TAT I ON I DENT I F I CkT ION ~ND OF 2.50 BUILD JG}KI ZONE 4A ~op DROP 1.50/100 IY)P SEABEE 1,tEAS DEPTH 2300 2400 2500 2600 2700 2800 2900 3000 3062 5185 6683 gT00 6800 6900 7000 7100 7200 7300 7400 7500 7600 7666 7700 7800 7900 8000 8100 820O 8300 8400 8500 INCLN ANGLE 32.50 35.00 37.50 40,00 ~2.50 45,00 47,50 50.00 51.55 51.55 51.55 51.30 49.80 48.30 46.80 45.30 43.80 ~2.30 40.80 39.30 37.80 36.80 36.30 34.80 33.30 31.80 30.30 28.80 27.30 25.80 24 EIRECTION AZIMUTH 259.65 259.65 259.65 259.65 259.65 PROPOSED WELL PROFILE VERT-DEPTI'IS SECT BKB SUB-S DIST 2231 2157 359 2315 2240 414 2395 2320 474 2473 2398 536 2548 2474 602 259.65 2621 2546 '671 259 , 65 2690 2615 743 259.65 2756 2681 819 259.65 2795 2720 867 259.65 4115 4040 2529 259.65 5047 4972 3703 259.65 S057 4982 3716 259.65 5121 5046 3793 259.65 5186 5111 3868 259.65 5254 5179 3942 259 ~65 5323 5248 4014 259.65 5394 5320 4084 259.65 5467 5'393 41'53 259.65 5542 5468 4219 259.65 5619 5544 4283 259.65 5697 5622 4346 259.65 5750 56~5 ~386 259.65 5777 5702 4406 259.65 5858 5783 4464 259.65 5941 S866 4520 259.65 6025 5951 4574 259.65 6111 6036 4625 259.65 6198 6123 ~675 259.65 6286 6212 4722 259.~5 6376 6301 4766 259.65 6466 6392 4809 RELATIVE - COORDINATES FROM- THE - WELLHEAD 64.46 S 353.08 lq 74.44 S 407.73 W 85.06 S 465.90 W 96.30 S 527.47 W 108.14 S 592.33 W STATE-PI~a24E TOOL X Y FACE 642981.60 5958989.81 HS 642927.15 5958978.79 ~.IS 642869.20 5958967.07 HS 642807.86 5958954.66 HS 642~43.25 5958941.58 HS 120.56 S 660.35 W 642675.48 5958927.87 133.53 S 731.40 I'1 642604.69 5958913.54 147.04 S 805.36 W 642531.01 5958898.64 155,66 S 852.59 W 642483.96 5958889.12 454,22 S 2487.89 ~I 6,10854.77 5958559.45 665.00 S 3642.44 667.36 S 3655.33 681.23 S 3731.29 694.79 S 3805.59 708.04 S 3878.17 720.97 S 3948.99 733.57 S 4018.00 745.83 S '4085.15 757.74 S 4150.39 769.30 S 4213,68 780.49 S 4274.99 787.70 S 4314.50 791.31 S 4334.25 801.75 S 4391.44 ~11.81 S 4446.52 821.47 S 4499.44 830.73 S 4550.18 839.59 S 4598.69 848.03 S 4644.95 856.06 S 4688.91 863.66 S 4730.56 HS HS HS 639?04.55 5958326.70 LS 639691.70 5958324.10 LS 639616.03 5958308.79 LS 639542.01 5958293.81 LS '639469.70 5958279.18 LS 639399.14 5958264.90 LS 639330.39 5958250.99 LS 639263.50 5958237.46 LS 639198.49 5958224.30 LS 639135.44 5958211.54 LS 639074.36 5958199.19 LS 639034.99 5958191.22 LS 639015,32 5958187.24 LS 638958.34 5958175.71 LS 638903.47 5958164.61 LS 638850.75 5958153.94 LS 638800.20 5958143.71 LS 638751.87 5958133.93 LS 638705.79 5958124.60 LS 638661.99 5958115.74 LS 638620.49 5958107.35 LS lO0 2.50 2.50 2.50 2.50 2,50 2.50 2.50 2.50 2.50 0.00 0.00 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.50 1.S0 1.50 1.50 i-I- 31 (P4) 12/30/93 Page 3 STAT I ON I DENTI F I CAT/ON END OF 1.50 DROP rKRU/r.CU FOP SAG RIVER ['OP SHUBLIK FARGET t's~m / z,~ ~.Ol.I E 3 r~OI4E 2C CD 50~'-~ 1 B ~OTTOI.I SADLEROCII I~T I~ROPOSED WELL PROFILE IqEAS INC12>I DIRECTION VERT-DEPTHS ~.ECT RELATIVE-COORDINATES DEPq~t ANGLE AZIMUTH BKB SUB-S DIST 8600 22.80 ' 259,65 6558 6483 4849 8700 21.30 259.65 6651 6576 4886 8800 19.80 259.65 6744 6670 4921 8900 18.30 259.65 6839 6764 4954 9000 16.80 259.65 6934 6859 4984 STATE - PL~'~E TOOL DL/ FROD,I- TIlE - WEb~-IEAD X Y FACE 100 ~70,84 S ~769 86 ¥1 6385U1,34 5958099.42 LS 1.50 877.58 S 4806.79 W 6385~4.55 5958091.98 LS 1.50 883,88 $ 4841.32 W 638510.15 5958085.02 LS 1.50 889.75 S 4873.42 W 638478.17 5958078.55 LS 1.50 895,].6 S 4903.08 W 638448,62 5958072.57 LS 1.50 9100 15.30 9200 13.80 9300 12.30 9400 10.80 9453 10,00 259.65 7030 6956 50~2 259.65 7~27 7052 5037 259,65 7224 7150 5059 259.65 7322 72,18 5079 259.65 7375 7300 50~9 900.13 S 4930.27 W 638421.53 5958067.08 L$ 1.50 904.64 S 4954.98 Iq 638396,9L 5958062.10 LS 1.50 908.69 S 4977.19 W 638374.79 5958057.63 LS 1.50 912.29 S 4996.88 W 638355.17 5958053.66 LS 1.50 914.01 S 5006.33 W 638345.76 5958051.75 1.50 9453 10.00 10844 10.00 10873 10.00 10956 10.00 10956 10.00 259.65 7375 7300 5089 259.65 8745 J~ 5331 259.65 8773 8698 5336 259.65 8855 8780 5350 ~59.65 8855 8780 5350 914.01 S 5006.33 W 638245.76 5958051.75 957.40 S 52%3.97 W 638109.01 5958003.85 958.28 S 5248.82 W 638304.17 5958002.87 960,88 S 5263.05 W 638090.00 5958000.00 960.88 S 5263.05 W 638090.00 5958000.00 1.50 0.00 0.00 0.00 0.00 11147 10,00 11190 10.00 '11218 10.00 11340 10.00 259.65 9043 8968 5383 259.65 9085 9010 5391 259.65 9113 9038 5396 259,65 9233 9158 5417 9348 9273 966,83 S 5295.66 W 638057.51 5957993.43 968.16 S 5302.94 W 63~050.25 5957991.96 969.05 S 5307.80 W 638045.41 5957990.98 972.84 S 5328.57 W 638024.7~ 5957986.79 0.00 0.00 0.00 0.00 9421 9346 I'TEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE F 2 thru 8_] ' ' . 2. 3. 4. 5. 6 8. (3) Admi~ ,~__ ///~//~/ 9. [9,~ru i3]~ '1' 10. [14 thru 2 15. (5) BOPE [23 thru 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Coenpany ~/~7~ YES Is permit fee attached ............................................... ~__ ... Is well 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 undo. dicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ...... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... ' /~ . Is administrative approval needed .................................... Is 1 ease nLrnber appropriate .......................................... L Does well have a unique name & nLrnber ................................ Is conductor string provided ......................................... O~- · . 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 $ intemediate 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 d iverter system required ........................................ ~.~ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~5-~-~ ps ig ..... --~ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas .probable ...................................... NO REMARKS (6) Other ~,~/~ ~_~/ 29. [29 thru 31] 30. 31. (7) C°ntact/~-/~32~/~'/~-~Y 32. (8) Addl 33. 9eo 1 ogy' DWJ ~ RPC..~ TAB eng i nee r i n9: _ _. ]) rev 6/93 jo/6.011 FOR EXPLORATORY $ STP~ATiGRAPHIC 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 end phone nLrnber of contact to supply weekly progress data ...... / .,// Additional requirements ............................................. Additional remarks' INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE UM ~ MERIDIAN: SM WELL TYPE:. I j__ Red r i 1 1 Rev 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. ~ ' ~' PRUDHOE BAY Run 1' 21 - February - 1994 DIFL/AG/OFt 10114 {1316 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 lST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6158.00 R. ECK D. BOYER REMARKS: H - 31 500292244400 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 01-MAR-94 RUN 2 RUN 3 21 liN 13E OPEN HOLE 3552 1265 76.10 74.60 45.50 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.625 10778.0 6.750 11330.0 DIFL/AC/GR. CIRCULATION STOPPED AT 14: 00, 21-FEB-94. PER CLIENTS REQUEST, BOREHOLE & TORNADO CHART COR- RECTIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE ~SIZE (6.75"). THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET AN "RT" CURVE & "DI" CURVE (depth of invasion). FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; cased hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DIL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 10772.0 11269.0 10772.0 11287.0 10772.0 11316.0 GR (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH all runs merged; no BASELINE DEPTH LL8 ILM DT SP 10772.0 10772.0 10772.0 10772.0 10772.0 10776.5 10776.5 10797.0 10797.0 10797.5 10797.5 10797.0 10804.5 10804.5 10803.5 10804.5 10852.5 10852.5 10868.0 10867.5 10867.0 10868.0 10870.5 10869.0 10883.5 10883.0 10891.5 10890.5 10891.0 10894.0 10893.5 10893.0 10893.5 10894.5 10895.0 10897.5 10897.5 10897.5 10897.0 10901.5 10902.0 10903.5 10903.5 10903.0 10907.0 10907.0 10907.0 10907.5 10912.5 10912.0 10915.5 10915.5 10915.5 10918.5 10918.0 10918.0 10919.0 10919.0 10923.0 10922.0 10926.5 10926.5 10929.0 10928.5 10928.5 10929.5 10929.0 10932.5 10933.0 10932.5 10937.5 10937.0 10942.0 10942.5 10942.0 10942.0 10949.0 10948.5 10949.5 10955.5 10955.0 10956.5 10967.5 10968.0 10968.0 10968.0 10968.0 10971.0 10971.0 10971.0 10974.0 10974.0 10978.5 10978.5 10980.0 10981.0 10984.0 10983.0 10983.0 10985.5 10985.5 10987.0 10987.0 10987.0 10989.5 10989.5 10990.0 10990.0 10990.5 10991.5 10996.0 11009.0 11024.0 11029.5 11030.5 11036.5 11061.5 11067.5 11068.5 11085.5 11086.0 11088.0 11093.5 11094.0 11096.0 11110.5 11112.5 11113.0 11116.5 11119.0 11130.0 11133.0 11133.5 11144.0 11147.0 11168.5 11170.5 11182.0 11185.0 11191.0 11193.5 11195.5 11203.0 11203.5 11208.0 11233.0 11234.0 11254.0 11278.5 11337.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS DIL $ REMARKS: 10995.5 10995.5 10995.5 11009.0 11023.5 11023.5 11023.5 11029.0 11029.0 11029.0 11030.5 11036.0 11036.0 11036.5 11062.0 11061.5 11067.0 11068.5 11085.5 11085.5 11085.0 11085.5 11088.0 11093.5 11093.5 11093.0 11093.5 11095.5 11095.5 11110.0 11110.5 11112.0 11112.5 11116.0 11116.0 11117.5 11130.0 11132.5 11133.5 11144.0 11146.5 11146.5 11146.0 11167.5 11170.0 11181.5 11184.5 11190.5 11193.5 11195.0 11202.0 11203.5 11207.5 11232.5 11234.0 11254.0 11277.0 11337.0 11337.0 11337.0 11337.0 RUN NO. PASS NO. MERGE TOP 1 7 10772.0 1 7 10772.0 1 7 10772.0 OPEN HOLE MAIN PASS. MTEM, TEND, & TENS WERE SHIFTED WITH LLS. ILD, RT, & DI WERE SHIFTED WITH ILM. DI = DEPTH OF INVASION. RT = TRUE FORMATION RESISTIVITY. MERGE BASE 11269.0 11287.0 11316.0 / ? ?MATCH1. OUT / ? ?MATCH2. OUT / ? ?MATCH3 . OUT / ? ?MATCH4. OUT $ CN : BP EXPLORATION WN : H - 31 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units 1 GR BCS 68 1 GAPI 2 DT BCS 68 1 US/F 3 TEND BCS 68 1 LB 4 TENS BCS 68 1 LB 5 LL8 DIL 68 1 OHMM 6 ILM DIL 68 1 OHMM 7 ILD DIL 68 1 OHMM 8 SP DIL 68 1 MV 9 RT DIL 68 1 OHMM 10 DI DIL 68 1 IN 11 MTEM DIL 68 1 DEGF API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 67 465 06 6 4 4 84 653 71 5 4 4 20 789 90 0 4 4 20 789 90 0 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 44 * DATA RECORD (TYPE# 0) Total Data Records: 54 1014 BYTES * Tape File Start Depth = 11337.000000 Tape File End Depth = 10772.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13573 datums Tape Subfile: 2 229 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: 8 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH $ BASELINE CURVE FOR SHIFTS: 0.5000 START DEPTH 10114.0 STOP DEPTH 10772.0 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE MAIN PASS. CN : BP EXPLORATION WN : H - 31 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : 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: 22 1014 BYTES * Tape File Start Depth = 10772.000000 Tape File End Depth = 10093.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5437 datums Tape Subfile: 3 49 records... Minimum record length: 62 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 7 0.2500 VENDOR TOOL CODE START DEPTH GR 10701.0 AC 10720.0 DIFL 10746.0 $ 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 11280.0 10298.0 11327.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY BHC ACOUSTILOG DUAL INDUCTION 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: 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: 21-FEB-94 FSYS REV. J001 VER. 1.1 1400 21-FEB-94 2127 21-FEB-94 11330.0 11319.0 10114.0 11316.0 1800.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 1609EA/1603MA 1503XA 6.750 10778.0 10772.0 LSND 9.00 42.0 9.8 6.0 190.0 2. 170 0.820 2.810 72.0 190.0 50.0 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: OPEN HOLE MAIN PASS. $ CN : BP EXPLORATION WN : H - 31 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.000 0.0 1.740 69.0 0.000 0.0 0.00 0.000 1.5 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 ACQ AC 68 1 4 TlR1 AC 68 1 US 5 TlR2 AC 68 1 US 6 T2R1 AC 68 1 US 7 T2R2 AC 68 1 US 8 CHT AC 68 1 LB 9 TTEN AC 68 1 LB 10 SPD AC 68 1 F/MN 11 RFOC DIFL 68 1 OHMM 12 RILM DIFL 68 1 OHMM 13 RILD DIFL 68 1 OHMM 14 SP DIFL 68 1 MV 15 CILD DIFL 68 1 MMHO 16 VILD DIFL 68 1 MV 17 VILM DIFL 68 1 MV 18 RT DIFL 68 1 OHMM 19 DI DIFL 68 1 IN 20 TEMP DIFL 68 1 DEGF 4 4 06 969 49 6 4 4 48 852 89 1 4 4 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 53 419 67 0 4 4 34 704 23 6 4 4 04 522 10 6 4 4 04 522 10 6 4 4 04 903 06 0 4 4 39 256 18 6 4 4 40 467 34 0 80 * DATA RECORD (TYPE# 0) Total Data Records: 219 1014 BYTES * Tape File Start Depth = 11337.000000 Tape File End Depth = 10681.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS rePresentation code decoding summary: Rep Code: 68 68699 datums Tape Subfile: 4 296 records... Minimum record length: 44 bytes Maximum record length: 1014 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: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10714.0 10732.0 10758.0 AC DIFL $ 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 MIS TEMP PCM GR AC DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY BHC ACOUSTILOG DUAL INDUCTION 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: 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: STOP DEPTH 11282.0 11300.0 11329.0 21-FEB-94 FSYS REV. J001 VER. 1.1 1400 21-FEB-94 2053 21-FEB-94 11330.0 11319.0 10114.0 11316.0 1800.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 1609EA/1603MA 1503XA 6.750 10778.0 10772.0 LSND 9.00 42.0 9.8 6.0 190.0 2. 170 0.820 2.810 0.000 1.740 72.0 190.0 50.0 0.0 69.0 MUD CAKE AT BHT: 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN : BP EXPLORATION WN : H - 31 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.00 0.000 1.5 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 ACQ AC 68 1 4 TlR1 AC 68 1 US 5 TlR2 AC 68 1 US 6 T2R1 AC 68 1 US 7 T2R2 AC 68 1 US 8 CHT AC 68 1 LB 9 TTEN AC 68 1 LB 10 SPD AC 68 1 F/MN 11 RFOC DIFL 68 1 OHMM 12 RILM DIFL 68 1 OHMM 13 RILD DIFL 68 1 OHMM 14 SP DIFL 68 1 MV 15 CILD DIFL 68 1 MMHO 16 VILD DIFL 68 1 MV 17 VILM DIFL 68 1 MV 18 RT DIFL 68 1 OHMM 19 DI DIFL 68 1 IN 20 TEMP DIFL 68 1 DEGF 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 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 81 285 47 0 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 53 419 67 0 4 4 34 704 23 6 4 4 04 522 10 6 4 4 04 522 10 6 4 4 04 903 06 0 4 4 39 256 18 6 4 4 40 467 34 0 80 * DATA RECORD (TYPE# 0) Total Data Records: 217 1014 BYTES * Tape File Start Depth = 11339.000000 Tape File End Depth = 10691.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 59891 datums Tape Subfile: 5 292 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 8 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10013.5 $ 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 MIS TEMP PCM GR AC DIFL $ STOP DEPTH 10796.0 CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY BHC ACOUSTILOG DUAL INDUCTION 21-FEB-94 FSYS REV. J001 VER. 1.1 1400 21-FEB-94 2154 21-FEB-94 11330.0 11319.0 10114.0 11316.0 1800.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 1609EA/1603MA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 6.750 10778.0 10772.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 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: LSND 9.00 42.0 9.8 6.0 190.0 2.170 0.820 2.810 0.000 1.740 0.000 72.0 190.0 50.0 0.0 69.0 0.0 NEUTRON TOOL ~OL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: CASED HOLE MAIN PASS. $ CN : BP EXPLORATION WN : H - 31 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.00 0.000 1.5 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CHT GR 68 3 TTEN GR 68 4 SPD GR 68 1 GAPI 4 1 LB 4 1 LB 4 1 F/MN 4 4 21 990 60 6 4 10 579 41 1 4 10 579 41 1 4 76 115 41 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 61 Tape File Start Depth = 10853.000000 Tape File End Depth = 10093.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 83905 datums Tape Subfile: 6 130 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 7 is type: LIS 94/ 3/ 1 01 **** REEL TRAILER **** 94/ 3/ 3 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 3 MAR 94 9:02a Elapsed execution time = 25.87 seconds. SYSTEM RETURN CODE = 0