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Home My WebLink About181-142CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPB-02 (PTD# 1811420) - Shut in for 4 year AOGCC MIT-IA Date:Monday, April 28, 2025 4:29:23 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Monday, April 28, 2025 1:30 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPB-02 (PTD# 1811420) - Shut in for 4 year AOGCC MIT-IA Mr. Wallace – PWI well MPB-02 (PTD# 1811420) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA due this month. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg '�7o' q s' K(zg� P.L Supervisor -"� FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, April l6, 2021 SUBJECT: Mechanical Integrity Tests Micmp Alaska, LLC B-02 MILNE PT UNIT B-02 See: Inspector Reviewed By: PJ. Sup" SE— Comm Well Name MILNF PT UNIT B-02 API Well Number 50-029-20662-00-00 Inspector Name: Guy Cook Permit Number: 181-142-0 Inspection Date: 4n2021 ' Insp Num: mitGDC210407100242 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well B-02 Type Inj w TVD 4239 - Tubing 861 s6z E17- s6zPTD lanazo Type Test srr Test psi 1500 - IA 109 2026 - 1930 BBL Pumped: 2.1 'BBL Returned: 2.1 OA o 0 0 0 Interval I4YPTST PJF P Notes: Testing was done with a Little Red Services pump truck and calibrated gauges. Friday, April 16, 2021 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,April 05,2017 TO: Jim Regg Supervisor SUBJECT: Mechanical Integrity Tests P.I.P M1`` HILCORP ALASKA LLC F \ �\---1 B-02 ROM: Chuck Scheve MILNE PT UNIT B-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry M NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT B-02 API Well Number 50-029-20662-00-00 Inspector Name: Chuck Scheve Permit Number: 181-142-0 Inspection Date: 4/4/2017 Insp Num: mitCS170404144032 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well B-02 Type Inj W TVD 4239 Tubing 907 907 895 868 PTD 1811420 Type Test SPT Test psi 1500 IA 807 1960 1912 1904 - BBL Pumped: 1.5 BBL Returned: 1 6 OA 65 143i 142 149 Interval 4YRTST P/F P Notes: SCANNED AUG 1 5 201? Wednesday,April 05,2017 Page 1 of 1 MEMORANDUM ,state of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re DATE: Wednesday,April 17,2013 gg iS&fi 4(A, l 3 P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC B-02 FROM: Jeff Jones MILNE PT UNIT SB B-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry aop NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB B-02 API Well Number 50-029-20662-00-00 Inspector Name: Jeff Jones Permit Number: 181-142-0 Inspection Date: 4/4/2013 Insp Num: mitJJ130416134827 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min :Test psi! 4239 0 2050 1975 1960 r PTD Type Test 0 ]81 1420 i SPT B-02 � W IA ' P I soo �' OA 0 30 40 40 Interval P/F Tubing 1000 1 1000 1000 1000 4YRTST P Notes: 3.1 BBLS diesel pumped. 1 well inspected;no exceptions noted EKED MAR 1 3 2014 Wednesday,April 17,2013 Page 1 of 1 • MEMORANDUM To: Jim Regg ~~~, ~I/b~D~ P.I, Supervisor NRO~I: }3ob Noble Petroleum Inspector C~ State of Alaska Alaska Oil and Gas ('onsen~ation Commission llATE: Wednesday, April 15. 2009 S[?BJE("T: Me..hanical Integrity T~~is BP F~?1.ORA'TIUN (Ai..rASkr\) INC 8-02 MILNE P"C UNIT SB B-U2 Src: Inspector Well Name: MILNE PT UNIT SB I3-(12 Ingp rJ~. mitRCN090414163102 Ret Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20662-00-00 Permit Number: 1x1-t42-v Reviewed By: P.I. Sluprv J 2- Comm Inspector Name: I3ob Noble Inspection Date: 4~14i2009 Packer Depth Pretest Initial 15 Mm. 30 Min. X15 Min.,- _60 Min. Well ~~ a °~ ~Tvpe Ind. ~i~'~TVD ~ ~ ,s T s„ + ise,o ~ i~ a -_ __ ~ _ , - o P.T. ~ Iana~o ~TvpeTest I SI ~ 1 Test pst +RO" ~ } Sn ~ so i ( +_- __-- -- 4YRTST P ~ TUbingl 1tA$1 1(i(x1 ~ I~XA1 __f IzwU ~ -___,-~ Notes: Paga 1 of l Wednesday, April 15, 2009 ) STATE OF ALASKA) F?S ALASKA OIL AND GAS CONSERVATION COMMISSION CI2I1,¡þ REPORT OF SUNDRY WELL OPERATI0/zJS 4UG 0 4 20D~D IIk3 Oil ~ - A G~~ CPROFILE Time E~~~~ ~n¿'I¥.~8Ù). ~ 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D Repair WellO PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D Stimulate D WaiverD 2. Operator Name: 3. Address: 4. Current Well Class: Development D ExploratoryD BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicD ServiceŒ) 9. Well Name and Number: MPB-02 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 46.00 8. Property Designation: ADL-047438 11. Present Well Condition Summary: Total Depth measured 4700 feet true vertical 4699.5 feet Effective Depth measured 4400 feet true vertical 4399.6 feet Plugs (measured) Junk (measured) Casing CONDUCTOR SURFACE PRODUCTION Length 103 2213 4680 MD 22 125 21 - 2234 20 - 4700 TVD 22.0 125.0 21.0 - 2233.9 20.0 - 4699.5 Size 20" 94# H-40 13-3/8 72# L-80 9-5/8" 47# L-80 Perforation depth: Re-enter Suspended Well D 5. Permit to Drill Number: 181-1420 6. API Number 50-029-20662-00-00 1.75" CIBP SET @ 4390' (07/16/2005) None Burst Collapse 520 2670 4760 1530 5380 6870 Measured depth: Perfs Behind TBG @ 4371 - 4401; Perfs in Tubing @ 4345 - 4347. True vertical depth: Perfs Behind TBG @ 4371 - 4401; Perfs in Tubing @ 4345 - 4347. SC¡j~,NNEO AUG 0 9 2005 TubinQ ( size, qrade, and measured depth): 2-7/8" 6.5# L-80 2-3/8" 4.7# L-80 2-7/8" 6.5# L-80 @ 18 @ 4239 @ 4256 4239 4256 4426 Packers & SSSV (type & measured depth): 2-7/8 HES AHC Packer @. 4239 2-7/8" Baker SC-1 Packers @ 4264 & 4408 9-5/8 Lynes EXT CSG Packers @ 4091 & 4346 9-5/8 Lynes EXT CSG Packers @ 4503 & 4553 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS BFL AUG 0 8 2005 Prior to well operation: Subsequent to operation: Representative Dailv Averaqe Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure WELL SHUT-IN WELL SHUT-IN STILL AS OF AUGUST 04, 2005 Tubing Pressure WAG D GINJD WINJŒ) WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: N/A 13 14. Attachments: 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD Copies of Logs and Surveys run_ Daily Report of Well Operations_ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr Signature A4k/~J,.~ Title Petroleum Engineer Phone 564-5174 Form 10-404 Revised 4/2004 ¡ c( \... :! \ L\ L l ~ ' DevelopmentD Service ŒI Date 8/4/05 ) ) M PB-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY PROFILE MODIFICATION --- CONVERT MPB-02 INJECTION FROM AN OA-SAND INJECTOR TO AN NC/ND-SAND INJECTOR TO SUPPORT MPE-31 (BEREN) - OA- SAND INJECTION NOT REQUIRED SINCE NO SUPPORT HAS BEEN OBSERVED IN MPE-30A. 07/16/05 SET 1.75" WEATHERFORD CIBP AT 43901 MD. PRESSURED TUBING UP TO 1000 PSI OVER SHUT IN PRESSURE. SHOT TUBING PUNCH FROM 4345' - 4347'. TUBING PRESSURE DROPPED TO 200 PSI. WELL LEFT SHUT IN. TURNED OVER TO DSO. JOB COMPLETE. FLUIDS PUMPED BBLS o NO FLUIDS PUMPED o TOTAL Page 1 Tree: 2-9/16" - 5M ') Wellhead: FMC 11" 5M w/ 11' x 2/78" EUE Tbg Hgr. 2.5" "H" BPV profile Actuator: I' 20" 94 ppf H-40 Btrs. 103 I~ Max Hole Angle 1.8& @ 4100' 13 3/8" 72 ppf, L-80, BTC l2234' md ... 9 5/8" Lynes External Casing Packers at 4091' -4100' 4346' - 4355',4503' - 4512',4553' - 4562' Perforation Summary: Ref. Log: DLL / SFL 12/29/81 Squeezed Perfs Size JSPF Interval (TVD) 4.0" 12 4372'-4402' same 4.0" 12 4464'-4490' same 4.0" 12 4518'-4542' same EHD = 0.7" HyperJet 11,90 deg. phasing Open Perfs Size JSPF Interval (TVD) NC/D 4.5" 12 4371 '-4401' same OA 4.5" 12 4464'-4490' same 08 4.5" 12 4518'-4542' same Jumbo Jet ("big hole") 26 gr. charges, 135 I 45 0 phasing, EHD = 0.74, TTP = 5.8" 5.5" x 33.7' 0.12 Ga. 304 SS -I 4372' Bakerweld screen, min. ID = 4.892" 5.5" X 84.5' 0.12 Ga. 304 SS -I 4461' 1 Bakerweld screen, min. ID = 4.892" Note: Screens perforated from 4464' - 4490' Two Milled out Halliburton 9 5/8" EZSVs retainers @ 4573' and 4790' DATE 10/16/95 10/22/01 7/16/05 [ REV. BY JBF GMH MPB-02 - - r 1···- ~~YH)~ ¿J ESP Completion by N-4ES Convert to Injector by N-4ES Set CIBP & Punch Holes Lee Hulme kB = 46.0' (Parker 128) GL = 24.0' ... Min 10 above the 'AHC' Pkr == 2.313 Min 10 below the 'AHC' Pkr::: 1.750 HES 'X' Nipple (2.313 10) 1 4172' ~ 2 7/8" 6.5 # L-80 EU 8rd Tubing (cap. = .0058 bpf, ID = 2.441) 95/8" 47 # L-80 BTC Casing (Cap. = .0732 bpf, ID = 4.75) (Cap. with 2 7/8" tbg inside = .0652 bpf) Camco 27/8" x 1" KBMM GLM 14172' 9 5/8" HES 'AHC' Packer HES 'XN' Nipple (2.313 Pkg X 2.205 no-go ID) 1 4239' I 4253' -(2)"72 ]/8""!<23/8"x";óvers (1.995ID) 1 I I 4256' I 12 7/8" 6.4 # L-80 STL Tubing 1 9 5/8" Baker "SC-1" Pkr wI - I 4264' I Mdl. EBH - 22 anchor seal& WLEG 14345 - 47'1 - I 4390' I I 4408' I 4426' I - 95/8" Baker Mdl N-1 bridge plug l- PBTD . - 9 5/8" Csg. Shoe 4546' 4603' 4700' MILNE POINT UNIT Well MPB-02 API NO: 50-029-20662 BP EXPLORATION (AK: MEMORANDUM ) Alaska Oil and Gas Conservation CommL ) State of Alaska TO: JilnRegg \:' I· P.I. Supervisor . ~"h S 1'3/0S- DATE: Wednesday, May 04, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC B-02 MILNE PT UNIT SB B-02 i\./Y \~V \ "í FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ;Jß,L Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT SB B-02 Insp Num: mitCS050429084921 Rei Insp Num: API Well Number: 50-029-20662-00-00 Permit Number: 181-142-0 Inspector Name: Chuck Scheve Inspection Date: 4/28/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well B-02 Type Inj. I P I TVD 4238 IA 0 2010 1950 1930 P.T. 1811420 TypeTest I SPT Test psi 1059.5 OA 0 0 0 0 Interval 4YRTST P/F P Tubing 200 200 200 200 Notes: sr;Ai~h1ED MAY 3 1 2005 Wednesday, May 04, 2005 Page 1 of 1 _ BP EXPLORATION (AK~ MIINF, POINT UNIT Well R - 02 API NO: 50-029-20662 4603' 4700' 4546' WI~ 4408' 4421' 4461' 4372' 4264' 4253' 4239' ESP Completion by N 4ES RWO Nabors 4ES - Convert to Injector 10/16/95 10/22/01 PBTD 95/8" Csg. Shoe ~= 9 5/8" Baker "New 5C-1" Pkr w/ Mdl. EBH - 22 anchor ..><. seal and WLEG [ ¡ 5.5" x 33.7' 0.12 Ga. 30455 I - " Bakerweld screen, min. ID = 4.892" - r~' 9 5/8 "Baker 96A2-47 I .. Mdl. "New 5C-1" Pkr. ~ , " : 3.5" HE5 "XN" nipple >r- ~, , [ ,: - 2.81 pkg. /2.75 no go =:::'>" , ]>::'; '-:-' 5.5" x 84.5' 0.12 Ga. 304 55 I . ¡T ,. ~~. ..~ "':, 'T __l.'~. ~ ':- Bakerweld screen, min. ID = 4.892" 9 5/8" Baker Mdl. N-1 bridge plug HES "XN" Nipple 2.3131" 00 x 2.20510" HES 9-5/8" "AHC" Pkr. Minimum In Relow "AHC" Pkr. = 1.75" @ "No-ao" ~ub on bttm. of stinaer. 4181' I 2214' I Minimum In Above "AHC" Pkr. = ~.31" Cameo 2 7/8" x 1" pocket KBMM GLM HES 2 7/8" - "X" Nipple I ~ 10 = 2.31" "t,,;A~~NED MAY \Ü) ~~ 100.6:' Note: Screens perfd wI 2/18" PowerjetlEnerjet @ 6 spf from 4464' to 4490' KB = 46.0' (Parker 128) GL = 24.0' ,,0/ ~ \ '13\( \'-\ -) 8-02 JBF GMH Size JSPF NC/C 4.5" 12 OA 4.5" 12 08 4.5" 12 4518'-4542' same Jumbo Jet ("big hole") 26 gr. charges, 135/45 deg phasing, EHD = 0.74", TTP = 5.8" ¿1 Two Milled out Halliburton 9 5/8" EZSVs retainers @ 4573' and 4790' DATE REV. BY Interval (TVD) 4371'-4401 ' same 4464'-4490' same Size JSPF Interval (TVD) 4.0" 12 4372'-4402' same 4.0" 12 4464'-4490' same 4.0" 12 4518'-4542' same EHD = 0.7" HyperJet II, 90 deg. phasing Open Perfs Perforation Summary: Ref. Log: DLL I SFL 12/29/81 Squeezed Perfs 13 318" 72 ppf, L-80, Btrc.' 2234' md ~ 95/8",47 ppf, L-80 Btrc. 9 5/8" Lynes External Casing Packers at: 4091' - 4100',4346' - 4355', 4454' - 4463',4503' - 4512', 4553' - 4562' Stimulation Summary: o Sands - 10/11/95, 143.6 M# 16 - 20 Carboite frac pack to design N Sands - 10 114 I 95,53.8 M# 16-20 Carbolite frac pack to screenout 2-7/8" 6.5#/ft., L-80, 8 rd. EUE tbg. (Drift 10 = 2.347", cap. = 0.00592 bpf) KOP and Max Hole Angle are not avail. Tree: 2-9/16" - 5M ) Wellhead : FMC 1 1" 5M w/11' x 2/78" EUE tbg. hng., 2.5" "H" BPV profile 20"94 ppf H-40 Btrs.1 103' I ~ , ~ ( gyro/data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 t' SURVEY REPORT. BP EXPLORATION B - PAD WELL MPB - 02 MAST TRUCK MILNE POINT, AK AK0904G_517 SEPTEMBER 6, 2004 (' /81- )L1~ ~ ( C.J (r/t L SCANNED OCT 0 9 2004 Serving the Worldwide Energy Industry with Precision Survey Instrumentation t{ 0 c.Yc- ?-ÆtJ Y A Gyrodata Directi onal Survey for BP EXPLORATION (ALASKA) .-.., Lease: B - PAD Well: MPB - 02 Location: Mast Truck, Milne Point, Alaska Job Number: AK0904G_517 Run Date: 06 Sep 2004 Surveyor: Steve Thompson Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.473130 deg. N Longitude: 149.415180 deg. W Azimuth COITection: Gyro: Bearings are Relative to True North .-,..~ Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location SCANNED nrT n (} ?nnJl A Gyrodata Directi onal Survey BP Exploration (Alaska) Lease: B - PAD Well: MPB - 02 Location: Mast Truck, Milne Point, Alaska Job Number: AK0904G_517 MEASURED INCL AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg.! feet feet deg. feet 100 ft. 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 0.00 N 0.00 E ... --- --... -- ----..... --- -- ---.. -- ----............ --............. --- ---.. -- ---- ------... --- ---------.. ----------- ---.. ------..- --- ------ -- -----.. ----------- ---., 0 - 4200 FT. RATE GYROSCOPIC MULTI SHOT SURVEY ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO WELL HEAD LOCATION ... ---.. -- ------ ---.... --- --.. -- -- -----.. --..... -- ----........... -- ----- --- ------- ---- ----------------------------- --... -- 100.00 0.15 121.28 S 58 43 E 0.15 100.00 0.1 121.3 0.07 S 0.11 E 200.00 0.20 125.20 S 54 48 E 0.06 200.00 0.4 122.9 0.24 S 0.36 E 300.00 0.21 114.13 S 65 52 E 0.04 300.00 0.8 121.4 0.41 S 0.67 E 400.00 0.23 109.88 S 70 7 E 0.03 400.00 1.2 118.3 0.55 S 1.03 E 500.00 0.40 93.41 S 86 35 E 0.19 500.00 1.7 112.3 0.64 S 1.56 E 600.00 0.42 90.00 N 90 0 E 0.03 599.99 2.4 106.2 0.66 S 2.28 E 700.00 0.45 91.51 S 88 30 E 0.04 699.99 3.1 102.5 0.67 S 3.04 E 800.00 0.47 95.93 S 84 4 E 0.04 799.99 3.9 100.7 0.73 S 3.85 E 900.00 0.52 93.26 S 86 45 E 0.05 899.98 4.8 99.6 0.79 S 4.71 E 1000.00 0.54 89.96 N 89 58 E 0.04 999.98 5.7 98.3 0.82 S 5.63 E 1100.00 0.52 106.03 S 73 58 E 0.15 1099.98 6.6 98.2 0.94 S 6.54 E 1200.00 0.51 106.52 S 73 29 E 0.01 1199.97 7.5 99.2 1.19 S 7.40 E 1300.00 0.53 105.60 S 74 24 E 0.03 1299.97 8.4 99.9 1.44 S 8.27 E 1400.00 0.53 119.67 S 60 20 E 0.13 1399.96 9.3 101.2 1.80 S 9.12 E 1500.00 0.43 140.67 S 39 20 E 0.20 1499.96 10.0 103.4 2.32 S 9.76 E 1600.00 0.41 166.50 S 13 30 E 0.19 1599.96 10.5 106.4 2.96 S 10.08 E 1700.00 0.44 168.53 S 11 28 E 0.03 1699.95 10.9 109.8 3.69 S 10.24 E 1800.00 0.48 166.05 S 13 57 E 0.04 1799.95 11.3 113.2 4.47 S 10.42 E 1900.00 0.57 164.70 S 15 18 E 0.09 1899.95 11.9 116.7 5.35 S 10.65 E 2000.00 0.68 166.44 S 13 34 E 0.11 1999.94 12.7 120.4 6.40 S 10.92 E 2 SCANNED OCT 0 9 2004 A Gyrodata Directi onal Surve y BP Exploration (Alaska) Lease: B - PAD Well: MPB - 02 Location: Mast Truck, Milne Point, Alaska Job Number: AK0904G_517 deg. deg. BORE HOLE BEARING deg. min. DOGLEG SEVERITY deg.l 100 ft. VERTICAL DEPTH feet CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet MEASURED DEPTH feet I N C L AZIMUTH ~ 2100.00 0.68 169.42 S 10 35 E 0.04 2099.93 13.5 124.1 7.56 S 11.17 E 2200.00 0.70 175.82 S 4 11 E 0.08 2199.93 14.3 127.7 8.75 S 11.32 E 2300.00 0.59 181.17 S 1 10 W 0.13 2299.92 15.0 131.0 9.87 S 11.36 E 2400.00 0.59 190.55 S 10 33 W 0.10 2399.92 15.7 134.1 10.89 S 11.25 E 2500.00 0.63 194.38 S 14 23 W 0.06 2499.91 16.2 137.2 11.92 S 11.02 E 2600.00 0.56 205.16 S 25 9W 0.13 2599.90 16.7 140.4 12.89 S 10.68 E 2700.00 0.38 218.85 S 38 51 W 0.21 2699.90 17.0 143.0 13.59 S 10.26 E 2800.00 0.41 214.91 S 34 55 W 0.04 2799.90 17.2 145.2 14.14 S 9.85 E 2900.00 0.33 229.38 S 49 23 W 0.12 2899.90 17.4 147.2 14.62 S 9.43 E 3000.00 0.30 225.77 S 45 46 W 0.03 2999.90 17.5 148.9 14.99 S 9.03 E 3100.00 0.38 256.18 S 76 11 W 0.20 3099.89 17.5 150.8 15.25 S 8.51 E 3200.00 0.53 64.43 N 64 26 E 0.91 3199.89 17.4 150.4 15.13 S 8.61 E 3300.00 0.82 111.88 S 68 7 E 0.60 3299.89 18.0 147.5 15.19 S 9.69 E 3400.00 1.12 95.75 S 84 15 E 0.40 3399.87 19.2 144.0 15.56 S 11.32 E 3500.00 0.77 10.10 N 10 6 E 1.30 3499.86 19.5 140.4 14.99 S 12.41 E -~, 3600.00 1.12 238.88 S 58 53 W 1.73 3599.86 18.9 141.8 14.84 S 11.68 E 3700.00 1.65 121.74 S 58 16 E 2.39 3699.84 20.1 143.2 16.11 S 12.07 E 3800.00 0.63 2.34 N 2 21 E 2.04 3799.83 21.1 140.8 16.32 S 13.32 E 3900.00 1.31 223.69 S 43 42 W 1.82 3899.82 20.8 142.9 16.60 S 12.55 E 4000.00 1.26 184.73 S 4 44 W 0.86 3999.80 21.9 147.8 18.52 S 11.68 E 4100.00 1.86 138.20 S 41 48 E 1.35 4099.76 24.4 148.7 20.83 S 12.67 E 4200.00 1.74 197.22 S 17 13 W 1.78 4199.72 27.0 150.5 23.49 S 13.30 E Final Station Closure: Distance: 26.99 ft Az: 150.48 deg. 3 SCANNED OCT 0 9 2004 BP Exploration (Alaska) Well: B - PAD MPB - 02 Location: Mast Truck, Milne Point, Alaska 0.0 ~¿ -j - -:&----. .to .. .. .to -2.5 -5.0 -7.5 -10.0 ,......., d: ......... ~ ~ -12.5 J: ~ 0 z -15.0 -17.5 -20.0 -22.5 -I 1 I 1 I I I I I I I I I I I I 012 SCANNED OCT 0 9 2004 3 I I I I 4 .to I I I I 5 .to In ru n Gyrodata AK0904G_517 DEFINITIVE ~~ "'~ \. ~ '"4 \ \ ~ \ j. . j. / / ~ .to ¡þ I I I I I I I I I I I I I I I I 6 7 EASTING (ft) 8 9 \---; ~ ~~ / </ "- '" ~ \ BOTTOM - OLE \. LOC^TED M): 4200.00 I I J I I I I I I I I I 10 11 12 .-"." \ \. ~ I I I I 13 BP Exploration (Alaska) Well: B - PAD MPB - 02 Location: Mast Truck, Milne Point, Alaska 8 7 6 """' ~ 5 0 ~ ~ () "0 '-'" Ë 4 ~ w > w U) (!) ~ 3 (!) 0 c 2 1 ., ~ ~ 0 ~ ' ~ , , , ~ ~ ~~~ I I I I 2000 2500 3000 MEASURED DEPTH eft) 0 500 1000 1500 Ct"lU\IMt:n n~T 0 Q ?nnLJ. . / í a 3500 Inrun Gyrodata AK0904G_517 DEFINITIVE ----, ~ . \ "j. ~ I BOTTOM HOLE LOCATED / MD: 4200.00 , , . ,/ - I I I l I I 4000 4500 95.0 92.5 ......... u.. I g' 90.0 "0 ......... w ~ ::> ~ -: g: 87.5 f ~ w t- 85.0 82.5 BP Exploration (Alasl<a) Well: B - PAD MPB - 02 Location: Mast Truck, Milne Point, Alaska rl ~~ \ \ \~ \ \~ - ~ \ 4 - ~ .. ~ ~ ~A - \ / " 'j;:' . I I I ~! \! ~ I In ru n Gyrodata AK0904G_517 DEFINITIVE ¡Â A ,/ BOTTOM H ~' " / LOCATED OLE i ~~ MD: 4200.00 I I I I I I I I I I I 0 500 1000 SCANNED OCT 0 9 2004 1500 2000 2500 3000 MEASURED DEPTH eft) 3500 4000 4500 ~ STATE OF ALASKA ALASKA L AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate Ilil Pull Tubing [] Alter Casing [] Repair Well [] Other Convert to Injector 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. I-1 Development KBE = 46' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1' SNL, 910' EWL, SEC. 19, T13N, R11E, UM MPB-02i At top of productive interval 9. Permit Number / Approval No. 181,142 1' SNL, 908' EWL, SEC. 19, T13N, R11E, UM 10. APl Number At effective depth 50-029-20662-00 1' SNL, 908' EWL, SEC. 19, T13N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 1' SNL, 908' EWL, SEC. 19, T13N, R11 E, UM 12. Present well condition summary Total depth: measured 4700 feet Plugs (measured) 9-5/8" Baker Ndl. N-1 Bridge plug at 4546' MD true vertical 4700 feet Effective depth: measured 4546 feet Junk (measured) Two Milled out Halliburton 9-5/8" EZSV's retainers at true vertical 4546 feet 4573' MD and 4790' MD Casing Length Size Cemented MD TVD Structural Conductor 103' 20" Cement to Surface 103' 103' Surface 2234' 13-3/8" 4400 sx Arctic Set II 2234' 2234' Intermediate Production 4700' 9-5/8" 600 sx 'G', 150 sx AS, 130 Bbl Arctic Pack 4700' 4700' Liner "~ ,~,,,,.~,~,,~,, Perforation depth: measured Open: 4371' 4401'; 4464' - 4490'; 4518' - 4542' NOV i 200 true vertical Open: 4371' 4401'; 4464' - 4490'; 4518' - 4542' ,,~r~.~ m,,., & ¢~ C0~,s. C0mmissic~ Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 4427' A~'~i~ra§ Packers and SSSV (type and measured depth) 9-5/8" AHC Packer at 4239'; Screen Assembly with 9-5/8" Baker SC-1 Packer at 4264' and 9-5/8" Baker 96A2-47 SC-1 Packer at 4408'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure , 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pdor to well operation: Subsequent to operation: , 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the fj3[egoing is true and correct to the best of my knowledge Si~lned ... Son~ Title Technical Assistant Date Prepared By Name/Number: Sondra Stewman, 564-4750 - ~ ,~ ~ ~ i ..... Form 10-404 Rev. 06/15/88 Submit In Duplicate Legal Well Name: MPB-02 Common Well Name: MPB-02 Spud Date: 12/3/1981 Event Name: RECOMPLETION Start: 10/17/2001 End: Contractor Name: NABORS Rig Release: 10/22/2001 Rig Name: NABORS 4ES Rig Number: 10/17/2001 04:00 - 12:0o 8.00 MOB P DECOMP MOVE FROM MP E-06 TO B-02. RIG UP. 12:00 - 14:00 2.00 MOB P DECOMP RAISE & SCOPE OUT DERRICK. 14:00 - 20:00 6.00 MOB P DECOMP SPOT & BERM FRAC TANK. RU LINES. LOAD PITS & WT. UP TO 8.8 HEAVY. !20:00- 20:30 0.50 MOB P DECOMP PULL BPV. 20:30 - 22:00 1.50 REST P DECOMP HOOK UP LINES TO TREE. PRESS TEST LINES. 22:00- 00:00 2.00 REST N RREP DECOMP REPAIR SCR SYSTEM. 10/18/2001 00:00- 00:00 24.00 REST !N RREP DECOMP REPAIRING SCR SYSTEM. 10/19/2001 00:00- 15:00 15.00 REST ~N RREP DECOMP REPAIRED SCR SYSTEM. 15:00 - 20:00 5.00 REST P DECOMP OPENED UP WELL. TBG. 90 PSI. CSG 150 PSI. KILL WELL W/8.8+ PPG BRINE. 5.5 BPM @ 1900 PSI. CIRC.BACK TO PITS. MONITOR WELL. SLIGHT VAC. ON TBG. & CSG. 20:00 - 20:30 0.50 REST P DECOMP RUN & TEST TWC TO 3500 PSI. 20:30- 00:00 3.50 REST P DECOMP ND TREE. 10/20/2001 00:00 - 03:00 3.00 REST P DECOMP NU BOPE. 03:00 - 06:00 3.00 REST :~ DECOMP PRESS. TEST BOPE 250/2500 PSI. AS PER BP/AOGCC SPECS. TEST WITNESSING WAIVERED BY JEFF JONES AOGCC !REP. @ 20:30 ON 10-19-2001. 06:00 - 07:00 1.00 REST 3 :DECOMP :PULL TWC. 07:00 - 08:00 1.00 REST 3 DECOMP PU LANDING JT. MU TO HANGER. BOLDS. 08:00 - 09:00 1.00 REST :~ DECOMP PULL HANGER TO FLOOR. PU WT. 38K. LD HANGER. 09:00 - 12:00 3.00 REST :) DECOMP CIRC. WELL W/8.85 PPG BRINE BACK TO PITS. 5.5 BPM @ 1200 PSI. MONITOR WELL. 12:00 - 22:00 10.00 REST :~ DECOMP ATTACH ESP & HEAT TRACE TO SPOOLING UNIT. POOH W/2 7/8" TBG. & ESP, 22:00 - 00:00 2.00 REST ~ DECOMP INSPECT & LD ESP. 10/21/2001 00:00 - 04:30 4.50 REST :) DECOMP RU HALCO SL. RIH VV/6" JUNK BASKET TO 4262'. POOH. NO RECOVERY. RIH W/2" SAMPLE BAILER. SET DN. @ 4362'. POOH. NO RECOVERY. RD SL 04:30 - 06:00 1.50 REST 3 DECOMP PU MULE SHOE & 5 JTS. OF 2 1/16" STL. 06:00- 06:30 0.50 REST P DECOMP SERVICE RIG. 06:30 - 08:00 1.50 REST P DECOMP FINISH PU 5 JTS. 2 1/16" STL & 9 5/8" CSG. SCRAPER & RIH. 08:00 - 10:30 2.50 REST P DECOMP RIH W/2 7/8" TBG, TAGGED UP @ 4325'. 10:30 - 14:30 4.00 REST P DECOMP WASH DN. TO 4549'. REV. CIRC. BTTMS. UP. MONITOR WELL. 14:30 - 15:00 0.50 REST P DECOMP POOH TO 4254'. SPOT HIGH VIS. PILL OUT TBG. 15:00 - 16:30 1.50 REST P DECOMP TIH to 4549'. REV. CIRC. PILL 5.5 BPM @ 500 PSI. 16:30 - 18:30 2.00 REST P DECOMP POOH TO 4254'. MIX & PUMP COREXlT PILL. 5.5 BPM @ 1000 PSI. MONITOR WELL. 18:30 - 20:30 2.00 REST P DECOMP DROP TBG. DRIFT. POOH STDG. BACK. 20:30- 21:00 0.50 REST P DECOMP LD BHA. 21:00 - 00:00 3.00 REST P DECOMP RU SWS. PERF. 4464' TO 4490'. 2 1/8" ENERJET 6 SPF 0 DEGREE PHASING. RD SWS. 10/22/2001 00:00 - 01:00 0.00 REST P DECOMP PU STINGER ASSM. & HALCO AHC PACKER. 01:00 - 04:00 3.00 REST P DECOMP RIH W/PACKER ASSM. & 2 7/8" TBG TO 4427'. 04:00 - 07:00 3.00 REST P DECOMP SPACE OUT TO LAND W/5000K DN. PU HANGER AND LAND HANGER. RILDS. 07:00 - 07:30 0.50 REST P DECOMP RUN TWC & TEST TO 3500 PSI. 07:30- 09:00 1.50 REST P DECOMP ND BOPE. 09:00 - 11:30 2.50 REST P DECOMP CO FLANGE ON TREE. NU TREE. TEST TREE TO 5000 PSI. 11:30- 12:30 1.00 REST P DECOMP PULLTWC. Printed: 11/1/2001 9:39:27AM Legal Well Name: MPB-02 Common Well Name: MPB-02 Spud Date: 12/3/1981 Event Name: RECOMPLETION Start: 10/17/2001 End: Contractor Name: NABORS Rig Release: 10/22/2001 Rig Name: NABORS 4ES Rig Number: 10/22/2001 12:30 - 13:00 0.50i REST ; P DECOMP PRESS. TEST LINES TO 4500 PSI. 13:00 - 16:00 3.00 REST P DECOMP DROP BALL. PRESS. UP TO 4500 PSI. PACKER SET @ 4239'. BLED DN. TBG. TO 1300 PSI. PRESS. UP CSG. TO 2000 PSI. HELD FOR 30 MIN. BLED DN. TBG. 8, CSG. PRESS BACK UP TO 2500 PSI TO SHEAR RP VALVE. BLED DN. RD LINES. 16:00 - 18:00 2.00 REST P DECOMP RUN BPV. SECURE WELL & CELLAR. RELEASE RIG @ :18:00 HRS. Printed: 111112001 9:39:27AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission / TO: Cammy O Taylor (~\ DATE: December 10, 2001 Chairman · . ~SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder 1~ G~/~~_.~--,\ BPX P.I. Supervisor/'5'Y' '_ ?% ,'~'-~' MPU-B Pad ~--'7q-~''' B;02 FROM: Chuck Scheve MPU Petroleum Inspector Milne Point NON- CONFIDENTIAL I ' Packer Depth Pretest Initial 15 Min. 30 Min. ~eil.IMPUa-021Typelni. I S I T.V.D. I '4239 ITubingl '~200 I 1200I 1200 I' 1'200 I lnte~all ' II P.' ITestpsil 1060 ICasingI 1200 1'2200 I 2200 I '22°Q I P/F I,.P=..'.] 'liib.tes: Intial test pOst workover P-'i"D"lWe"! IType,ni.I" IT.V.D.I "1TUbin~lI "1 '1 I, l'nte~va'l . Typetes. t] I.TM,psil . I casing I . I I. I I . PIE I. Notes: . we, J P.T.O.I. Notes: WellI p.T.D.I Notes: I Typeln).J' ' 'l T.v.D. i .... [Tubingl I ',1 i IlntervalJ Type testI I Test.psil .... I Casing I . . ! .. I I , I . PIF,! I TYpa Ini'l ! T.V.D. I" I Tubing I I I I i lnterva'l TypeteStI 'lTest psi'J. .. I. Casing I , ' "1 ' ' I 'J "J PIE ! ,' I 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 0= Other (describe in notes) Test's Details I traveled to BPXs B Pad in the MPU and witnessed the initial MIT on well B-02 following a rig workover converting this well to an injector. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured tested for 30 minutes with the well demonstrating good mechanical integrity. M.I.T.'s performed: 1_ Attachments: Number of Failures: 0 Total Time dudng tests: ! ,hour Cc: MIT report form 5/12/00 L.G. MIT MPU B-02 12-10-01 CS.xls 12/13/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Conversion - Prod to Inject operation shutdown_ Stimulate_ Plugging_ Pull tubing _ Alter casing _ Repair well _ Perforate _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1' FNL, 908' FWL, Sec. 19, T13N, R11E, UM At top of productive interval 1' FNL, 908' FWL, Sec. 19, T13N, R11E, UM At effective depth 1' FNL, 908' FWL, Sec. 19, T13N, R11E, UM At total depth 1' FNL, 908' FWL, Sec. 19, T13N, R11E, UM 5. Type of Well: Development __ Explorato~._ Stratigraphic__ Service__X (asp's 571988, 6023121) (asp's 571988, 6023121) (asp's 571988, 6023121) (asp's 571988, 6023121) 6. Datum elevation (DF or KB feet) RKB 47 feet 7. Unit or property name Milne Point Unit 8. Well number MPB-02 9. Permit number / approval number 181-142 10. APl number 50-029-20662 11. Field / Pool Miline Point Unit / Schrader 12. Present well condition summary Total depth: measured true vertical 4700 feet Plugs (measured) 4700 feet Effective depth: measured 4546 feet Junk (measured) true vertical 4546 feet Casing Length Size Cemented Measured Depth Conductor 103' 20" Cement to Surface 136' Surface 5873' 13-3/8" 4400 sx Arctic Set II 2816' Production 11049' 9-5/8" 600 sx 'G', 150 sx AS, 11259' 130 bbl Arctic Pack True Vertical Depth 136' 2642' 8419' Perforation depth: measured Open Peris Behind Grave/Pack 4372' - 4402', 4518' - 4542'. Open Peris Shot through Screen 4464' - 4490' true vertical Open Peris Behind Gravel Pack 4372' - 4402', 4518' - 4542' Open Peris Shot through Screen 4464' - 4490' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 TBG @ 4239' MD. 2-3/8" L-80 TBG @ 4264' RECEIVED DEC 0 1 2001 Packers & SSSV (type & measured depth) 9-5/8" x 2-7/8" HES 'AHC' Packer @ 4239'. 9-5/8" Gravel Pack Packers @ 4372' & 4408'. 9-5/8" Baker Mdl. N-1 BP set @ 4546'. 2-7/8" HES 'X' Nipple @ 2214'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 11/21/2001 Subsequent to operation 11/25/2001 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ Oil __ Gas __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~,~~;~~)~ Title: Technical Assistant DeWayne R. Sc'hnorr ~ Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Shut-in, Water Injection Started 11/22/2001. 19273 16. Status of well classification as: Suspended_ Casing Pressure Tubing Pressure Service Water Iniection Form 10-404 Rev 06/15/88 · ORIGINAL 1031 Date November 26, 2001 Prepared by DeWa~ne R. Schnorr 564-5174 SUBMIT IN DUPLICATE MPB-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 10/16/2001 DOMOBE 10/23/2001 POST RWO FREEZE PROTECT 11/04/2001 CHANGE OUT WING VALVE FROM AWV TO MANUEL VALVE. 11/16/2001 SET BPV 11/22/2001 WATER INJECTION STARTED 11/26/2001 WATER INJECTION RATE- 19273 BWPD EVENT SUMMARY 10/16/01 SLICK LINE PREVIOUSLY SET BPV. BLED DOWN AND SAFED OUT SYSTEM. SUPPORT REMOVED FLOW LINES AND FOUNDATION. INSTALLED BLIND FLANGES AND TORDQUED. WELL PREPPED AND READY FOR RWO. 10/23/01 TGSM, MIRU HB&R: PRESSURE TESTED SURFACE EQUIPMENT TO 3500 PSI. FREEZE PROTECT TUBING AND ANNULUS WITH DIESEL TO 2000'. 11/04/01 SUPPORT TECHS REMOVE AWV AND INSTALLED MANUAL WING VALVE. ALL FLANGES TORQUED TO SPEC. JOB COMPLETED. PRESSURE TESTED TO 5000 PSI. 11/16/01 PJSM. SUPPORT SET BPV SO WELL TIE INS COULD INSTALL WELL HOUSE. 11/22/01 WATER INJECTION STARTED. 11/25/01 WATER INJECTION RATE IS 19273 BWPD. TUBING PRESSURE IS 1031 PSI. FLUIDS PUMPED BBLS 145 DIESEL 145 TOTAL Page I Re: FW: B-02 Completion Subject: Re: FW: B-02 Completion Date: Wed, 17 Oct 2001 10:38:43-0800 From: Tom Maunder <tom_maunder@admin.state,ak. us> To: "Mathews, William L" <MathewWL@BP.com> Thanks Bill. "Mathews, William L" wrote: > Bill Thanks Tom, Here is the original note I tried to send last night. .... Original Message .... From: Mathews, William L Sent: Tuesday, October 16, 2001 5:02 PM To: 'tom_m a u nder~ adm in. s tate. a k. u s. com ' Subject: B-02 Completion Per our conversation, we plan to set the 9-5/8" x 2-7/8" packer at -4235' md. This would put it approximately one tubing joint above the existing gravel pack packer. Sorry for the confusion, Bill Tom Maunder <tom maunder~.admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission I of 1 10/17/01 2:25 PM 10/16/2001 16:21 FAX 907 $64 4440 BP-ACT DEPT, ~003 I I i i~ II IIIE~ IIII I ..... I Tree: 2-9/16"-SM MPUB-02 Wellhead · FMC 1 1" 5M wi 11' x 2/78" EUE tbg. ""'" ~ -- ~ ' KB = 46.0' (Pa~er 128) hag,, 2.5""H" BPV profile ~ I'~ I ~ ~ GL = 24.0' Actuator: ~ a I! ! 9 ~8", 4z p~, L-80 Btm. - - - I'---[-. { k . ___. 9 5/8" Lyn~ External Casing Packem I ' ~ ~ · I Stimulation SummarY: ! ' I I 16 - 20 Ca~oi~ fmc pack to d esign ~ , ~ Pe~mtlon Summa~: ! I J [JSPf In~e~al, ~(TVD) 4,0" i 12 4464'~490' same I L J ~ w! Mdl. EBH - 22 anchor { ~zu~ md~ _4.0" ~2 4~18'-4.54~ same ~ ~ ~ ' ~al andWLEG Open Parrs , B~e~eld screen, min. ID = 4.8~" ~l ,~' 5.5" x 33,7' 0.12 Ga. ~4 Size JSPF lateral I 4408,::= :1 ' MdL "New SC-l" Pkr. 4.5" ~2 .71-~01': same ' ~'~: ~ 3.5'HES"XN"nippIe OA Co~-3 , ~'~"~ 4.5" 12 44~'~490' ~me ~, ~: 2. B~ Pkg. 12.75 no go r o~ ~ (=N~7 ~~ ~,, =4,5"~ ~2- ~18'~2'~ same ~ ~ ~ BaRe.eld scmen, min. lD=~a2"~ 1351 ~ deg phasing, EHD e 0.74", . ~ Two Mi~ed out Hallib~n 9 5/8" ~ k~ PB~ 4603 md EZSVs m~i~m ~ 4573' and 4790' a [ ! ~ 9 SI8 C~. S~e 4~0' md i i i ii iii ' =' i B iii i i i - -- MI~E POI~ UNIT 10/1~ JBF ESP C~pl~ion by N 4ES ...... ~ Well B - 02 I II BP E~LOUTION (~) lie I I I I I I II IIIIIIIIII I I I I Size JgPf Interval ~(TVD) 4,0,, ~ 12 ~372'-440Z same 4,0" 12 4464'-44§0' same _4.0" _12 4.518'-4.54A" same Size JSPF Interval ('T'VD.} 4.5" 12 ~371'-4401' same OA 4.5" 12 44~'~490' ~me 4 5" 12- ~18'~2', sama BP-ACT DEPT, ~ 002 10/23/2001 16:25 FAX 907 564 4440 TOP SCHRADER BLUFF 'STRUCTURE B-B2 AREA B.ASE MA'P bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 7, 2001 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for MPB-02 Conversion from Producer to Injector BP Exploration Alaska, Inc. proposes to convert well MPB-02 from a shut-in producer to an active injector to provide waterflood support to the northern lateral in producer MPE-30A. B-02 was drilled by Conoco as a Schrader producer in the OA, OB and N sands. A cement bond log was run by Schlumberger on 2/2/82 showing fair cement from TD up to 1700 ft md. The well was recompleted by BP in 1995. It was frac packed in all three sands. It was a Iow oil rate, high water cut producer until the ESP failed in 1999. The water rate was 1000 b/d and the oil rate was 20 b/d. Because of the poor oil rate and high water cut the well was deemed uneconomic to workover. The well has been shut in since and it's wellhouse and flowline have been removed. E-30A is a recently completed coil sidetrack. It has two horizontal laterals in the OA sands. The laterals are not supported by any injection in the area. B-02 is located in a good position to support the northern lateral. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5476 or e-mail me at maJJto:mathcw-w]('~_,bl~.¢om. Sincerely, William L Mathews Milne Point Unit/Schrader Bluff Completion Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Conversion from Prod to Inject Well Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Conversion Prod to Inject Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1' FNL, 908' FWL, Sec. 19, T13N, R11E, UM At top of productive interval 1' FNL, 908' FWL, SEC 19, T13N, R11 E, UM At effective depth 1' FNL, 908' FWL, Sec. 19, T13N, R11E, UM At total depth 1' FNL, 908' FWL, Sec 19 T13N, R11E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploratory __ Stratigraphic __ SerVice__ (asp's 571988, 6023121) (asp's 571988, 6023121 ) (asp's 571988, 6023121) (asp's 571988, 6023121) 4700 feet Plugs (measured) 4700 feet 6. Datum elevation (DF or KB feet) RKB 47.0 feet 7. Unit or Property name Milne Point Unit 8. Well number MPB-02 9. Permit number / approval number 181-142 10. APl number 50-029-20662 11. Field / Pool Milne Point Unit / Schrader Effective depth: measured true vertical Casing Length Conductor 103' Surface 5873' Production 11049' Size 20" 13-3/8" 9-5/8" 4546 feet Junk (measured) 4546 feet Cemented Cement to Surface 4400 sx Arctic Set II 600 sx 'G', 150 sx AS, 130 Bbl Arctic Pack Measured Depth True vertical Depth 103' 103' 2234' 2234' 4700' 4700' Perforation depth: Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) measured Open Perfs Behind Gravel Pack 4372'- 4402', 4464' - 4490', 4518'- 4542'.U~ ~ '~ true vertical Open Perfs Behind Gravel Pack 4372' - 4402', 4464' - 4490', 4518' - 4542' ~ 2-7/8", 6.4#, L-80 TBG @ 4172' MD. Bottom of ESP Pump @ 4210". U~ C3,..~, 9-5/8" Gravel Pack Packers @ 4372' & 4408'. 9-5/8" Baker Bridge Plug set ~4546'. ~ 2-7/8" x 1" Camco pocket KBMM GLM @ 127' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: October 22, 2001 16. If prQposal was verbally ap. proved Oil X m e~oof~aap~o~ve r~ O~'~ ~' ~ t'~\ -- Na Date approved Service 17. I he reb//.~/' ~he~orrect to th ebest of my knowledge. Gas __ Suspended __ Questions? Call William Mathews @ 564-5476. Title: Milne Point Petroleum Engineer FOR COMMISSION USE ONLY Date October 09, 2001 Prepared b~/DeWa~me R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness ,~.~(:~, ~:~'~) ~-.~,..~ Plug integrity__ BOP Test _~ Location clearance Mechanical Integrity Test _~ ..Subsequent form req--I~ired 10- ~,{~,_ Approved by order of the Commission Original Sil;Ined By Commissioner Cammy Oechslj Form 10-403 Rev 06/15/88 · 0Rt~t~tAL [ Appr°va' n°'80l0 Date//~.~/,.~/~/ SUBMIT IN TRIPLICATE Well MPB-02 Current Status: · ESP failed in January 1999. · Well has been shut in and freeze protected. BPV set. · W ellhouse and flowline have been removed. Plan Forward: 1. Install new piping to convert well to an injector. 2. MIRU. Kill well if necessary. 3. Pull existing ESP completion 4. Clean out to TD and establish injection. 5. Run 2-7/8" completion with N sands isolated. 6. Obtain a state witness of MITIA. 7. Put well on water injection and monitor pressures Tree: 2~9/16"-5M '} MPU B-02 Wellhead: FMC 1 1" 5M w/11' x 2/78" EUE tbg. - '--' '-' .... KB = 46.0' (Parker 128) hng., 2.5 .... H" BPV profile GL = 24.0' " Actuator: ~ , ~ .~ ::.:~iii~,i'~ .... 20" 94 ppf H-40 Btrs. I 103 I ~ Camco 2 7/8"x 1" 127' MD I I KOP and Max Hole pocket KBMM GLM ' ' Angle are not avail. Raychem Heat Trace w/cable guard Cen rilift No. 2 ESP Power Cable _ __ to a depth of approx. 2315' 13 3/81 72 ppi, L-80, Btrc. 12234' mdI · 9 5/8", 47 ppf, L-80 Btm. ~ ~ 9 5/8" Lynes External Casing Packers at: 4091' - 4100', 4346' - 4355', Minimum ID is 2.37" in GLM at 4454', - 446,3,', 4503'- 4512', 127' 4553 - 4562 Stimulation Summary: O Sands - 10/11 / 95, 143.6 M# 16 - 20 carboite frac pack to design N Sands - 10 / 14 / 95, 53.8 M# Centrilift FC-925 ESP FPMT 178 Stg. ' ' 16-20 Carbolite frac pack to screenout ~ Seal SectionGSTGBHL I 4188' md I I I Perforation Summary: Ref. Log: DLL / SFL 12/29/81 Centrilift Motor, 82 hp, 1230 Volt, 38 Amps, KME Squeezed Perfs Centrilift PHD I 4210'md I I I Size JSPF Interval (TVD) 4.0" 12 4372'-4402' same 9 5/8" Baker "NeTM SO-1" Pkrl , I 4.0" 12 4464'-4490' same w/Mdl. EBH-22 anchor I 4.0" 12 4518'-4542' same seal and WLEG , EHD = 0.7" HyperJet II, 90 deg. phasing 5.5" x 33.7' 0.12 Ga. 304 SSII 4372 md II Open Perfs__ i ' Bakerweld screen, min. ID = 4.892" Size JSPF Interval (TVD) ,' ' 9 5/8 "Baker 96A2-47 I ...... I NC/D ' ? Mdl. "New SC-I" Pkr. 4.5"OA 12 4371'-4401' same 3.5" HES"XN"nipple I 4421' mdl 4.5" 12 4464'-4490' same ' I 2.81 pkg. / 2.75 no go OB : t 5.5" x 84.5' 0.12 Ga. 304 Sd 4461' mdI 4.5" 12 4518'-4542' same , I Bakerweld screen, min. ID = 4.892" / ,, 4546' wlm Jumbo Jet( big hole") 26 gr. charges, I 9 5/8 Baker Mdl. N-1 135 / 45 deg phasing, EHD = 0.74", I I / bridge plug TTP = 5.8" / 4603' md Two Milled out Halliburton 9 5/8" , . ~ PBT,,D EZSVs retainers @ 4573' and 4790 · 9 5/8 Csg. Shoe 4700' md DATE REV. BY MILNE POINT UNIT 10/16/95 JBF ESP Completion by N 4ES Well B - 02 APl NO: 50-029-20662 BP EXPLORATION (AK) Size JSPF Interval (TVD) 4.0" 12 4372'-4402' same 4.0" 12 4464'-4490' same 4.0" 12 4518'-4542' same Size JSPF Interval (TVD) NC/D 4.5" 12 4371'-4401' same CA 4.5" 12 4464'-4490' same OB 4.5" 12 4518'-4542' same . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0,7:) DATE: July 12, 2000 Commissioner' ol/o/bc.) THRU: Blair Wondzell, ~~ P. I. Supervisor . êt '1(éiJ FROM: ~t!tl Jeff Jones /..-. SUBJECT: Safety Valve Tests Petroleum'l sp c r Milne Point Unit B & C Pads Julv 9. 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. . SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '8 JvP... r~-k-,;>t- 21 well houses were inspected, no failures. ". Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: FieldlUnitlPad: Kuparuk River/MPU/B-Pad Separator psi: LPS 140 HPS N/A 7/9100 N W N ~~ff¡;;lJ;t}.We-ìl ~l)at~~? ". :~'~,:', '.;"~',': :!',:,~::i,' :;J~: ;.<. ~'. ::,;',~ Pïi~ts:', ,: J"h':~Y~/+.~;:~~;: f "'~~.$:y_':d, ,~SSV ~ , '.,' .>.,::,...,-:.. W ell¡:,Tj¡l~r{~f;': Well Perm it Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code Oil, WAG, GINJ, GAS or CYCLE B-02 1811420 B-03 1820560 140 100 115 P P OIL B-04A 1821000 140 100 95 P P OIL B-06 1850130 140 100 90 P P OIL B-07 1850620 B-09 1850340 140 100 95 P P OIL B-10 1850170 140 100 90 P P OIL B-13 1850930 B-15 1851210 140 100 95 P P OIL B-16 1851490 B-19 1852300 B-20 1860050 140 100 95 P P OIL B-21 1860230 140 100 95 P P OIL B-22 1853020 140 100 100 P 4 OIL B-23 1890160 9 Componen.ts: 18 Failures: 1 Failure Rate: 5.50/0 090 Day Wells: Remarks: Three well SV's recorded slow closing times; B-04A(3:20), B-03(3:03),B-06(3:30). Some of the wells on this pad do not have well signs on them. Larry Niles, theBP representative, said he would have these items corrected. RI7 100 Page 1 of 1 Vv043m1 t.xls eared rvices rilllng BP Exploration/Arco From: Subject: Alaska Oil & Gas Conservation Commission Date: Terrie Hubble Technical Assistant 10-407 for Permit #81-142, MPB-02 September 18, 1996 Please find attached the Well Completion or Recompletion Report and Log for the above mentioned well. Due to the fact that this operation was for a Recompletion, there were no new directional surveys ran. The original directional surveys have previously been filed with you and there are no changes. /tlh RECEIVED SEP 19 1996 Alaska Oil & Gas Cons. Commissio. Anchorage ~ ALASKA OIL AND GAS CONSERVATION C MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. status ~f Well ............................................. C'Jassification of Service"Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 81-142 3. Address 8. APl Numbe'r ....... P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20662 4. Locatior{'"0i well'at su'~face ............................ ~~.~ 9. Unit or Lease Name 5278' NSL, 4301' WEL, SEC. 19, T13N, R11E, U.M.: C0~&,~Ot~ ~ , . . ' Milne Point Unit At top of productive interval /~ ~,~F/,,~,,~~" 10. Well Number , , L, /.J.~'./_Z..~ ~ 5277 NSL, 4303 WEL, SEC. 19, T13N, R11E, U.M. -'~ '~ ' ~~/~_r/'.! MP B'02 ;;~°~ ~;IPt, h4 ~ ' · ,a 303'WEL, SEC. 19, T13N, R11E, U.M. i ~: 1'1; Fieid and POol 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and SetT~t_~;.z-::~ Milne Point Unit / Schrader Bluff KBE = 47' I ADL 047438 12. Date Spudded 113. Date T.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 12/03/81 I 12/28/81 J 10/17/95 I N/A MSLI One :17. TOtal Depth (MD+TV~) 118. Plug 'BaCl~' DeP{'h'(Mb+T~'D)Jl 9'. Di'recti'0nai"Sur~eyl2b. Depth""~he'm S'SSV setpl'. Thi'ckness of Perm~'froSl 4700 465.4........FTI 4546 4500 FT~ ...... i--I..¥es... ~ N.o. ..... I ........... N/A MD! .... 1..800' (App..rox.) 22. Type Electric or Other Logs Run DLL/ GR; FDC / CNL / NGT; MLL / ML; BHCS / GR; ML / PROX; DIL/ GR; RFT 23. CAsiNG, LINER AND CEMENTING RECORD ......................... cAsING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 SUrface 103' 26" Cement to Surface 13~3/8" 72# L'80 Surface 2234' 17-1/2" 4400 sx Arctic Set II .... 9'5/8" 47~ .............. L-80 Surface 4700' 12-1/4" ~600 Sx ;G;i 'i~0 Sx Arctic set; ~3o Bbl ArctiC Pack 24~ PerforatiOns open to Production (MD~¥VD of Top and Bottom 25. ' ........ TUBING REcoRD and interval, size and number) " S,ZE ........ DEPTH SET (~"D) ' ' PACKER'SET'(MD) 4-1/2" Gun Diameter, 12 spf Squeezed Perfs, 4" CD, 12 spf 2.7/8,,,"'6.5#, L-80 4212' "' MD TVD MD TVD 4371' - 4401' 4325' - 4355' 4372' - 4402' 4326' - 4356' 4464' - 4490' 4418' - 4444' 4464' - 4490' 4418' - 4444' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 4518' - 4542' 4472' - 4496' 4518' - 4542' 4472' - 4496' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4067' - 4541' Squeeze Perfs, 42 Bbls Class 'G', 2000 psi Gravel Pack Assy, 4~08'- 4545' "'O' 'Sands: 136,972# 16/20 Carbolite Behind Pipe Gravel Pack Assy, 4372'- 4'308" 'N' Sands: 53,800# 16/20 Carbolite Behind Pipe Freeze Protect with 160 Bbls Diesel 27. PRODUCTION TEST bate Firs¥ Production IMethod of Operation' (Flowing, gas lift, etc.) "' November 19, 1995 I Electric Submersible Pump Date"of T~st Hours Tested PRODUCTION FOR OIL-BEE GAS-MCF WATER'BEE CHOKE SIZE I GAs-O~L R.,{:ho ..... TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED .1~ OIL-BEE GAS-MCF WATER-DEL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED SEP 19 1996 Alaska 0il & Gas Cons. Commissio~ Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 2'9. Geologic Marker/ 30. J"Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Prince Creek 1938' 1892' Schrader Bluff 3264' 3218' 'NC' Sand 4376' 4330' 'OA' Sand 4464' 4418' 'OB' Sand 4518' 4472' Seabee 4677' 4631' 31~ List Of Attacl~ments .... Summary of Daily Drilling Reports '~21 i--herel:)y certify that the foregoing is tlrue andic~)rrect to the best of my knoWledge ....... TimSchofield /L,V,"I .-.~.~~ Title Senior Drilling Engineer Date c~ /~ //. . Prepared By Name/Numbec Terrie Hub~le, 464-4628 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 ,~ND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BP/AAI SHARED SERVICE DAILY OPERATION~~, PAGE: 1 WELL: B-02 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 09/26/95 03:30 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 4ES WO/C RIG: NABORS 4ES 09/27/95 ( 1) TD: 4700 PB: 0 09/28/95 (2) TD: 4700 PB: 0 09/29/95 (3) TD: 4700 PB: 0 09/30/95 (4) TD: 4700 PB: 0 BLEED OFF WELL MW: 0.0 SCOPE DERRICK DOWN. BRIDAL UP. LD DERRICK. MOVE IN & RIG UP. TEST 9-5/8 & BRIDGE PLUG T/3500 PSI. BROKE DN @ 2800 PSI, BLEED T/400 PSI. ND WKM FLANGE. NU OTIS FLANGE. NU LUB. ATTEMPT TO SET FMC BPV, WON'T SET. ATTEMPT TO SET CAMERON TWC, WON'T SET. RD LUB. ND OTIS FLANGE. NU WKM FLANGE. BLEED OFF GAS. MONITOR WELL & CONT BLEEDING. RIG ACCEPTED @ 1530 HRS., 09/26/95. BLEED GAS TO TT MW: 0.0 BLED OFF GAS & MONITOR. PRESSURE TEST 9-5/8" CASING ANN T/1000 PSI. BLEED 9-5/8" CASING ANN TO 0 PSI. ND DRY HOLE XMAS TREE. NU BOPE, RISER, FLOWLINE & FUNCTION TEST BOP'S. MU LANDING JT. BOLDS. ATTEMPT TO PULL HANGER. ATTEMPT TO CIRC THRU TUBING & ANN. NO CIRC. RU CAMCO. RU ATLAS. RIH WITH GUN W/CCL & PERF. POOH. BLED WELL & MONITOR. RD ATLAS. MU LANDING JT, DISPLACE DSL WITH NACL THRU PERF RETURNS TO TT. MONITOR. BLED GASTO TT. LD LANDING JT. SHUT IN WELL & BLEED GAS TO TT. CLEAN UP AND MONITOR WELL MW: 0.0 CIRC TBG THROUGH PERFS. RU ATLAS AND RIH W/CHEMICAL CUTTER AND CUT TBG AT 302'. POOH AND RD. MONITOR WELL. LD OLD HANGER AND MU AND LAND NEW HANGER. RILDS, INSTALL TWC. RU AND TEST BOPE. MU LD JT IN HANGER. PULL HANGER AND LAY DOWN. FILL HOLE THROUGH ANNULUS. MONITOR WELL. POOH AND STAND BACK 2 STDS AND 2 JTS. BHA #1, RIH W/TBG, HANGER AND LD JT. CBU. LATCH ON STUMP W/OS HGR 1' FROM BOWL. RD ATLAS CHEM CUTTER/CCL MW: 0.0 MONITOR WELL & BLEED GAS T/0 PSI. MU LANDING JT & ATTEMPT TO CIRC PUMP. MONITOR WELL & BLEED ANNULUS & TBG PRESSURE T/0 PSI. RU ATLAS, RU LUB & TEST. CHANGE BALLS T/15' & PREPARE TO FREE POINT. RIH WITH FPI T/1630'. UNABLE TO GET ACCURATE INFORMATION. POOH & BLEED LUB OFF. READJUST GUIDES ON FPI & RIH TO LOCATE FP @ 1656'. POOH & LD FPI. RI ATLAS, PU PERF GUN/CCI & RIH TO PERF. POOH LD GUN/CCL. RD LUB & 15' PARKER BALLS. RU & DISPL DIESEL THRU CHOKE TO TT. CONT CIRC TO HEAT WB WITH NL. LD LANDING JT, MU PERF FLANGE & PU ATLAS LUB, TEST ILUB, PU CHEM CUTTER/CCL LOG & RIH T/1607'. LOG & CUT. POOH & LD CHEM CUTTER/CCL. WELL : B-02 OPERATION: RIG : NABORS 4ES PAGE: 2 10/01/95 (5) TD: 4700 PB: 0 10/02/95 (6) TD: 4700 PB: 0 10/03/95 (7) TD: 4700 PB: 0 10/04/95 (8) TD: 4700 PB: 0 CIRC & COND NACL MW: 0.0 RD ATLAS. ND SHOOTING FLANGE & NU FLOWLINE. MU LANDING JT & PULL HANGER FREE. CIRC & COND WELLBORE NACL. POOH. LD TUBING, FISHING ASSY. INSTALL TEST PLUG & CHANGE RAMS. PULL TEST PLUG & INSTALL WR. CLEAR FLOOR & STRAP DC'S. ND FLOWLINE & NU SHOOTING FLANGE. RU CAMCO, RU & TEST LUB. HANG UP BELLOW CASING HEAD. PULL WR & VERIFY OD. ATTEMPT GR/JB. RIH T/1607'. RD CAMCO ND SHOOTING FLANGE & NU RISER/FLOWLINE. IWR, CLEAR FLOOR & MONITOR. PU BAKER PACKER, STORM VALVE, DC & RIH WITH DP. SET PACKER & TEST CASING. RELEASE PACKER & OPEN STORM VALVE. MONITOR. CIRC & COND NACL. WASH INSIDE TUBING T/2036' MW: 0.0 CIRC & WT UP NACL @ 1593' TEST CASING. HEAT WELLBORE. POOH & TEST CASING WITH BAKER ~EST PACKER. LOAD & STRAP TUBING & RU TO RUN SAME. PWR & INSTALL TP. CAHNGE RAMS & TEST. PULL TP. MU BHA #3 (FISHING ASSY) & RIH T/1600' WITH TUBING INSTALLING TIW VALVE ON EVERY JT. CIRC GAS OUT EVERY 300'. CBU 2 TIMES. SPACE OUT & WORK OVER FISH @ 1607', LAND TUBING, CHECK FISH. RILDS, LANDING JT, CLEAR FLOOR. MU MILL BHA #4 & RIH WITH HYDRIL CS TUBING T/1992'. CIRC THRU CHOKE & MONITOR WELL. WASH OUT ICE F/1992' T/2005'. CLOSE HYDRIL & CIRC OUT GAS THRU CHOKE. MONITOR WELL. CIRC & WT UP. MONITOR WELL. WASH OUT ICE F/2005' T/2036'. MU BHA #5 MW: 0.0 LUBRICATE RIG. PU 2-1/16" HYDRILL TUBING & WASH OUT ICE F/2036' T/2191'. DISPLACE WELL. PU & RIH WITH TUBING. DISPLACED EVERY 300' & CIRC GAS OUT THRU CHOKE & GAS BUSTER. POOH. LD HYDRIL TUBING & HANDLING TOOLS. PU LANDING JT. MU HANGER WITH TIW VALVE & CIRC THRU CHOKE BOTTOMS UP X 2. BOLDS, PULL HANGER, LD PUPS. POOH, LAYING DOWN TUBING. FISHING ASSY & TUBING T/3960'. INSTALL TEST PLUG. CHANGE RAMS & TEST. IWR. MU BHA #5. RIH W/ BHA #8 MW: 0.0 LUBRICATE RIG. RIH TO RETRIEVABLE BRIDGE PLUG @ 4010'. REVERSE CIRC. TEST CASING. SLIP DRILLING LINE. POOH. PU SCRAPER & RR #1 & RIH T/4010. CIRC. POOH & LD SCRAPER & RR 91 BIT. MU BRIDGE PLUG RETRIEVING TOOL & RIH TO BRIDGE TOP @ 4010'. CIRC & LATCH TO BRIDGE PLUG. CBU THRU CHOKE & GAS BUSTER. OPEN ANN & CONT CIRC. MONITOR WELL. NO FLOW. POOH & LD BRIDGE PLUG & RET TOOL. MU BHA #8 & RIH. WELL : B-02 OPERATION: RIG : NABORS 4ES PAGE: 3 10/05/95 (9) TD: 4700 PB: 0 10/06/95 (10) TD: 4700 PB: 4545 10/07/95 (11) TD: 4700 PB: 4545 10/08/95 (12) TD: 4700 PB: 4545 10/09/95 (13) TD: 4700 PB: 4545 10/10/95 (14) TD: 4700 PB: 4546 CUT TBG W/ CHEM CUTTER MW: 0.0 RIH W/ BHA #8. FILL DP EVERY 10 STDS T/4378'. CIRC OUT GAS & CRUDE T/THRASH TANK. TIH TAG FISH @ 4417'. ATTEMPT TO LATCH PLUG. TOH WITH BHA #8 & INSTALL GRAPPLE. TIH WITH BHA #9 TAG FISH @ 4417'. ATTEMPT TO CATCH PLUG. CIRC WELLBORE. MONITOR WELL. POOH & LD BHA #9. ND RISER & NU SHOOTING FLANGE. RU ATLAS W/ LUB & TEST. RUN #1 IMPRESSION BLOCK @ 4411' & POOH. RUN #2 RIH CCL & SINKER BARS T/4426' & POOH. RUN #3 RIH BAILER T/4436'. POOH. RUN #4 RIH IMP BLOCK, COULDN'T GET INTO PACKER @ 4418' & POOH. RUN #5 RIH WITH CHEM CUTTER T/4534' & CORRELATE IN & CUT BLANK JT @ 4440' & POOH. POOH W/ FTA #11 MW: 0.0 POOH W/ CUTTER & RD ATLAS. ND PERF FLANGE & NU FLOW LINE. MU BHA #10 & RIH & ENGAGE PACKER @ 4417' & PULL FREE. CBU. TOH W/ FTA #10 REC PACKER & 10' OF BLANK PIPE. MU & RIH WITH BHA #11. WASH OVER SCREEN ASSY F/4440' T/4537'. CIRC XANVIS SWEEP. POOH & LD FTA #11. MU FTA #12 & RIH. LATCH SCREEN ASSY & PULL TO FREE. CBU. POOH W/ FTA #12. WAIT ON SQUEEZE CMT MW: 0.0 CONT TOH & LD FTA #12 & SCREEN ASSY. TIH WITH BHA #13, TAG FILL @ 4539'. REV CIRC & WASH T/4541', TAG BRIDGE PLUG. REVERSE XANVIS SWEEP. TOH & LD BHA #13. MU MULE HSOE & RIH. CUT DRLG LINE. CONT TIH T/4541'. TEST SURFACE LINES. POOH 11 STDS. SQUEEZE CEMENT TO PERFS. IN STAGES & HOLD IN PLACE. TO PITS. DROP WIPER PLUG & PUMP DOWN. CIP @ 0300 HRS., 10/07/95. LD DP & POOH. DRILL CMT SQZ OUT OF CSG MW: 0.0 TEST BOP'S. WOC. TIH WITH BHA #14 T/4067', TOP OF CEMENT. WOC & CIRC & CLEAN FLUID. TEST 9-5/8" CASING. OK. DRILLING CEMENT OUT OF 9-5/8" CASING F/4067' T/4166'. NU DOWN PERF FLG & NU FL MW: 0.0 DRILLING CEMENT SQUEEZE F/4166' T/4350'. TEST CASING. DRILLING CEMENT F/4350' T/4538'. TAG BRIDGE PLUG. CIRC XANVIS SWEEP. REV CIRC. LD DP & TOH. ND FLOW NIPPLE & NIPPLE UP PERF FLANGE. RU ATLAS & LUB & TEST. RUN #1 RIH GUN. WIRELINE TIE-IN & TD @ 4532' SOLID & CLEAN PU. POOH. RD ATLAS WIRELINE. RD PERF FLANGE & RIG FLOWLINE. RIH WITH PERF GUN #1 MW: 0.0 CONT TO RIG FLOW NIPPLE. MU BHA #15 & RIH T/4538' TAG. NO FILL. MILL ON E-Z DRILL. CIRC & CLEAN BRINE CHANGE OUT. TOH T/1700'. CIRC BRINE. CONT TOOH & LD BHA. ND FLOW NIPPLE & NU PERF FLANGE. RIG ATLAS & TEST LUB. RUN #1 RIH WITH BAKER MODEL N-1 BRIDGE PLUG & SET. RUN #2 RIH WITH SPF GUN. RECEIVED SEP 19 199t Alaska Oil & Gas Cons. Commm~lor~ Anchamge WELL : B-02 OPERATION: RIG : NABORS 4ES PAGE: 4 10/11/95 (15) TD: 4700 PB: 4546 10/12/95 (16) TD: 4700 PB: 4546 10/13/95 (17) TD: 4700 PB: 4546 10/14/95 (18) TD: 4700 PB: 4546 10/15/95 (19) TD: 4700 PB: 4546 RU TO FRAC OA-OB SAND MW: 0.0 CONT RIH WITH RUN #2 PERF F/4518' T/4542'. RUN #3 GUN F/4464' T/4490'. RIH WITH GR/JB T/4546'. ND SHOOTING FLANGE & NU FLOW NIPPLE & CHANGE RAMS & TEST. RU BAKER FRAC PAC ASSY & RIH TO BRIDGE PLUG & SPACE OUT. CIRC DOWN TUBING & DROP BALL & SET PACKER IN STAGES. PULL TEST PACKER & TEST ANNULUS. RIG CAMCO SLICK LINE & RIH & RETRIEVE ROD BALL & RIG DOWN CAMCO. RIG BJ SERVICES TO FRAC PAC. RIH W/ PUMP BAILERS & TAG MW: 0.0 FRAC-PAC SANDS WITH BJ TEST LINES. DATA FRAC & ANALYZE RESULTS. FRAC WELL. ANNULUS BROKE DOWN @ APP. ATTEMPT TO CIRC OUT LONG WAY, NO RESULTS. RD BJ & LD TUBING. CIRC OUT EXCESS FRAC-SD & MONITOR WELL. POOH. LD TUBING & LD DC'S & BAKE FRAC TOOL. ND FLOWLINE & NU FLANGE. MOVE BJ EQUIP & RIG CAMCO WIRELINE. RIH WITH 2-1/18" BAILER ON SLICKLINE & TAG @ 4377'. RIH W/PERF GUN #1, 30' MW: 0.0 R/D CAMCO. P/U TBG AND MULE SHOE, RIH TAG SD AT 4382'. REV CIRC TO PKR TOP AT 4408'. POOH AND L/D WASH PIPE. M/U BAKER PLUG AND SETTING TOOL, RIH. CIRC AND SET PLUG IN PKR AT 4408', PUMP SD PLUG TOP. TOH W/SETTING TOOL, L/D. N/D FLOWLINE AND N/U SHOOTING FLANGE. RIG ATLAS AND TEST LUB. RIH W/GUN #1, 30'. 4-1/2" 12 SPF. RIG BJ FOR FRAC PAC MW: 0.0 CONT RUN PERF #1. F/4372' T/4402'. RUN PERF #2. RIH WITH GR/JB. ND FLANGE & RU FLOW NIPPLE. MU RETRIEVING TOOL & RIH T/4408'. CIRC XANVIS SWEEP TO ANNULUS & REVERSE SAME DOWN TO CLEAN FRAC SAND FROM PLUG & RETRIEVE. POOH WITH PLUG. RIG FLOOR TO RUN BAKER FRAC PAC ASSY. MU FRAC PAC TOOLS & RIH ON 4-1/2" TBG TO PACKER @ 4408'_ SNAP SEALS INTO PACKER & DROP SETTING BALL & SET PACKER T/2200 PSI. PULL & TEST SAME & TEST ANNULUS. REVERSE OUT SETTING BALL. RIG BJ TO FRAC PAC 'N' SANDS. RUN PDK LOG MW: 0.0 PERFORM DATA FRAC. STRESSED SCREEN SEVERAL TIMES. REVERSE OUT EXCESS FRAC. CIRC & BALANCE WELL BORE FLUIDS. POOH & LD TUBING & FRAC TOOLS. MU BAKER WIRELINE ENTRY GUIDE & RIH & SET IN PACKER @ 4266'. POOH. LD DP. RD FLOW NIPPLE & RU SHOOTING FLANGE. RIG ATLAS & TEST LUBRICATOR & RIH WITH PDK LOG. WELL : B-02 OPERATION: RIG : NABORS 4ES PAGE: 5 10/16/95 (20) TD: 4700 PB: 4546 10/17/95 (21) TD: 4700 PB: 4546 10/18/95 (22) TD: 4700 PB: 4546 RIH WITH ESP COMP MW: 0.0 RUN PKD LOG THROUGH GRAVEL PACK. FOUND TD. ND FLANGE & NIPPLE FLOW NIPPLE. CHANGE RAMS IN BOP & TEST. PU WASH STRING & TUBING T/4268'. MIX XANVIS SWEEP WITH LITHIUM BREAKER & SPOT ON ANNULUS SIDE. PU TUBING T/4525' & WASH TO BOTTOM OF GRAVEL PACK @ 4545' & CIRC. POOH. PULL WR & RU TO RUN ESP COMP. MU ESP ASSY & CHECK OUT. RIH WITH SAME. ND BOP'S & NU TREE MW: 0.0 RIH WITH ESP COMPLETION. RU HEAT TRACE TAPE EQUIP. RIH WITH ESP COMPLETION INSTALLING HEAT TRACE & ESP CABLE GUARDS. INSTALL HANGER & SPACE OUT FOR HEAT TRACE PENETRATOR & CHECK. MAKE ESP SPLICE @ HANGER & CHECK. LAND TUBING & RILDS, CLEAR FLOOR & SET TWC. ND BOP'S & NU TREE. RELEASED & MOVE T/MPF-01 MW: 0.0 CONT NU TREE & TEST. CHECK HEAT TRACE & ESP. PULL TWC & FREEZE PROTECT ANNULUS & TUBING, SET BPV. RD CELLAR LINES & SECURE TREE & CLEAN PITS & FLOWLINE. RIG RELEASED @ 1500 HRS., 10/17/95. SIGNATURE: (drilling superintendent) DATE: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 October 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION MPB-02 1 PFC/PERF FINAL BL+RF 1 PDK FINAL BL+RF ECC No. Run ~ 1 6490.04 Run # 1 6490.05 Please sign and return to: Attn. Rodney D. Paul~son Atlas Wireline Services 5600 B St'reet Suite 201 ~/ Anchorage, AK 99518 Received by: ~~ / //~] Date- LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: ' 17 October 1995 Transmittal of Data ECC ~: 6490.03 Sent by: HAND CARRY Data: PFC/PERF Dear Sir/Madam, Reference~ MPB-02 MILNE POINT / SBP NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PERF FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600///~B Street Suite 201 ~ Anchorage, AK 99518 . ~ Or FACto (907) 563-7803 Received by:~~7 ~~,.~ Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MPB-02 M~LNE POINT / SBP NORTH SLOPE, AK Enclosed, please find the data as described below: Date: RE: 10 October 1995 Transmittal of Data ECC'#: 6490.02 Sent by: HAND CARRY Data: CCL Prints/Films: 1 CCL FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street · Suite 201 ~ Anchorage, AK 99518 Received bz~'-/ Date: .,~ ,, LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AKa. 99501. Date: 4 October 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL MPB~02 %~ MPB-02 DESCRIPTION CCL FINAL BL+RF 1 CCL FINAL BL+RF Run ECC No. 6490'.00 Run # 1 6490.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ Or~X to (907) 563-7803 Received bye//~z~///~,~/~. Date: RECEIVED OCT 3 1995 ~as.lr, a .0il & Gas Cons. Commission' BP EXPLORATION TO' David W. Johnston Chairman Alaska Oil & Gas Commission From: Steve Horton, Drlg Mgr Shared Services Drilling Subject: Suspended wells Compliance with regulations In response to your letter dated August 15, 1994 regarding suspended wells attached are lists detailing well status and criteria for maintaining these wells in a suspended status. Plans for well inspections are in place for October 1 through October 3, 1994 as discussed with Blair Wondzell and John Spaulding. Updated reporting has been filed with the commission as listed. Yours Sincerely, Steve Horton Drilling Manager Bill Bredar Patrick Collins Jim Farnsworth Mike Miller Bruce Policky Scott Sigurdson Marian Sloan RECEIVED ' 0CT 1 4 1994 Alaska 0il & Gas Cons. Commission Anchor~a Suspended Wells, Request to retain sus.Dension status The following wells are listed as suspended by the AOGCC under 20 AAC 25.110. These wells are requested to remain suspended for the reason(s) as indicated. Site inspections should be conducted as soon as possible. MPA-01; 029-20376-00 79-/(i)'0 4 Potential recompletion in the Kuparuk C and/or B sand as a water injector. Decision hinges on 1994/95 development drilling results (E-13) in this area. MPB-02; 029-20662-00 81-/¢'142 This well is scheduled for initial completion in the Schrader Bluff late this year or early next year. MPA-03; 029-20891-00 83-~001 Future utility as a Schrader Bluff producer with producing utility when surface infrastructure is installed on A pad. MPN-01 B; 029-21053-02 84-0013 N-01 B is a usable well in the Schrader Bluff, with producing utility when surface infrastructure is installed on N pad. The well should be retained in a suspended status until that time. MPC-16; 029-21364-00 85-011 0 C-16 has recompletion potential in the Kuparuk "C" sand and/or the Schrader Bluff horizons. Although additional evaluation must be performed to quantify reserves and production potential, C-16 is believed to be a viable workover and/or sidetrack candidate. NWM#1; 029-22231-00 91-0145 Northwest Milne #1 should remain suspended until the Northwest Milne Point development is better defined. The wellbore is strategically located on a gravel island and may. possess utility in either production or injection operations. DNR recently certified this well as capable of production. No Point #1; 029-22450-00 94-0027 No Point #1 will be utilized in the upcoming F- Pad development. Expectations are to complete the Kuparuk "A" zone and commence production 4Q95. Niakuk #4, 029-21217-00 84-O2O0 Niakuk #4 is requested to remain suspended until the viability of the well for monitoring is defined. Niakuk #5, 029-21290-00 85-0027 Niakuk #5 should remain suspended for observation purposes at this time. Sag Delta #33-12-16, 029-20176-00 75-0058 Area being drained by 1994 Alapah well NK-26 (HAW). Potential use as a monitor well for this new reservoir Would have to truck oil across winter ice road if resume production Produced 186 MBO in 1985 2 month production' test. Sag Delta #5, 029-20527-00 80-0129 Area being drained by L5-26 (high gas well), L5-28, and L5-36 from south to west. Well tests indicated fairly tight, but productive rock; perhaps inadequate stimulation? Costs prohibitive for eventual tie-in to L5 (? via Heald Point). Potential for gas cap monitor well Sag Delta 31-11-16, 029-20011-00 69-0014 Area being drained by L4-36, 80 Acre offset to NW. Potential for service well (water injection?) Well is capable of production, but most Lisburne in water leg and costs likely prohibitive for tie-in to L4. Sag Delta #2A, 029-20234-01 77-0069 South of Sag Delta #1, in water leg of Alapah oil accumulation in NK-26 well. Remote potential for pressure monitoring of Alapah offtake and the effect on the Alapah aquifer; though, costs would likely be prohibitive. Sag Delta #8, 029-20519-00 80-0121 Z-32A, 029-21924-01 93-0113 S-10A, 029-20765-01 91-0123 Sag Delta #8 should remain suspended until the development plan for the area is better defined. This well may possess utility for production or as an observation well. Z-32 was shut in due to high water production in 1992. In 1993 it was sidetracked to a new location. The oil column at the new location was less than prognosed and was not considered economic and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. S-10 was sidetracked in 1992. Drilling difficulties were encountered while drilling through a fault in the Kingiak and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. The West Sak formation, a non unitized formation in the PBU license area, is reachable from this wellbore. Work in ongoing on a facility sharing agreement. In the case that a satisfactory agreement is reached, this wellbore could be used to access oil in this formation. Y-22A, 029-21558-01 88-O 115 Y-22 was sidetracked in 1988. The sidetrack was suspended due to drilling difficulties. There is oil in the region that can be reached as a new sidetrack from this well. A location has not been worked on but we wish to retain this wellbore for a future sidetrack. U-01, 029-22244-00 92-0011 There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. PR 33-12-13, 029-20047-00 69-0104 The well penetrates The West Sak and Ugnu formations in the aquifer. Work in ongoing on a facility sharing agreement with subsequent appraisal of the formations. This well could be used to test the aquifer properties. These wells are listed as suspended, action items are detailed. Ak Island ¢1,289-20018-00 81-0119 Alaska Island ¢1 was abandoned in 1988. The completion notice has been refiled with AOGCC on 9/15/94. The site is ready for inspection (priority 1). Niakuk ¢1A, 029-20156-01 76-O028 Niakuk #lA was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). Niakuk #2A, 029-20180-01 76-O079 Niakuk ¢2A was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). PBU H-01, 029-20099-00 71-0015 The well was drilled in 1971 and hit a down thrown fault block with only 20ft of oil bearing Ivishak. This was not economic at the time. It was left suspended without tubing. Recent success in fraccing the Sag formation indicated that it might be an economic well. A rig workover was completed in April 1994 and the well was put on production 9/94. It is not necessary to inspect this site. Kemik Unit ¢1,223-20006-00 70-0060 Kemik Unit ¢1 is scheduled to be abandoned in the near future. Abandonment planning is now in progress. Site inspection will not be necessary at this time most likely should be scheduled for Spring of 1995. P2-59, 029-22096-00 90-0140 Arco Alaska Inc. is the operator of this well, they will be addressing the question of suspension. Sag Delta #3, 029-20233-00 79-0080 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. Sag Delta #4, 029-20245-00 77-0015 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. The following wells are not under BP Exploration ownership. A letter requesting the owners to respond regarding their wishes for these wells was sent on 9/30/94. MP 03-10-12, 029-20483-00 80-0066 MP 33-11-12, 029-20504-00 80-0092 CHEV 18-11-12, 029-20511-00 80-0108 Term C 03-11-12, 029-20356-00 78-0102 MP 22-31-11-13, 029-20545-00 81-0010 MP 43-31-11-13, 029-20536-00 80-0139 MP 30-11-13, 029-20546-00 80-0152 MEMORANDUM e of Alaska Alaska Oil and Gas Conservation Commission TO: David~ DATE: October 2, 1994 Chairman THRU: Blair Wondzell, .-~~ FILE NO: 2991jbbd.doc P. I. Supervisor '~'/~-~ John Spaulding,Q~. Petroleum Insp. ~l~,l ~3A FROM: SUBJECT: Suspended Wells Inspection North Slope, Alaska October 1,2&3, 1994:_ I accompanied Marian $1oan BPX representative on an inspection tour of BPX suspended wells at various North Slope locations. Travel was by pickup and helicopter. Marian Sloan Informed me that BPX is drafting a program with reasons for leaving wells listed below as suspended, this program will be available to the AOGCC in the very near future Oct. 1,1994 Y-22A / PBU / PTD 88-115;. well head on configuration, no pressure on tubing or annulus, area very clean, well is located on a producing drillsite. S-10A / PBU / PTD 91-123; wellhead on configuration, no' pressure on tubing or annulus, area clean, well is located on a producing drillsite. U-01 / PBU / PTD92-11; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. Z-32A / PBU / PTD 93-113; wellhead on configuration, no pressure on tubing, 750 psi on inner annulus, 0 pressure on outer annulus, area clean, well is located on producing drillsite. Chevron 18-11-12 / PTD 80-108; wellhead on configuration, no pressure on tubing or annulus, area clean. MP 22-31-11-13 / PTD 81-10; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. MP 32-30-11-13 / PTD 80-152; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. Oct. 2, 1994: A-01 / MPU / PTD 79-40; wellhead is removed with casing hanger still on, area clean, well is located on a active drillsite. A:03.../MPU / PTD.83-0.1; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a active drillsite. B-02 / MPU / PTD 81-142; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite, C-16 / MPU / PTD 85-116; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. N-01B / MPU / PTD 84-13; wellhead on configuration, no pressure on tubing or annulus, area clean with timbers covering the cellar area and well guard around the wellhead. No Point #1 / MPU / PTD 94-27; wellhead on configuration, area clean, unable to land helicopter to check wellhead for pressures, No Point #t is scheduled to become part of the F- pad construction at MPU. , NW Milne #1 / MPU / PTD 91-145; wellhead on configuration, area clean, island is suffering from severe-erosion on the North side. O...cL .3, ,.1994: .Sag Delta 31-11-16 / PTD 69-14; wellhead on configuration, area clean, has wooden location marker, no pressure on tubing or annulus. Sa,q Delta #3 / PTD 76-80; wellhead on configuration, area clean no pressure on tubing or annulus. sa,q Delta ~4 / PTD 77-15; wellhead on configuration, area clean, no pressures on tubing or annulus. Sa.a Delta #2A / PTD 77-69;j wellhead on configuration, no pressures on tubing or annulus, timbers and cellar box material, reserve pit open. Sa,q Delta #5 / PTD 80-129; no wellhead; bell shaped affair was covering the supposed well surface location, area clean. Sa,q Delta #8 / PTD 80-121; wellhead on configuration, timbers and well guard, island is eroding. · Alaska Island #1 / PTD 81-119;. unable to land, area appeared clean from the air, marker post visible on South side of island. · Niakuk #4 / PTD 84-200; wellhead on configuration, concrete river weights, cellars open, island eroding. · Niakuk #5 / PTD 85-27; wellhead on configuration, concrete river weights, cellars open, island eroding. Location Clearances; Niakuk #lA / PTD 76-28; area is clean, no visible marker post, island is eroding as planned. (;Niakuk #2A / PTD 76,79; ...area -is-clean;-.no-visible-marker-post; ..island--is-eroding as planned. I recommend that the AOGCC consider Niakuk lA & 2A for final abandonment and location clearance. , Summary,: I inspected locations of 28 BPX suspended wells. I also inspected 2 wells for final abandonment and location clearances. ALASKA OIL AND GAS CONSERVATION COMMISSION ..WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 15, 1994 Steve Horton, Drlg Mgr BP Exploration (Alaska) Inc P O Box 196612 (MB12-1) Anchorage, AK 99519-6612 Re: Suspended Wells Compliance with regulations Dear Mr. Horton: BP Exploration and the predecessor Sohio companies have several suspended wells as shown on the attached lists: BP SUSPENDED WELLS PRIOR TO 1980 and BP SUSPENDED WELLS SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above, or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as .r~_equir~d by 20 AAC 25.110(e), must have well site inspections is ye snow covering the locations. Chairman ",.,,~ ~ Attachments c: Blair Wondzell bew/11 bps usp 8/15/94 PERMIT 79-0040-0 80-0066-0 80-0092-0 80-0108-0 80-0121-0 80-0129-0 80-0139-0 80-0152-0 81-0010-0 81-0119-0 81-0142-0 83-0001-0 84-0013-0 84-0200-0 85-0027-0 85-0110-0 88-0115-0 90-0140-0 91-0123-0 91-0145-0 92-0011-0 93-0113-0 94-0027-0 API NUMBER 029-20376-00 029-20483-00 029-20504-00 029-20511-00 029-20519-00 029-20527-00 029-20536-00 029-20546-00 029-20545-00 089-20010-00 029-20662-00 029-20891-00 029-21053-02 029-21217-00 029-21290-00 029-21364-00 029-21558-01 029-22096-00 029-20765-01 029-22231-00 029-22244-00 029-21924-01 029-22450-00 BP SUSPENDED WELLS SINCE 1980 AUGUST 1994 WELL WELL WELL NAME CLASS STATUS MILNE POINT UNIT A-01 EXP SUSP PRUDHOE BAY UNIT 3-10-12 DEV SUSP PBU MP 11-33-11-12 i DEV SUSP PRUDHOE BAY 131~IT TR 18-11-12 DEV SUSP SAG DELTA 8 EXP SUSP SAG DELTA 5 EXP SUSP PRUDHOE BAY UNIT 31-11-13 DEV SUSP PBU MP 32-30-11-13 1 DEV SUSP PBU MP 22-31-11-13 2 DEV SUSP ALASKA ISLAND I EXP SUSP MII~NE POINT UI~IT B-02 DEV SUSP MILNE POINT UNIT A-03 DEV SUSP MILNE POINT UNIT N-01B DEV SUSP NIAKUK 4 EXP SUSP NIAKUK 5 EXP SUSP MILNE POINT UNIT C-16 DEV SUSP PRUDHOE BAY UNIT Y-22A DEV SUSP PT MCINTYRE P2-59 EXP SUSP PRUDHOE BAY UNIT S-10A DEV SUSP NORTHWEST MILNE I EXP SUSP PRUDHOE BAY UNIT U-01 DEV SUSP PRUDHOE BAY UNIT Z-32A DEV SUSP NO POINT i DEV SUSP STATUS DATE 4/15/oo lO/11/8o 4/29/Ol 12/24/80 4/15101 4/13/81 2/20/81 1/10/81 2/14/81 6/08/82 5/27/82 12/10/83 4/27/84 2/17/85 4118/o5 lO/27/93 lO/29/88 12/22/9o 11/o6/91 3/30/92 3/16/92 8/31/93 4/08/94 SECT 23 33 33 O7 27 36 O5 30 30 23 30 25 25 10 33 25 O6 TWP 13N 11N 11N 11N 12N 12N 10N llN 11N 10N 13N 13N 13N 12N 12N 13N 11N 12N 12N 14N 11N 11N 13N RNG 010E 012E 012E 012E 016E 015E 013E 01BE 013E 022E 011E 010E 010E 015E 015E 010E 013E 014E 012E 009E 013E 012E 010E PAGE MER U U U U U U U U U U U U U U U U U U U U U U U S/15/94 PERMIT 69-0014-0 69-0104-0 70-0060-0 71-0015-0 75-0058-0 76-0028-0 76-0079-0 76-0080-0 77-0015-0 77-0069-0 78-0102-0 API NUMBER 029-20011-00 029-20047-00 223-20006-00 029-20099-00 029-20176-00 029-20156-01 029-20180-01 029-20233-00 029-20245-00 029~20234-01 029~20356-00 BP SUSPENDED WELLS ~RIOR TO 1980 AUGUST 1994 W~LL WELL WELL NAME CLASS STATUS SAG DELTA 31-11-16 EXP SUSP PRUD~OE BAY UNIT 33-12-13 DEV SUSP KEMIK UI~IT 1 DEV SUSP PRUDHOE BAY UNIT H-01 DEV SUSP SAG DELTA 33-12-16 EXP SUSP NIAKUK 1-A EXP SUSP NIAKUK 2-A EXP SUSP SAG DELTA 3 EXP SUSP SAG DELTA 34633 4 EXP SUSP SAG DELTA 28337 2-A EXP SUSP PRUDHOE BAY I/NIT TERM C DEV SUSP STATUS DATE 4/28/69 12/20/69 6/17/72 6/22/71 4/28/76 4/30/76 3/30/77 3/23/77 3/22/78 12/27/77 4/25/79 SECT 31 33 17 21 04 26 26 35 35 10 03 TWP 11N 12N 01N 11N 11N 12N 12N 12N 12N llN 11N RNG 016E 013E 020E 013E 016E 015E 015E 016E 016E 016E 012E PAGE MER U U U U U U U U U U U Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 November 6, 1984 Mr. Jim Trimble Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-I, A-2, B-I, B-2, B-3, B-4A, B-5, C-l, C-2, C-3, D-I, L-I, M-lA, N-lB, and Gwydyr Bay State 2A. Ail of the above are classified suspended wells. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the wells are suspended. Please contact Jim Dosch at 279-0611 if you have any questions. You_rs very truly,, / /~anager of Alaskan Operations JTD/ks Attachments RECEIVED NOV o g Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASI~, "'~blLAND GAS CONSERVATION ')MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 81-142 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50- 029-20662 4. Location of Well 5278' FSL, 4304' FEL, Section 19, T13N, RllE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) GL=24' KB=46' 12. I 6 . Lease Designation and Serial No. ADL 47438 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point B-2 11. Field and Pool Kuparuk Fiel.d Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other E~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year as long as the status of the well is suspended. This well is currently completed in the Upper Cretaceous interval. An engineering evaluation is currently geing conducted on this formation and this well will be held suspended pending results of the evaluation. 14. I hereby to the best of my knowledge. Manager of Alaskan Oporat'ions Signed ~ A~hZ ~v~-"~~.,~ Title The space b~5~ for Commission use Conditio~to~Approval, if any: Date 9-26-84 By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMO TO: ~HRU ,. FROM: RA". )DUM Sta+i.') of Alaska ALASK~I~AND GAS CONSERW~TION COMMISSION ~ /,! C. V~ q~t)zrton - OATm August 22, 1984 Chai~ ntE,e D. 3I. 52 Lonnie C. Smith ~~ Co--is s loner~ TELEPHONE N~ Bobby Fos ter~. Petrole~ Inspector SUBJECT: Inspect Suspended Wells and Locations at Conoco Sites. Thursday, August 16, 1984: I traveled this date to Prudhoe Bay~and met with' Jerry Fritch and Jim Dosch, Conoco representatives, to' inspect the suspended drill sites and wells listed below. Gwyder' Bay 2A Milne Point N-lB Milne Point M-IA Milne Point L-1 Milne Point Pad A (4 wells)' Milne Point Pad C (4 wells) Milne Point Pad Milne Point Pad I recommend to the Commission that these wells and drill sites be accepted as suspended. _ . . Pictures attached. 02-00 lA(Rev. 10179) . Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: .o . OPera~°r' L'~)~JgPf14~ ' · ~ Date S~spended AddreSs ~5~ ~ ~. ~/~'/~. ~~~~~' Surface Lo6a~i6n 0f W~lf. ' ' ' -~ · >efmi't NO. ~/_ /~ _~ 7~ Ft. F J L, .~~. Ft. F~L API No. ~ T_~~R~ ~,~ ~M. Unit or Lease Name~~ Field & Pool Condition of Pad_ Condition' of Pits ~~~ Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard Attached to Information correct No Ye s No ~ ~o ~ No Cellar - opened Filled Covered WaterWell - Plugged off No No No Capped Ope n Rat Hole Open Yes No Fi 1 led Ye s No Covered ~ No Explanation_ . _. _ %yraph s t~/verify ab/Tve i ~ No ,~Explanaton ~ ~-/~/~ ~.2C//f %/ ~~t one . _ .... . Work to ~ done to ~ acceptable ~~ _ This well and location is le to (accemtab L (unacceptable) be classified as suspended for the 1 thru ~-/~____ 19~. Inspected by: Da te: Revised 8/24/82 Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 January 19, 1984 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: RE: Request For Milne Point Unit D No. 1 Registered Survey Plat (1/10/84) Request For Inclination Survey (1/10/84) Please find attached; a Registered Survey Plat for Milne Point Unit Well D No. 1, and a list of all Single Shot Surveys run in Milne Point Unit B No. 2, as requested by the referenced letters. We regret that this information was not submitted earlier, and we will strive to prevent such oversights in the future. Your~ ~ery truly, R. J. Francis Manager - Engineering JBF/km Cc: Milne Point Unit D No. 1 Well File, w/Encl. Milne Point Unit B No. 2 Well File, w/Encl. MILNE POINT UNIT B NO. 2 SINGLE SHOT DIRECTIONAL SURVEYS Measured Deviat ion Depth (RKB) Degrees 500' 908' 1400' 1816' 1° 2248' 3/4° 2720' 3/4° 3194' 3/4° 3700' 1° 4215' 4700' 2-3/4 Surface Location: 5278' FSL, 4304' FEL, Sec. 19, T13N, RllE, UM. ALASKA OIL AND GAS CONSERVATION COMMISSION' Bill Sheffield Governor 3001 PORCUPINE DRIVE . ANCHORAGE,ALASKA 99501'-3192 TEL EPHONE (907) 279,- 1433 We wish to bring to your attention that the Commission has .not yet received the following required items on the subject well which our recordS indicated was completed ._~--~ ~-~c~, Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, C. V. Chat~ Chairman H. D. Haley Manager of Alaskan Operations Conoco Inc, 2525 C Street Suite 100 Anchorage, AK 99503 October 17, 1983 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble: Attached are completed 10-403 forms for Milne Point A-i, A-2, B-I,~B'~2~ B-3, B-4A, C-i, C-2, C-3, C-4, D-I, and Gwydyr Bay State #2A. Ail of the above are classified as suspended wells, and Conoco will be contacting one of your representatives to conduct an inspection of these wells each year as long as the wells remain under this status. Also attached is a completed 10-407 form requesting a change in status for Milne Point B-5 from plugged and abandoned to suspended. You will also find photographs enclosed covering the cleanup operations that took place subsequent to this year's inspection of Gwydyr Bay State #1 and #2A. Photographs are also included that show the new signs mounted on Milne Point C-4 and D-2A. Please contact J. T. Dosch if additional information is necessary or if you should have any questions. H. D. I-Ialey Manager of Alaskan Operations JTD/kp cc: A. E. Hastings, Anchorage ') STATE OF ALASKA . ~') ALASKA OIL AND GAS CONSERVATION COI~IMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLX]~ OTHER [] 2. Name of Operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchorage, Alaska 99503 4. Location of Well 5278' FSL, 4304' FEL, Sec.. 19, T13N, R11E, U:M. 5. Elevation in feet (indicate KB, DF, etc.) KB= 46"'_, GL=24' 12. 6. Lease Designation and Serial No. ADL 47438 7. Permit No. 81-142 8. APl Number 50-029-20662 9. Unit or Lease Name Mi!ne Point Unit 10. Well Number Milne Point B-2 11. Field and Pool Kuparuk Field (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other . 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one.year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year until the well has a plugged and abandoned status. 14. I hereb~,,~t~lat ~'¢yoregoing i,s true and correct to the best of my knowledge. S~g,ed ~"./"" ~Z//~/~~~,~..C..__ ~ T~t~e Manager of Alaskan Operations Date The space be~o~'~or Commission use H. i~.' Hal ey 10-19-83 Conditions of Approval, if any: Approved by Ot~IG':#AL 8Y LONHIE ~. SMIT! Approved Copy Returned ~!0 -~0-~3 .... By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate H. D. Haley Manager of Alaskan Operations October 1, 1982 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 Mr. Jim Trimble Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Trimble' Attached are completed 10-403 forms for- Milne Point A-l, B-l, ,~.~Bm.2~ B-3, B-4A, C-1, C-3, D-l, Kavear~k Point 32-25; and Gwydyr Bay State #2A. All of the above are classifi.ed as suspended wells and Conoco will be contacting one of your representatives to conduct an inspection each year until the wells have a plugged and~..abandoned status. Also attached is a completed 10-407 form requesting a change in status for Gwydyr BaS State #1 from suspended to plugged and abandoned. You will also find the photographs you requested concerning the recent inspections of Gwydyr Bay State #1, #2A, and Milne Point A-1. Please contact J. T. Dosch if additional information is necessary or if you should have any questions. Yours very truly, H. D. Ha ley Manager of Alaskan Operations Ol, D/tt cc- G. A. Merriman - w/o attachments A. E. Hastings - w/o attachments iL STATE OF ALASKA "~) ALASKA AND GAS CONSERVATION CC,, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 81-142 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50_029-20662 4. Location of Well 5278' FSL', 4304' FEL, Sec. 19, T13N, R11E, UM 5. Elevation in feet (indicate KB, DF, etc.) KB-46 ' GL=24' 12. I 6 . Lease Designation and Serial No. ADL 47438 9. Unit or Le~se Name Nilne~Point Unit 10. Well Number Milne Point B-2 11, Field and Pool Kuparuk Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other Y~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Request one year extension for a suspended well. Conoco will contact one of your representatives to conduct an inspection each year until the well has a plugged and abandoned status. 14. I hereby ce~~ ~?u~and correct to the best of my knowledge. Signed ,/'~/ ~ / V'~-~[-~---~ Title Manager of Alaskan Operations The space below for Commission use ~ Conditions of Approval, if any: .__,/ Approved Copy An inspection will be necessary by August 1983. Returned / /_ .v ,' ~y W. KUGLER By Order of Approved by ' COMMISSIONER the Commission Date 10-6-82 Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Conoco Inc. 2525 C Street Suite 100 Anchorage, Alaska 99503 September 21, 1983 Mr. Bill Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: In accordance with A.O.G.C.C. Regulations, Article 6, Section 536, please find attached a complete set of core samples from the Milne Point Unit Well B No. 2. This set consists of 748 core samples from the following intervals: Box No. 1 Box No. 2 Box No. 3 Box No. 4 Box No. 5 Box No. 6 Box No. 7 Box No. 8 Box No. 9 Box No. 10 Box No. 11 Box No. 12 Box No. 13 Box No. 14 Box No. 15 Box No. 16 3700'-3720', 3729'-3752', 3757'-3779' 3780'-3784', 3787'-3810', 3816'-3822', 3824'-3853' 3854'-3865', 3876'-3899' 3900', 3902',3914'-3938', 3947'-3966', 3976'-3988' 3989'-3995', 3999', 4004'-4026', 4036'-4040', 4042'-4043', 4045' 4066'-4081', 4096'-4112' 4113'-4127', 4129'-4134', 4136', 4138'-4153', 4155'-4170' 4171'-4177', 4179'-4180', 4184'-4201', 4215'-4219, 4221'-4230' 4231'-4240', 4245'-4253', 4265'-4268', 4274'-4279', 4281'-4283' 4284'-4297', 4302', 4304'-4326', 4332'-4333' 4334'-4344'. 4346'-4370' 4371'-4380', 4383'-4396', 4398'-4418', 4420'-4426' 4427'-4445', 4447'-4487', 4489'-4490', 4492'-4499' 4500'-4507', 4509'-4526', 4529'-4551', 4571'-4575' 4576'-4587', 4599'-4622' 4623'-4660' Each core sample has a volume of at least one cubic inch and is packaged in a labeled cloth bag. It is our understanding that these core samples will be handled as confidential material for the remainder of the 24-month Confidentiality Period. RECEIVED Alaska Oil & Gas Cons. CommiSSion Anchorage ~~tea~e acknowledge receipt and content of this material by signing and returning the attached copy of this letter in the enclosed envelope. If you have any questions, please contact either Jim Fox or myself at 279-0611. Very truly yours, R. J. Francis Manager - Engineering JBF/kr Attachment RECEIVED Alaska OiJ & Gas Cons, Commission Anchorage MEMORANDUM State of Alaska ALA~) ~OIL-' AND GAS CONSER~TION COMMISSION C.- -~.~~t~prton DATE: September 2., 1983 TO: Ch~" '"~~ ' FILE NO: 108A:J6 TF~RU: Lonnie C. Smith J?'"~ Commissioner TELEPHONE NO: FROM: Earold R. Hawkins Petroleum SUBJECT: Cleanup Inspection for E~ension of: S~pended Status, Conoco, Milne Point B-2, Sec 19, TI3N,RllE, Permit No. 81~42. Wednesday .Au.gust 17, 198 .. I finished inspecting Milne Point No. B-l, subject of another report and inspected Conoco's Milne Point No. B-2, for extension of suspension. I took a picture for verification. I filled out an A.O.G.C.C. report which is attached to this report. In summary., I inspected Conoco's Well No. B-2 at Mi. lne Point. I found the pad clean and level, no debris, the well sign and well in good condition. This well is satisfactory for extension of suspension. Attachments 02-00IA(Rev. 10/79) Suspe d Wel, 1 and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: Operator Addre s s Surface Location of Well Sec.,./y, T~ ~, R~ ~ , ~ M. Da te Suspended Permit No. F ,~ L API No. Unit or Lease Name Wel 1 No. Field & Pool Condition of pad _~r~_,~.,.~D _ Well head - Ail outlets plugged Well sign - Attached to well head ' A,ttache:d .to~ ,well. guard .Attached to Information correct No Ye s No ~ No No Cellar - Wa t e rWe 11 Opened Yes No Rat Hole Ye s No · -Plugged off Cappod Open Explanation Open Fi 1 led Covered Yes ~ Ye s No Ye s No Photographs taken to verify above conditions No' Explanaton ~. ~_~_ .P.~. ~ ~_~ r~_ ¢~~'~ .... ,~ ~z~_ _~-~, ~- ..... Work to be done to be acceptable /t;?__~../~_._~_ This well and. location is (unacceptable) to suspended fOr the period of-- ~ 19, , thru Inspected by: ° ~ Revised 8/24/82 be Classified as 19 . ? ~COt"tOCO~ 'C~°noco Inc. Geophysical Section 'ecord of Shipment of Confidential Information Date JUL,,"/ 7~ /'~ a~ [] Under Separate Cover [] Enclosed Via Quantity I ~E'e~ A ( Contents F~G.-/:= ht~TC,~AC GA~t~,t'~,'i~'f Too .,~ <~c..: 2 ,__/00' · ~ /00/ RECEIVED J U L - 8 t982 Transmittal Approved By Signed By Date Instructions: PJease a~cknowledge r?,~,j~romp~by signing and ?turning carbon copy. Received B~. ~ ~" 7~/,,'~' -,,.~_. ///~_ Date Remarks AlasKa Oii & Gas Cons. Commission Anchorage Transmittal Copy Only To 13-98 PCX1. 7-79 PRINTED IN U.S.,m, O~onocolnc. Geophysical Section To From C')lecord of Shipment of Confidential Information [] Under Separate Cover [] Enclosed Subject Via Quantity Contents 700 / Transmittal Approved By TV LoG, J U L - 8 1982 Alaska Oil & Gas Cons, ComrnJssi0n Anchorage Signed By Date Instructions: Please acknowledge receipt promptly by signing and returning carbon copy. Received By /~ /'""'//~. ~ ~ Date Transmittal Copy Only To 13-98 PCXl, 7-79 NORICK OKLA, CITy PRINTED iN U.S.A. July 8, 1982 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 K Mr. William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen' Enclosed are an original and copy of the Well Completion Report and Log for Milne Point B-2. In addition, the required logs are being submitted with this letter along with a transmittal list. . As I discussed with you in a telephone conversation on July 6, 1982, we will attempt to submit the core chips for this well by September 19, 1982. The cores are in PVC pipe, and the core chips will be taken when all of the core plugs for engineering data have been obtained. If you have any qUestions concerning the Completion Report and Log or the materials being submitted, please contact either Jim Fox or Mike BradshaW at 279-0611. Yours very truly, Gary A. Merriman Supervising Production Engineer kp Enclosures t EC£1vED JUL -- 8:1982 Alaska Oil & Gas Cons. Com. m~sszon 'qnchorage ... ALASKA O,~'AND GAS CONSERVATION OIL [] GAS ~ SUSPENDED I~ ABANDONED [] SERVICE [] 2. Name of Operator Conoco Inc. 3. Address 2525 C Street, Suite lO0, Anchorage, Alaska 99503 4. Location of well at surface 5278' FSL, 4304' FEL, Sec. 19, T13N, RllE, U.M. At Top Producing Interval Same (Vertical Hole) 7 Permit Number 81-142 8. APl Number 50-029-20662 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point B-2 At Total Depth Same (Vertical Hole) · 5. Elevation in feet (indicate KB, DF, etc.) 6. Lea]:~e Designation and Serial No. KB=46' GL=24' '. ADL 47438 12. Date Spudded /13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 12/3/81 [ 12/28/81 I 5/27/82 1 7. Total Depth (MD+TVD) |18, Plug_~,ack Depth (MD+-FVD)I 19. Directional Survey 20. Depth where SSSV set 4700' (MD+TVD)/~rlu§e 1 / PI ug ~ 40!7' MI') I YES [] NO ~ NA feet MD 22. Type Electric or Other Logs Run DLL/GR; FDC/CNL/NGT; MLL/ML; BHCS/GR; ML/PROX; DIL/GR; RFT 11. Field and Pool Kuparuk River Fi eld ~ Prince Creek/Schrader Bluff Po.91 16. No. 15. Water' Depth, if offshore ~ of Completions NA feet MSL/ / 2 '1' 21. Thickness of Permafrost 1800+' 23. CASIN( CASING SIZE, WT. PER FT. 20" i 94# ' 13 3/8" 72# 9 5/8" 47# GRADE H-40 SETTIN( TOP 1 L-80 0' L-80 0' , LINER ANDCEMENTIN( DEPTH MD BOTTOM 103" 2234' 4700' 24, Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 4372' -4402' MD (30') 12 JSPF, 0.7" Hole ent. Diameter 4464' - 4490' MD (26') 12 JSPF, 0.7" Hole ent. Diameter 4518' - 4542' MD (24') 12 JSPF, 0.7" Hole ent. Diameter HOLE SIZE 26" 17½" 12¼" RECORD CEMENTING RECORD AMOUNT PULLED ement to surface O' ~400 sx Arctic set I 600 sx Class "G" 150 sx Arctic set 130 BBL Arctic pack 25. 'TUBING RECORD SIZE ]DEPTH SET (MD) az,, , .' ITRs 3938' =.2...~ 11 2#, O! OI PACKER SET (MD) g~ 401 7I ,... ~ ~.. .... 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 4462' - 4542' 20-40 qravel pack/O.O12" gauge wire wrap screen 27. PRODUCTION TEST - See Attached Sheet Date First Production Date of Test Hours Tested Casing Pressure Flow Tubing Press. J Method of Operation (Flowing, gas lift, etc.) IPRODUCTION FOR OIL-BBL GAS-MCF ICALCULATED . OIL-BBL GAS-MCr I:4-.OUR.RATE WATER-BBL WATER-BBL 28. CORE DATA ICHOKESIZE IGAS'OILRATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Attached Sheet · Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. "' I 30, ' GEOLOGIC MARKERS T ~..~:~ ~,.,.;.,-'~.~7 iL;':~, ~'~:.-i,'~' !i.: NAME . Include interval tested, pressure data, ali i~uid~, ~_;cu'~rec~ arid gl'av~ty, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Pr~nce Creek 1938' _ Schrader B1 uff 3264' - 'NC' Sand 4376' - See Attached Sheet '0A' Sand 4464' - " 'OB' Sand 45t8' - " Seabee 4677' _ 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 2~!: If this well is complete.d for separate production from more than one interval (multiple completion), so state in item 16, and in i'~em 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- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". MILNE POINT NO. B-2 WELL COMPLETION REPORT AND LOG 27. PRODUCTION TEST DATA PRODUCTION TEST DATA Listed below are representative test data on the intervals tested in Milne Point B-2. Interval Tested (M.D.) Date of Test Method of Operation 4518'-4542'/ 4518'-4542' 4464'-4490' 4464'-4490' 2/4-6/82 2/13-14/82 3/28-30/82 Swab Test Swab Test Downhole Jet pump 32.0 13.1 34.5 29 30 60 NA NA NA 55 37 391 NA NA NA Full Open Full Open Full Open 128/64" 128/64" 128/64" 2080-570 1575-1876 1480-385 1870 1874 Hours Produced Oil Produced (BBL) Gas Produced (MCF) Water Produced (BBL) OOR (CF/BBL) Choke Size Flowing Bottomhole Pressure Final Buildup Pressure (PSIG) 1710 Average Production Rates: BOPD 22* BWPD NIL MCFD NA Oil Gravity (°API) 14° 55* 42 NIL NA NA NA 17 o 16 o *Average flow rate over entire test period. No instantaneous or maximum flow rates available. -1- J U L - 8 (,CFIS, Alaska Oil & Gas MILNE POINT NO. B-2 WELL COMPLETION REPORT AND LOG 27. PRODUCTION TEST DATA (Continued) PRODUCTION TEST DATA Listed below are representative test data on the intervals tested in Milne Point B-2. Interval Tested (M.D.) Date of Test Method of Operation Hours Produced 4518'-4542' 4518'-4542' 4464'-4490' 4464'-4490' 3/31-4/2/82 4/4-7/82 Downhole Downhole Piston Pump Piston Pump 51.3 88 Oil prOduced (BBL) Gas Produced (MCF) Water Produced (BBL) ooR (CF/BBL) Choke Size Flowing Bottomhole Pressure 170'* 270** NA NA 138 4 NA 0.180'* 4518 '-4542 ' / 4464 ' -4490 ' 4/15-16/82 Swab in & Flow Final Buildup Pressure (PSIG) N/A Average Production Rates: BOPD 80** 74** BWPD 65 1 MCFD NA 13 Oil Gravity (°API) 16'* 16'* 24.8 Total Production Time 14.8' 39* NA 12' Full Open Full Open Full Open 128 / 64" 128 / 64" 128 / 64" 10-480 100-980 1073-1963' 1370 1836 30* 6* NA 14.6 * This value is for the stabilized flow period only. ** Corrected for power fluid contamination (factor= 0.25) TIAL I ECE[. VED JUL - ~ -2- MILNE POINT NO. B-2 WELL COMPLETION REPORT AND LOG 27. PRODUCTION TEST DATA (Continued) PRODUCTION TEST DATA Listed below are representative test data on the intervals tested in Milne Point B-2. Interval Tested (M.D.) Date of Test Method of Operation Hours Produced Oil Produced (BBL) Gas Produced (MCF) Water Produced (BBL) GOR (CF/B~L) Choke Size Flowing Bottomhole Pressure 4372'-4402' 4372'-4402' 4372'-4402' 4372'-4402' 4/23-24/82 4/25 4/26 4/27 Downhole D°wnhole Downhole Downhole Jet Pump Jet Pump Jet Pump Jet Pump 16.8 6.5 7.4 16.4 NA 44 48 321 NA NA NA NA NA 10 42 172 0.250 0.050 0.040 0.048 Full Open Full~ Open Full Open Full Open 128/64" 128/64" 128/64" 128/64" NA 1490-1605 1486-1690 1500-1355 1788 1817 1574 Final Buildup Pressure (PSIG) NA Average Production Rates: BOPD 28* BWPD 71 MCFD 7.6 Oil Gravity (°API) 16.2 162 262* 434 37 136 252 8.2 10.7' 21.* 16.4 NA NA * Average of instantaneous rates. -3- MILNE POINT NO. B-2 WELL COMPLETION REPORT AND LOG 27. PRODUCTION TEST DATA (Continued) PRODUCTION TEST DATA Listed below are representative test data on the intervals tested in Milne Point B-2. Interval Tested (M.D.) Date of Test Method of Operation Hours Produced Oil Produced (BBL) Gas Produced (MCF) Water Produced (BBL) OOR (CF/BBL) Choke Size Flowing Bottomhole Pressure 4464'-4490' 4372'-4402' 4372'-4402' 4518'-4542' 5/5-10/82 5/11-13/82 5/20-21/82 Downhole One Swab Run Downhole Jet Pump & Flow* Jet Pump 68.7 23.8 31.7 427 NA 23 NA NA NA 25 NA 171 NA NA 0.250 Full Open Full Open Full Open 128/64" 128/64" 128/64" 1425-1560 1502'*-1865'** 80-1047 1764 1751 Final Buildup Pressure (PSIG) 1818 Average Production Rates: BOPD 149.2 BWPD 9 MCFD NA Oil Gravity (°API) 16.5 123 17 31 129 NA 3 16.5 16 * Well was flowed primarily to obtain downhole fluid samples. ** Low flowing pressure due to swabbing. *** Suspected pressure communication from annulus to tubing. -4- Core Number & Footage Lithology MILNE POINT UNIT B-2 CORE DATA Porosity Fractures & Apparent Dip Presence of O, G, or W Core #1 3700-3728 Claystone (57%) Coal (33%) Siltstone (10%) Poor-Fair Apparent dip Poor is horizontal Poor-Fair None Core #2 3728-3757 Claystone (42%) Sandstone (21%) Coal (21%) Siltstone (16%) Fair V. Good Poor Fair Core #3 3757-3787 Claystone (30%) Shale (30%) Coal (19%) Lignite (15%) Siltstone (6%) Fair Poor Poor Fair Fair Apparent dip in upper 24' of core is horizontal. The lower 2.8' dis- plays poorly-defined parting planes which dip about 10°. Core #4 3787-3816 Sandstone (88%) Claystone (8%) Shale (4%) V. Good Fair Poor Parting planes dip about 10°. Scattered bleeding of viscous oil; good shows. Core #5 3816-3846 Shale (84%) Claystone (10%) Siltstone (6%) Poor Fair Fair Parting planes dip about 10°. A single fracture which dips about 10° was present in a siltstone layer. None Core #6 3846-3876 Shale (40%) Sandstone (35%) Claystone (20%) Siltstone (5%) Poor Good Fair-Poor Poor Parting planes as above. Scattered bleeding of Viscous oil is associated with sand- stone layers. Good shows in sandstone. Core #7 3876-3906 Sandstone (41%) Shale (41%) Claystone (14%) Siltstone (4%) V. Good Poor Fair-Poor Fair Parting planes dip about 10°. -5- Viscous oil is associated with sand- stone layers. Shows are good to fair. Core Number & Footage Lithology Porosity Fractures & Apparent Dip JUL A,~aska Oil & Gas Cert~. ..... Presence of O, Core #8 3914-3944 Sandstone (52%) Claystone (24%) Siltstone (12%) Shale (12%) V. Good-Fair None reported Fair-Poor Fair-Poor Poor As above Core #9 3946-3976 Sandstone (52%) Claystone (24%) Siltstone (19%) Shale (5%) V. Good Fair-Poor Poor-Fair Poor None reported As above Core #10 3976-4004 Claystone (60%) Sandstone (30%) Siltstone (10%) Poor Good-Fair Poor None reported As above; shows are fair. Core #11 4004-4036 Sandstone (65%) Siltstone (17%) Claystone (9%) Shale (9%) V. Good Fair Poor-Fair Poor None reported As above; shows range from good to poor. Core #12 4036-4066 Sandstone (100%) Good Horizontal As above; shows are good. Core #13 4066-4096 Sandstone (62%) Siltstone (19%) Shale (13%) Claystone (6%) V. Good Poor-Fair Poor Poor Parting planes are horizontal. As above; shows range from good to poor. Core #14 4096-4125 Shale (59%) Sandstone (27%) Siltstone (7%) Claystone (7%) Poor Good-Fair Fair-Poor Poor Apparent dip is horizontal. As above Core #15 4125-4155 Sandstone (100%) V. Good As above Minor amounts of oil associated with sand- stone layers; shows are fair. Core #16 4155-4184 Sandstone (92%) Siltstone (4%) Shale (4%) V. Good-Fair None reported -6- As above Core Number & Footage Lithology Porosity Fractures & Apparent Dip J U L - 8 ~,,' ~,~"~:~,,k~'~ Oil & Gas Cons~ Commission Presd~n~0r~ O, G, or W Core #17 4184-4214 Sandstone (50%) Shale (28%) Siltstone (17%) Claystone (5%) Good-Poor Poor Poor Poor None reported As above; shows are good-fair Core #18 4215-4245 Sandstone (92%) Siltstone (4%) Claystone (4%) V. Good Poor Fair None reported As above Core #19 4245-4274 Sandstone (100%) V. Good Apparent dip is horizontal As above; shows are fair. Core #20 4274-4302 Sandstone (96%) Claystone (4%) V. Good As above As above Core #21 4302-4332 Sandstone (40%) Shale (40%) Siltstone (16%) Claystone (4%) V. Good Poor Poor Poor As above As above; shows range from fair to good Core #22 4332-4361 Claystone (73%) Sandstone (23%) Siltstone (4%) Poor Poor Poor As above Moderate amounts of viscous oil are present in sandstone layers; shows range from good to fair. Core #23 4361-4390 Claystone (54%) Sandstone (42%) Siltstone (4%) Poor As above V. Good-Poor Poor Viscous oil is present in sandstone; shows are good. Core #24 4390-4420 Sandstone (87%) Claystone (10%) Siltstone (3%) V. Good-Poor Poor Poor As above As above Core #25 4420-4450 Shale (47%) Siltstone (23%) Claystone (17%) Sandstone (13%) Poor Poor Poor Poor As above Minor amounts of viscous oil are present in sandstone layers; shows range from good to fair. -7- Core Number & Footage Lithology Porosity Fractures & Apparent Dip Presence of O, G, or W Core #26 4450-4480 Claystone (40%) Siltstone (30%) Sandstone (27%) Shale (3%) Poor Poor Good-Fair Poor As above As above; minor amounts of viscous oil are present in sand- stone layers; shows range from good to fair. Core #27 4480-4509 Claystone (38%) Siltstone (35%) Sandstone (27%) Poor Poor Cood-Poor As above Viscous oil associated with sandstone layers; shows range from fair to good. Core #28 4509-4540 Sandstone (53%) Claystone (44%) Siltstone (3%) Good-Fair Poor Poor As above As above Core #29 4540-4570 Claystone (73%) Sandstone (27%) Poor Fair-Poor As above As above Core #30 4570-4596 Claystone (100%) Poor As above. Frac- tures w/ slicken- sides wL/dip 45°. Minor amounts of oil, shows are fair to poor. Core #31 Shale (84%) 4599-4629 Sandstone (16%) Poor Poor-Fair Apparent dip angle As above is horizontal. Core #32 4629-4659 Shale (100%) Poor None reported None -8- IAi WELL HISTORY MILNE POINT NO. B-2 - CONOCO ET. AL. API NO. 50-029-20662 DATE OPERATIONS 11-21-81 to 12-2-81 12-3-81 12-3-81 to 12-5-81 12-6-81 to 12-7-81 12-8-81 12-9-81 to 12-12-81 12-13-81 to 12-15-81 12-16-81 to 12-28-81 Move in and rig up drilling rig and support facilities. Set conductor pipe (20", 94#/ft., H-40) at 103' KB. Spud well a 0100. Drill 17~" hole from conductor shoe to 1816'. Drill 8~" hole from 1816' to 2248'. Run the following logs: FDC/CNL/NGT - 2242' to 110' BHCS/GR - 2249' to 110' DIL/GR - 2249' to 110' ML/Prox - 2242' to 1800' Ream 8~" hole to 17~" hole from 1816' to 2248'. Run 13 3/8", 72#/ft., L-80, BTRS casing from 2234' to surface, cement with 4400' sks of Arctic Set II (15.0 ppg.), and circulate to surface. Wait on cement. Drill out cement and test casing. Drill 12¼" hole from 2274' to 3700'. Core No. 1 - Core from 3700' to 3728'; recovered 20.4' of 3~" core. Core No. 2 - Core from 3728' to 3757'; recovered 23.5' of 3~" core. Core No 3 - Core from 3757' to 3787' recovered 26.8' of 3¥' core. Core No. 4 - Core from 3787' to 3816'; recovered 23.6' of 3½" core. Core No. 5 - Core from 3816' to 3846'; recovered 30 5' of 3~" · 2 core. Core No. 6 - Core from 3846' to 3876'; recovered 20.6' of 3½" core· Core No. 7 - Core from 3881' to 3914'; recovered 26.6' of 3~" core. -9- WELL HISTORY Milne Point No. B-2 Page 2 12-16-81 to 12-28-81 (Con't) Core No. 8 - Core from 3916' to 3946'; recovered 24.8' of 3½" core. Core No. 9 - Core from 3946' to 3976'; recovered 20.4' of 3~" core. Core No. 10- Core from 3976' to 4004'; recovered 19.2' of 3~" core. Core No. 11- Core from 4004' to 4036'; recovered 23.0' of 3~" core. Core No. 12- Core from 4036' to 4066'; recovered 9.7' of 3½" core. Core No. 13- Core from 4066' to 4096'; recovered 16.0' of 3~" core. Core No. 14- Core from 4096' to 4125'; recovered 28.7' of 3½" core. Core No. 15- Core from 4125' to 4156'; recovered 28.8' of 3~" core. Core No. 16- Core from 4156' to 4185'; recovered 26.0' of 3~" core. Core No. 17- Core from 4185' to 4215'; recovered 18.2' of 3~" core. Core No. 18- Core from 4215' to 4245'; recovered 26.2' of 3~" core. Core No. 19- Core from 4245' to 4274'; recovered 24.7' of 3~" core. Core No. 20- Core from 4274' to 4302'; recovered 24.3' of 3~" core. Core No. 21- Core from 4302' to 4332'; recovered 24.4' of 3~" core. Core No. 22- Core from 4332' to 4361'; ~',-~ a core. Oil & Ga~) ~,,~ s. Coitt~l~!ssio~ recovered 29.0' of 3~" Core No. 23- Core from 4361' to 4390'; recovered 26.8' o£ 3~" core. Core No. 24- Core from 4390' to 4420'; recovered 26.8' of 3~" core. -10- WELL HISTORY Milne Point No. B-2 Page 3 12-16-81 to 12-28-82 (Con't) 12-29-81 to 12-30-81 12-31-81 to 1-1-82 1-2-82 1-3-82 Core No. 25- Core from 4420' to 4450'; recovered 28.0' of 3~" core. Core No. 26- Core from 4450' to 4480'; recovered 30.0' of 3½" core. Core No. 27- Core from 4480' to 4509'; recovered 27.0' of 3~" core. Core No. 28- Core from 4509' to 4540'; recovered 30.5' of 3½" core. Core No. 29- Core from 4540' to 4570'; recovered 12.0' of 3½" core. Core No. 30- Core from 4570' to 4596'; recovered 17.5' of 3½" core. Core No. 31- Core from 4599' to 4629'; recovered 30.5' of 3~" core. Core No. 32- Core from 4629' to 4659'; recovered 30.0' of 3½" core. Drill 8~" hole from 4659' to 4700'. Run the following logs from TD (loggers TD = 4694') to the 13-3/8" casing shoe (Loggers csg. point 2227'): FDC/CNL/NGT - NGT run from TD to 1700' only DLL/GR ML/MLL BHCS/GR Ran a wiper trip to condition hole and then ran a RFT tool at selected intervals. Ream 8½" core hole to 12¼". Run 9-5/8", 47#/Ft, L-80 BTRS. casing with shoe at 4700' and 5 external casing packers at the following depths: 4558', 4508', 4459', 4350' and 4096'. Pump preflush before 600 sks. Class "G" with 12% D-53, 0.6% D-59, and 0.2% D-46 (@15.2 ppg). Set packers, open D.V. tool (@2115'), circulated through D.V., pump 100 bbl water spacer, 130 bbl of Arctic Pack, 150 sks. of Arctic Set cement and displace with diesel. Nipple down BOPE, install 13-5/8" tubing spool, and test. Release Parker rig #128 at 1300 hrs. and temporarily suspend operations. -]]- CO FI ENTIAI. WELL HISTORY Milne Point No. B-2 Page 4 1-4-82 to 1-8-82 1-14-82 to 1-26-82 Rig down, move out drilling rig. Move in, and rig up completion rig and support facilities. 1-27-82 to 1-28-82 Nipple up and test BOPE. Re-enter wellbore. 1-29-82 to 2-1-82 2-2-82 Drill out cement to 4605'. Displace drilling fluid with KC1 completion fluid and condition. Run GR/CBL/VDL/CCL log from 4568' to 96'. Perforate from 4518' to 4542' with Schlumberger 4" casing gun at 12 jpf, and 0.7" entry hole size. 2-3-82 Run in hole with 3~" tubing and test equipment and set packer at 4394'. Install surface test equipment. 2-4-82 to 2-6-82 Swab well in for approximately 32 hours (41 swab runs). Swabbing was discontinued when a sand bridge was encountered at 3200'. A down- hole valve shut-in the test string to initiate a 24-hour pressure buildup test. Fluid level started at the surface (KC1 load water) on the first run and was drawn down to a minimum of -3000' by swab run no. 33. Oil returns were noticed after 4 hours (9 swab runs). 84 barrels of fluid were recovered of which 55 barrels were free water. The 29 barrels of oil ranged from 30% to 6% water. An additional 6.5 bbls. of oil was recovered when the test string was reversed out. 2-7-82 to 2-8-82 Recover test string, clean out fill in well bore from 4506' to 4605' (TD), run gauge ring and junk basket to 4577' (top of fill). Run in and set bridge plug at 4510'. Release workover rig and temporarily suspend operations. 2-9-82 to 2-10-82 Rig down, move out rig. 3-8-83 to 3-10-82 Move in and rig up completion rig and support facilities. 3-11-82 3-12-82 Run in hole with 3~" drill pipe and circulate hole clean to top of bridge plug @ 4505'. · ,.~,.~.,~,~ Rig up Schlumberger and perforate casing from 4464' to 4490' using 4" hollow carrier guns with 12 j spf and 0.7" entry hole size. -]2- WELL HISTORY Milne Point No. B-2 Page 5 3-13-82 to 3-14-82 Run in hole with drill stem testing assembly and set packer at 4350'. Open APR valve and swab for 3½" hours. Close APR valve to shut-in well for 16.5 hours for bottomhole pressure buildup. Attempt to swab well, swab stuck in hole at 340'. Recover swabbing tool and pull test equipment out of the hole. 3-15-82 Run in hole with drill bit and drill up retainer at 4505'. Run in and set EZSV retainer at 4545'. Pressure test retainer. 3-16-82 to 3-17-82 Make a bit and scraper run and circulate hole clean. Run in hole with wash tool and wash perforations from 4464' to 4490' and from 4518' to 4542'. 3-18-82 Run in hole with gravel pack assembly, 30' of blank liner, and 90' of 0.012" gravel pack screen. Set packer at 4407'. Gravel pack zones from 4462' to 4490' and from 4518' to 4542' using 25 bbl. of 20/40 mesh gravel slurry. Pull gravel packing equipment out of hole. 3-19-82 to 3-22-82 Rig up surface production equipment and run in hole with the downhole production equipment (Kobe pump cavity and seal assembly) and production strings (4~" BTRS casing, 2-1/16" Hydrill tubing, 2-7/8" tubing and ¼" bubble tube). 3-23-82 to 3-26-82 Latch into packer at 4406', space out tubing and land tubing hanger. Nipple up landing spool, BOPE, and surface test equipment. 3-27-82 Condition pump power fluid in surface storage tank, drop standing valve, circulate down 2-7/8" tubing and return up 2-7/8" x4~" annulus. 3-28-82 to 3-30-82 3-31-82 to 4-2-82 Drop Kobe jet pump and pump well fluids. Jet pump replaced once due to plugged ports. Retrieve jet pump, shut in well for bottomhole pressure build up, and circulate power fluid. Drop Kobe "Type B" piston pump and pump well using the 2-7/8" x 4½" annulus for fluid production and the 2-7/8" and 2-1/16"' tubing for power fluid in and power fluid return respectively. Piston pump was replaced twice WELL HISTORY Milne Point No. B-2 Page 6 during this test. 4-3-82 Circulate tubing strings clean, retrieve standing valve, and displace 25 barrels and 15 gallons of Dowell Free-Flow surfactant into gravel pack/formation and shut in well. 4-4-82 to 4-6-82 Drop standing valve and piston pump and pump well. 4-7-82 to 4-8-82 Shut well in for bottomhole pressure buildup. Retrieve piston pump. 4-9-82 Retrieve standing valve and end pressure build-up test. Circulate power fluid out of hole with 9.2 ppg KCL water. Rig down surface test equipment and nipple up BOPE. Run wireline casing collar log and string shot in 2-7/8" tubing, shoot string shot, back off and pull out of hole with 2-7/8" tubing. 4-10-82 Trip out of hole with 4%", 1-1/16", and ¼" tubing. Attempt to latch isolation plug into packer. Pressure test not successful. Well starting to flow while fishing out isolation plug. 4-11-82 to 4-13-82 Circulate 9.2 ppg KC1 brine to kill well. Make two additional attempts to latch into packer without a successful pressure test. 4-14-82 Run in and set 4-3/4" seals x 5-3/4" seal section with isolation plug, set in packer at 4406' and pressure test. Rig up Schlumberger and perforate casing from 4372' to 4402' with 4" hollow carrier guns, 12 jspf, and 0.7" entry hole size. 4-15-82 to 4-16-82 4-17-82 Run in hole with DST assembly and 2-7/8"Hydrill tubing and set Packer at 4264'. Swab well for 12 hours, allow to flow for two hours and shut well in. Run in hole with Schlumberger three downhole pressure samples taken from pressure fluid sampler. Three runs made and 4209' . Complete downhole pressure survey. Reverse out test. string with 9.2 ppg ECl brine and pull test equipment out of hole. 4-18-82 to 4-22-82 Run in and set 9-5/8" hydraulic packer, and seal assembly at 4202'. Run in hole with 4½" -14- WELL HISTORY Milne Point No. B-2 Page 7 tubing, 2-1/16th" tubing, and 2-7/8" tubing with pump assembly to packer seal assembly. Install and pressure test wellhead equipment. 4-23-82 Make up and pressure test surface testing equipment. Drop Kobe jet pump and start production test. 4-24-82 Shut-in well for bottomhole pressure build-up survey. 4-25-82 Pump well for a production test. Shut well in for bottomhole pressure build-up survey. 4-26-82 to 4-27-82 Retrieve and repair downhole pump/test equipment. Drop pumping/testing equipment and jet pump well for a production test. Shut well in for bottomhole pressure build-up survey. 4-28-82 to 4-29-82 Retrieve downhole pump/test equipment. Circulate hole clean with 9.2 ppg KC1 water. Pull out of hole with 2-1/16", 2-7/8", and 4~" tubing strings. 4-30-82 to 5-2-82 Run in hole with 3~" drill pipe and circulate hole clean to 4409'. Make three unsuccessful attempts at running and setting an Otis Packer using 3½" drill pipe. 5-3-82 to 5-5-82 Run in, set, and pressure test Otis Packer at 4224'. Trip in hole with 4½" tubing, seal assembly, Hewlett-Packard recording gauge, Kobe pump assembly and stab into seal assembly. Run 2-7/8" tubing. Run standing valve into 2-7/8" tubing with wireline and seat in seating nipple. 5-6-82 to 5-8-82 Drop jet pump down 2-7/8" tubing and pump well for a production test. 5-9-82 to 5-10-82 Shut well in for bottomhole pressure build-up survey. 5-11-82 5-12-82 to 5-13-82 Circulate through tubing with 9.2 KC1 brine. Retrieve downhole pump equipment and trip in hole with Kobe blanking took to isolate 4~" tubing. Make one swab run and start flowing well. Complete flow test and shut well in. Run in JUL ~8 ii~iS~ hole with Schlumberger Hewlett-Packard WELL HISTORY Milne Point No. B-2 Page 8 5-14-82 5-15-82 to 5-16-82 5-17-82 5-18-82 5-19-82 to 5-20-82 5-21-82 5-22-82 to 5-23-82 5-24-82 5-25-82 to 5-27-82 recorder, gamma ray, casing collar locator, gradiomanometer and downhole sampler. Take 4 downhole samples at 3600'±. Shoot circulation holes in 2-7/8" tubing due to inability to unseat blanking tool. Displace tubing with 9.2 KC1 brine and circulate clean. Pull H.P. gauge, 4~" tubing, and 2-7/8" tubing out of hole. Run in hole to retrieve packer and blanking plug. Circulate to kill well. Run in hole with Dowell seal assembly, 4~" tubing, Otis packer and stab into packer at 4406'. Set Otis packer at 4253'. Pull assembly out of hole due to unsuccessful pressure test and change out seals. 4~" tubing and Run in hole with electric line, , downhole test equipment. Run 2-7/8'' tubing inside 4~" tubing and nipple down BOPE. Circulate out KC1 brine with power fluid (fresh water), drop jet pump, and start production test. Complete production test. Pull 2-7/8" tubing, 4½" tubing and electric line out of the hole. Run in hole with drill pipe, latch into packer at 4282' and pull free. Circulate KC1 brine to kill well. Run in hole, latch onto and retrieve Otis packer and bottom hole assembly. Run 9-5/8" Baker Model "C" retrievable bridge plug in hole and set at 4017'. Run in hole with 4½" tubing to 2000' and displace hole with 150 bbl of diesel. Run in hole to 3938', land 4½" tubing and nipple down BOPE. Rig down, move out. STATUS OF WELL: Suspended 9-5/8" Bridge plug @ 4017' 4~" BTRS Tbg. w/retrieving head @ 3938' (NOKB) Rig KB = 16' -16- Suggested form to be inserted in each "Active:' well folder to check for timely compliance with our regulations. 0~erator, Well Name and' NumbeF Reports and Materials to be received by: ~.--~ Date Required Date Received Remarks - Completion Report Yes Well History '> Yes :Samples. _ X~_.p/ . Mud Log ~ , Registered Su~ey Plat , Su~~-.. . _Dire~ional ~ey ~,a- pi ~/~r Drill St~ Test Re~s ~~ .,. , Pr~u~ion. Test Re~s ~~. / , , , STATE OF ALASKA '" ALASK~ IL AND GAS CONSERVATION C( /IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERA/IONS · Drilling well [] Workover operation ~X 2. Name of operator 7, Permit No. Conoco Inc. 81-142 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 5o-029-20662 9. Unit'or Lease Name Milne Point Unit 4. Location of Well atsurface 5278, FSL, 4304' FEL, Sec. 19, T13N, RllE, Umiat Meridian 5. Elevation in feet (indicate KB, DF, etc.) 26' GL 10. Well No. Milne Point B No. 2 11. Field and Pool 6. Lease Designation and Serial No. ADL 47438 Kuparuk River Field Prince Creek/.SChrader 'Bluff For the Month of. May ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Continued testing the well. Rig was moved out May 25, 1982. on final report. Test results will follow 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TITLE Drlg. Superintendent DATE ~/~//¢2-.- NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 AFE 1744 AO & GCC (2) ~TO Submit in duplicate Rev. 7-1-80 N 0 R T H o ~ · 0 ~ 0 PAD B SECTION lB ~ ~, TI3N, RIlE UMIAT MER)D~AN VICINITY MAP ss¢. ,s LOCATION IN SECTION SEC. 19 W~L ! FROM NORTH LINE ,~ FROM WEST UNE I ~ 212' . ' 978' :5 : 49' 4 ; ,es' ." ': ~ROM SOUTN UNE : : OF SEC. 18 STATE PLANE COORDINATES · ............--. e--..o ....o. · WELL ~ NORTHIN6$ : EASTINSS I : 6 022 911.70 ; 572 058.98 · · · 2 ; G 02:5 121.76 : 571 989.77 ~ .1 $ 02:3 077.00 : 572 209. I0 4 ; 6 022 960.7'6 : ~7,2 2:39.11 : : : ZONE 4 · ; GEODETIC POSITIONS WELL ; LATITUOE .;..l- LONGITUDE ..o· o.... ~............ ·...· ·., ~,.. .. · .... ,.. o.... · : I : 70°28'' 22.:567," : 149°24'41.17G· · 2 : 70028' 24..4Z, 9' : 149024'4Z,.151'' · :3 : 70° 28' 23.97'8' ; 149°24' 36.7'14" 4 ! 70028. 22.832" ~ 149°24'35.86.~" · ! CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ~lO THAT ,eeeeeeee, THIS PLAT REPRESENTS A LOCATION SURVEY ,. MADE BY ME OR UNDER MY SUPERVISION, AND · r THAT ALL DIMENSIONS AND OTHER DETAILS ~ e~. ,~, p I~ ARE CORR.'O','. · . .? ~ ,, · (con ~ DRAWN '~,' DATE 5-6-82 DL FIELD BOOK 9-82 :?2,¢0 ArT*rio Boulevard, Suite 201. Anchorage, Alaska 99503 SCALE I "' 200' May 10, 1982 Conoco Inc. 2525 C Street Suite 100 Anchorage, AK 99503 Mr. Lonnie Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: SUBJECT: MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Attached are the subject reports for the month of April. Very truly yours, W. M. Haskell Administrative Coordinator SHB/kr Attachments cc: Working Interest Owners, w/Attachments RECEIVED MAY 1 2 1982 Alaska Oil & Gas Cons. Commission Anchorage MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling well [] Workover operation~ 2. Name of operator ]~1~ ~1~' ~ ~lffi i. ~m ~,,.__ _- Conoco Inc. 3. Address 2525 C Street, Suite 100 Anchorage, Alaska 4. Location of Well atsurface 5278' FSL, 4304' FEL, Sec. 19, T13N, TllE ADL 47~38 99503 7. Permit No. 81-142 8. APl Number 5o-029-20662 9. Unit or Lease Name Milne Point Unit 10. Well No. Milne Point B-2 1 1. Field and Pool Kuparuk River Field Prince Creek/Schrader For the Month of April ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Lost B. A. isolation plug downhole - made full recovery. results to follow on final report. Continue testing well- 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 1 6. DST data, perforating data, shows of H2S, miscellaneous data SPF FROM TO Perforations: 12 4372' 4402' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED MAY 1 2 1982 Alaska Oil & Gas Cons. Commission SIGNED TITLE Drlg. Superintendent DATE May 10, 1982 .... · NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 AFE 1744 AO & GCC (2) WIO Rev. 7-1-80 Submit in duplicate STATE OF ALASKA MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation I'~ ~'~ 2. Name of operator Conoco Inc. 3. Address 2525 C Street, Suite 100, Anchorage, AK 99503 4. Location of Well at surface 5278' FSL, 4304' 5. Elevation in feet (indicate KB, DF, etc.) 26' GL FEL, Sec. 19, T13N, RllE 6. Lease Designation and Serial No. ADL 47438 7. Permit No. 81-142 8. APl Number 50- 029-20662 9. Unit or Lease Name Milne Point 10. Well No. B-2 11. Field and Pool Kuparuk River Field Prince Creek/Schrader Bluff For the Month of March ,19 82 '.12. Depth at end of month, footage drilled, fishing jobs, directional drilli6g problems, spud date, remarks Begin MIRU on 3/8. Run Kobe hydraulic-jet pump system to test well - results to follow on final report. 13. Casing or liner run and quantities of cement, results of pressur9 tests Gravel Pack- From To 4462' 4490' 4518' 4542' 14. Coring resume and brief description None 15. Logs run and depth where run None .1 6. DST data, perforating data, shows of H2S, miscellaneous data Perf' SPF From To 12 4464' 4490' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~'S,GNED .-"~'~' ~/~' T,TLE Supervising Prod. Eng. DATE 7~~-- NOTE--R~ort on ~; form is required for each calendar month, regardless of the status of operations and must be'flied in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10~04 Submit i. duplicate ~.7-~-80 AFE 1744 A0 & GCC (2)' W~0 .. A(~ STATE OF ALASKA '1 AND GAS CONSERVATION C('~'.,4MISSION ALASK L MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling well [] Workover operation [~ 2. Name of operator 7. Permit No. Conoco Inc. 81-142 3. Address 8. APl Number 2525 C Street Suite 100, Anchorage. Alaska 99503 5o-029-20662 4. Location of Well atsurface 5278' FSL, 4304' FEL, Sec. 19, T13N, RllE 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 26' GL I ADL 47438 9. Unit or Lease Name Milne Point 10. Well No. B-2 11. Field and Pool Kuparuk River Field Prince Creek/Schrader Bluff For the Month of February ,19 82 112. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Rig moved to Milne Point B-l, will continue completion work on B-2 when rig is finished with B-1. DST results to follow. 13. Casing or liner run and quantities of cement, results of pressur9 tests 14. Coring resume and brief description 15. Logs run and depth where run Logs. GR-CBL-VDL CCL From To 4568' O' .16. DST data, perforating data, shows of H2S, miscellaneous data Perfs: SPF From To 12 4528' 4542' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED~ TITLE Drilling Supervisor DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form ~0-404 AFL 1744 A0&GCC (2) Submit in dupliCate' Rev. 7-1-80 STATE rjr: ALASKA /~ ./~ ~ '~: '~,LASKA(' AND GAS CONSERVATION C(~" MISSION ~~S MONTHLY REPORT OF DRILLING AND WORKOVER OPERA 1. Drilling well E~ Workover operation [] · : :" , 7. Permit No. 2. Name of operator '~'~ .'~,7 ~ ~ '~'~ LJ ~' !¼ -, ~ ~ L~ L,~'~ ;~, Conoco Inc. ~ 81-142 3. Address 8. APl Number 2525 C Street Suite 100, Anchorage, Alaska 99503 so-029-20662 ' 4. Location of Well at surface 5278' FSL, 4304' 5. Elevation in feet (indicate KB, DF, etc.) 26' GL FEL, Sec. 19, T13N, R11E 6. Lease Designation and Serial No. ^DL 47438 9. Unit or Lease Name Milne Point 10. Well No, [t-2 11. Field and Pool Kuparuk River Field Prince Creek/Schrader Blurt For the Month of January ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth on 1/31 - 4700' (S.LM) Move out drilling rig-on-i/3. unit on 1/20. Preparing hole for completion operations. Circulate and wash to 4605' as of 1/31. Move in & R/U completion Drilled out DV tool @ 2115'. 13. Casing or liner run and quantities of cement, results of pressure tests Ca s ing: Si ze Wt. Grade From To 9 5/8" 47#/ft L-80 O' 4700' Cementing: Pump 20bbls (W-lO0), 40 bbls (D-3000), mix 600 sks.(Class G), w/12%. (D-53) 0.6% (P59) & 0.2% (D46) @ 15.2 ppg. Pump 100 bbls water spacer, 130 bbls arctic pack, 150 sks. Arctic set & displace w/dim_sel. 14. Coring resume and brief ~lescription NONE 15. Logs run and depth where run NONE .16. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED FEB 1 6 ]982 Oil & Gas Cons. Commission , SIGNED ITLE. Drill lng Supervisor NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate Rev. 7-1-80 AFE 1743 & 1744 AO&GCC (2) ALASKA OIL AND GAS CONSERVATION COMMISSION Thru: Cha ~~h~&~'~er~,o n Cha~n~ Lonnie C. Smith Commissioner Bobby Foster Petroleum Inspector Feburary 5, 19 82 Inspect Instal lation of Manual Choke on Choke Manifold at Conoco's Milne Point B-2 Mgnday, February... 2~. .... 1..9..8.2 - After completing the BOPE test on ~RCO's DS 11'-7 I went t0 Conoco's Milne Point B-2 and inspected the manual choke that had been installed after the BOPE test witnessed by Ben LeNorman. The choke was installed and worked properly. A('~j STATE OF ALASKA ~,., AL,~,SK IL AND GAS CONSERVATION .vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL }~K COMPLETED WELL [] 2. Name of Operator 7. Permit No. Conoco Inc. 81-142 3. Address 2525 C Street 4. Location of Well 5278' FSL, 4304' FEL Sec. SUite 100, Anchorage, Alaska 99503 5. Elevation in feet (indicate KB, DF, etc.) 26' . Ground Level 12. 19, T13N, RllE, UM JAN 2 21982 Alaska 0il & Gas Cons. Con Anchorage I 6. Lease Designation and Serial No. ADL 47438 8. APl Number S0-029--20662 9. Unit or Lease Name Milne Point Unit 10. Well Number Milne Point B-2 [~$S~i~ld and Pool Kuparuk River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data OTHER F'I ~ NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) ~;, Perforate ~] Alter casing [] - Perforations [] Altering Casing E~ Stimulate [] Abandon [] Stimulation [] ' Abandonment r"] Repair Well [] Change Plans []' Repairs Made [] Other I-'1 Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Estimated Commencement Date: january 26, 1982 1) MIRU workover rig. ~7~4atl IO",~x=c~~, A-~-'~, ~5oP ~ ~&~ ~z> 5~?$~B. C~ ~~ t~ 9.~¢~ ~C.. 2) Run a GR-VDL-CCL log from PBTD of 4603' to the surface. 3)Perforate the following intervals: 12 jet shots per foot with 4" casing guns (0.7" hole entrance diameter). I - 4518' - 4542' II - 4464' - 4490' III - 4372' - 4402' Note: These zones will be perforated and tested seperately,' usin~ plugs to isolate the zones. 4) After the above mentioned zones have been tested, the bridge plugs used for isolation will be remov, ed and the zones will be gravel packed with U.S. mesh 20/40 gravel. (see attached sketch), These zones then will be re-tested. 5) After the bottom three zones have been tested they will be isolated by setting a plug in the top graVel pack packer. 6) The following interval will then be perforated with 12 jet shots per foot with 4" casing guns (0.7" hole entrance diameter) and gravel packed with U.S. mesh 20/40 .gravel: IV - 4020' -4060' 7) After. this zone has been tested the zones will be isolated with through tubingplugs and ............ ,,w ..... ,= w=-- w--- ~,,=,, be suspended. 14. I hereby certify that the foregoing is true and the best of my knowledge. .. Signed Title Supervising Engineer Date 1-22-82 The space~oelow for/Commission use Conditions of Approval, if any: ~ SSION ~SENTATITIVE TO WI ~NESS BOPE TEST. Approved: Copy Returned ORIGINAL S'IGN£O /- ~- ~,~ 'BY [ON.qlE C. SMITH Bv Order of Approved by COMMISSIONER the Commission Date __ Form 10~403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate PROPOSED COMPLETION 1-21-82 KB=46' GL=24' MILNE POINT UNIT Wel 1 #B-2 1'03' 20" ,94#/ft. 2234' 13 3/8",72#/ft. L80 Buttress ECP's @ 1) 4091-4100 2) 4346-4355 3) 4454-4463 4) 4503-4512 5) 4553-.4562 Model 16 Packer @ 3852' Perforations @ 4020-4060 12 spf 12 Gauge screen, 4014-4065 0D=5.045", ID=4.09", 20/40 gravel -Model 16 Packer @ 4067' x-nipple ~ 4060' Blank liner, 0D=4.5", ID=4.09" Perforations @ 4372-4402 12 spf x-ni pple @ 4426' Perforations @ 4464-4490 ~ spf 12 Gauge screen, 4368-4405 0D=5.045", ID=4.09", 20/40 gravel Model 16 Packer @ 4407' · Blank liner, 0D=4.5", ID=4.09" 12 Gauge screen, 4450-4.544' 0D=5.045", ID=4.09", 20/40 gravel Perforations @ 4518-4542 12 spf 4700' 9 5/8",47#/ft. L80 Buttress TD=4700' Bull plug shoe Bridge plug @ 4545' RECEIVED JAN 2 21,982 Alaska Oil & Gas Cons. Commission Anchorage WRL _- /.... STATE OF ALASKA [ ~ ALASKA ([. . AND GAS CONSERVATION COl. AISSION ./,..~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~] Workover operation [] 2. Name of operator 7. Permit No. CONOCO I NC. 81-142 3. Address 8. APl Number 2525 "C" St., Suite 100, Anchorage, Alaska 99503 50- 029-20662 4. Location of Well -at surface 5278' FSL, 4304' FEL, Sec 19, T13N, RllE 5. Elevation in feet (indicate KB, DF, etc.) 26' GL 6. Lease Designation and Serial No. ADL 47438 9. Unit or Lease Name Milne Point 10. Well No. BNo. 2 11. Field and Pool Kuparuk River Field Prince Creek/Schrader Blur For the Month of December ,19 81 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud Date' 12-3-81 SLM, Total Depth is 4697'. Preparing to run and cement 9-5/8" casing. 13. Casing or liner run and quantities of cement, results of pressur9 tests Casing: Size Wt. Grade From To Cement 20" 94# H40 0' 80' To Surface 13-3/8" 72# L80 0' 2234' 4400 Sks. to surface 14. Coring resume and brief description Cored from 3700'-4659'-Prince Creek/Schrader Bluff Pool. Recovery was' 81%. The lithology of the cored zone is dominated by alternating sandstone and siltstone beds. Shale is common with claystone and coal present in minor amounts. Laminated beds are uncommon. 15. Logs run and depth where run Logs From To FDC-CNL 2242' 110' BHC Sonic - GR 2249' 110' Dual Induction - GR 2249' 110' Proximity Microlog 2242' 1800' Logs From To FDC-CNL,DLL-GR,ML- MLL, BHC-GR 4697' 2234' NGT 4697' 1 700' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED' JAN 1 4 1982 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S'GNEDO~~/' ~ T,TLE Drilling Supervisor Alaska Oil & Gas Cons. Commission Anchorage DATE 1 -8-82 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form~0-404 AFE 1743 A0 & GCC (2) File Submit in duplicate ~, 7-1 -~F~ Thru: ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton~ Chairman Lonnie C. Smith~/7~.~ Commissioner Edgar W. Sipple, Jr.~ Petroleum Inspector December 16, 1981 Witness BOPE Test on Conoco ' s ... 2B Milne Point.. Sec. 19, T13N, RllE, UPM Permit No. 81-142 Parker Rig No. 128 Thursday,_ ~cember~. 1.0, 1981 - I left Sohio's 'D" pad, Vanguard ~kg"'~o. 3'and traVeled to Conoco's 2B Milne Point, Parker Rig 128, to witness a BOPE test. Upon arrival at the drill site Parker was in the process of nippling up. Friday,. r~cember 11, 198_1 - I witnessed the BOPE test on Conoco's 2'B Milne Point', this test commenced at 12:45 p.m. and was concluded at 3~30 p.m. There were no failures. I filled out the A.O.G.C.C. BOPE test report which is attached. In summary, I witnessed the BOPE test at Conoco's 2B Milne Point. There were no failures. S~ "? OF AIASK,\ ALASKA OIL & -CA% ODNSERVATi[('," ~ ~,IY~LSSION B.O.P.E. Inspection 'rator ('m~ooC o ation: Sec_ / ~, 1 linq Contractor Date Representative $ ' _. ~e rmit# ." ~ 377/ Casing Set Rig ~ :Z-~--Representative_ ation, -General 1 Sign. O~ eral Housekeeping erve pit E Stack I ~ar ~_~venter nd Rams ke Line Valves~- ,___ .R. . i Line Valves., / ck Valve. / '__ . · . Test Pressure ~oo ~ooo ~.0oo 3 ~o0 ACCL%~UIATOR 'SYSTEM Ful 1 Charge Pres surq ~ Pressure After Closure psig psig /-- m in O sec. Punp incr. clos. pres. 200 psig Full Charge Pressur~ Attained: ~ min ~/ sec. Controls: ~ster ~/./~ Remote ~ Blinds switch cover t Results: Failures Test Pres sure Test Pressure Test Pressure ~/ Test Pressure___3000 Kelly and Floor Safety Valves · ./ Upper Kelly -- Test Pressure ~r Kelly, Bal 1 Type Irs ide BOP Choke Manifold No. Valves /.~, No. flanges Adj ustab le Chokes }~{drauically operated d~oke .-- ..... :~:::. :nz_-_'. :.' --- :'.:_-_' :r ----'~ .--:- ...... _--:'- -_-r-mt: ~ ~)'--~--~--Test Tim~' ~ , hrs .... ~ ~- ~.,!~ air or Replacement of failed oquipment to he made within---O--i, days and tribut ion ~. - AO&CCC - ~rator - Su~sor / -'i/ / Conoco Illc. 2525 C Street Suite 100 Anchorage, Alaska 99503 December 11, 1981 Hoyle Hamilton, Chairman Alaska Oil & 'Gas Conservation Commission 3001. Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton- Enclosed are three copies of the Sundry Notice that requests approval for changes in the drilling program of Milne Point B-2. If you have any questions, or need more informatiom, please call me at 279-0611. Sincerely, G. A. Merriman Supervising Engineer R E C DEC 1 1 Alaska Oil & Gas Cons. Comm[ssior~ Anchorage STATE OF ALASKA ALASKA{~ .L AND GAS CONSERVATION ~' AMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Conoco, Inc. 81-142 3. Address 8. APl Number 2525 C Street, Suite 100, Anchorage, Alaska 99503 50-029-20662 OTHER 4. Location of Well 195 FNL, 4240' FEL, Sec. 19, T13N, RllE, UM 5. Elevation in feet (indicate KB, DF, etc.) 26' Ground Level 6. Lease Designation and Serial No. ADL 47438 9. Unit or Lease Name Conoco et al, Milne Point Un 10. Well Number Milne Point B-2 11. Field and Pool Kuparuk River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate r-] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon r-I stimulation [] ' Abandonment [] Repair Well [] Change Plans ]~ Repairs Made [] Other [] [] Other r'-] Pulling Tubing ,ri Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state ali pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.,105-170). 1) Surface location change. As built survey: 5278' FSL, 4304' FEL., SECTION 19, T13N, Rll.E, UM. Verbal approval g~ven on 11/25/81, in telephone.conversation between D. O. Uldrich,~ Conoco, and Blair Wondzell, Alaska Oil and Gas Conservation Commission. J 2) ~d system change. From 2100' to 4700' (TD), a MCl salt mud system (40 to 50 Kppm) will be used instead of a fresh water-gel system.. RECEIVED, DEC1 1 ~Jaska 0il & (~as Cons. Commissior~ Anchorage 14. I hereby cer~t~y that the foregoing is tr, ue and cc~ect to the best of my knowledge. Signed 2 Title Supervising Production Engineer Date 12-8281 The space/below fo/Commiss.on use Conditions of Approval, if any: Approved by ORIGI!~T~[' SIGNED" BY [O~.~E C. SMITH Appravs~ C COMMISSIONER the Commission Date /'~/'/..~/~/' Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilto Chairman c. Commissioner Bobby Foster ::' Petroleum Inspector December 7, 1981 Inspect Diverter System on Conoco's Milne Pot=t ~ Sec. 197T13N,RllE UPM Permit #81-142 Wednesday, December 3, 1981: After witnessing.the.BOPE test on Arco's P.S. 15-14, I went to co~o~'06s~Miln~s P°int~'B-2 and inspected the diverter system installed 6n.the.i 20~ c°nd~ct°r-pipe. The diverter system meets' A.O.G.C.C. and API RP - 53 regulations with the exception of two 90° ells ~n~talled Where 'the two 6" lines turn to allow venting to opposite' ~irec~ions, · i · informed 'Mr. John Henderson, Conoco drilling foreman, .t~at'"{hese' ~0uld have. tO' be replaced-with targeted tees before the 's~stem"couidi~be'''used On fUt~e Wells . In summary, I inspected th~ diverter Syst.em. on Conoco's Milne Point B-2. I September 25, 1981 Mr. Gary A. Merriman Supervising Engineer Conoco Inc. 2525 C Street, Suite I00 Anchorage, Alaska 99503 Res Milne Point Unit, Milne Point COnoco Inc. Permit No. 81-142 Sur. I~)c.~ 195'FNL, 4240'FEL, Sec 19, T13N, RllE, UM. Bottomhole Loc.~ S A M E Dear Mr. Merriman~ Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. An inclination survey is re~lired. If available, a tape containing the digitized log information shall be submitted on ali logs for copying except experimental logs, velocity surveys and dipmeter .surveys o Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative COde). Prior to commencing operations yo~ may be contacted by the Habitat Coordinator's office, Department of Fish and 'Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. Gary A. Merriman -2- Milne Point Unit, Milne Point B-2 September 2 5, 19 81 commencing operations you may be contacted by a representative of the. Department of Environmental Conservation. TO aid us in scheduling field work, we would appreciate your notifying this office at lease 48 hours before the well is spudded. We would like to be notified so that a representative of the Commission may be present to inspect the diverter system before the conductor shoe is drilled and also to witness testing of blowout preventer equipment before surface casing shoe is dril lc4. In the event of suspension or abandonment, please give this office adequate advance notification so that .we may have a witness present. .Very truly yours, H'. Hamilton Chairman of CO~ISSlON corem1 ssion Enclosure cot Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/eno1. Conoco Inc. 3201 C Street Suite 403 Anchorage, AK 99503 September 18, 198! Mr. Lonnie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Smith: Enclosed are the permit applications to drill Milne Point B-2, C-l, and D-1. These applications are being submitted in triplicate on form 10-401, revised 7-1-80. Please disregard any previous permit applications to drill the above mentioned wells. If you have any questions, please call me at 279-0611. Sincerely, Supervising Engineer RECEIVED Oil & ~as Cons. Co~,~nission Anchorage STATE OF ALASKA CO S .V^T O CO( PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I--I SINGLE ZONE ~] MULTIPLE ZONE [] 2. Name of operator Conoco Inc. 3. Address 2525 'C' Street, Suite 100, Anchorage, Alaska 4. Location of well at surface 195' FNL, 4240' FEL, Sec 19, T13N, RllE, UM At top of proposed producing interval Same At total depth Same 5. Elevation in feet (indicate KB, DF etc.) 26 ' Ground Level 6. Lease designation and serial no. ADL 47438 99503 9. Unit or lease name Conoco etal, Milne P~in~ TinCt 10. Well number Milne Point B-2 11. Field and pool Kuparuk River Field Prince Creek Schraeder Bluff 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 Amount $200.000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line i Deadhorse: Southeast 3] miles 1040 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease (Vertical Hole) MD:4700 feet 2560 AC 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures i KICK OFF POINT - feet. MAXIMUM HOLE ANGLE - o I (see 20 AAC 25.035 (c) (2) { 21 15. Distance to nearest drilling or completed well Mi ] ne_,. Pt - 2 90 feet 18. Approximate spud date November 15. 1981 ;2060 pslg@ (J Surface 2320 ' psig@, 4700 'ft. mD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Grade 26" 17½ 12¼ Casing 20" 13-3/8 9-5/8" Weight 94# 72# H-40 N-80 47# L-80 22. Describe proposed program: Coupling BTRS . BTRS iBTRS Length 80 ' M D TOP TV D 0 I 0 2000 4700 MD BOTTOM TVD ~0'~I 80* 2000 ..,,-,2 0 0 0 4700 i )4700 2/o o (include stage data) 4200 CF (200% 1st: 700cF, 2nd:~OOc~ Proposed surface and bottomhole loCation plat enclosed ~._~/_~ / As-built survey_plot will be submitted after setting conductor '"'casing. See attached Supplemental Data Sheet See attached wellhead and BOP sketches RECEIVED SEP 2 1 1981 Alaska 0ii & Gas Cons. Comrnisslort Anchorage *set 80' from ground level; all other fiqures ar~ based on 20' KB 23. I hereby certif that the foregoing is true end,correct to the best of,my knowledge SIGNED ~~, ~ TITLE Supervisinq Engineer The space I~low for C~mmissio~ u~e DATE Sept. 17, 198: Samples required []YES Permit number CONDITIONS OF APPROVAL Mud Icg required I Directional Survey required I APl number DYES /[~O 1, DYES _~NO [ 50-- ~'7~? - "7..c i~ (. '~-- Approval date 09/2-5/81 i SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER by order of the Commission DATE September 25, 1981 Form 10~101 Rev. 7-1-80 Submit in triplicate SUPPLEMENTAL DATA SHEET FOR APPLICATION FOR PERMIT TO DRILL CONOCO et al. MILNE POINT NO. B-2 CONOCO,' INC. 2525 "C" Street- Suite 100 Anchorage, Alaska 99503 I CEMENTING PROGRAM A. The 20" OD conductor casing will be cemented to the surface with perma- frost cement in 26" bucket drilled hole. B. The 13-3/8" OD casing will be cemented to the surface with permafrost cement through drillpipe stinger stabbed into float collar and through float shoe. C. The '9-5/8" OD casing will be cemented through plug container head, float shoe, and float collar with. 700CF of Class "G" cement. Isolation of the 13-3/8" - 9-5/8" casing annulus @ the 13-3/8" casing shoe will be accomplished., through multi-stage cementing collar run at the 13-3/8" casing shoe with 100 CF of permafrost cement. Non-freezing fluid will be placed in the 13-3/8"-9-5/8" casing annulus through the permafrost utilizing multi-stage cementing collar placed at the base of the permafrost. II ANTICIPATED GEOLOGY 0' - 4,500' 4,500' - 4,700' Surface conglomerates, silt and sand sequences Estimated base of permafrost @ 1,600' Siltstone, shales III FORMATION EVALUATION A. Standard mud logging equipment will be installed while drilling interval 60'-to total depth. B. Full size cores may be taken as determined by on-site geologists. C. Wireline logs including: Dual Induction Laterolog; Borehole Compensated Sonic-Gamma Ray; Formation Compensated Density with CNL and GR-Caliper. IV DRILLING FLUIDS Depth Type Density 0' - 2,000' High Viscosity 9.5 - 10.0 ppg Gel - Fresh Water 2,200' - 4,700' Low Solids - Nondispersed 9.5 - 9.8 ppg RECEIVED' $£P 1 8 1981 A~aska 0i! & Gas Cons. Comr~ission Anchorage 97 Conoco Inc. Milne P~. Uni~ Pr®posed Drilling 1 981 Supplemen% ~o SPCC Development Plan (Phase 2) Milne Point Unit North Slope, Alaska T 13 N ~ R 10 E Sec. 9, 10, 11, 12, 13, 14, 15, 22, 23, 24, 25, 26, 36 T13N~RllE Sec. 7, 8, 16, 17, 18, 19, 20, 21 18 19 J'-i' ~o,~oc.o .,K, dC. A 24)" 0.1~. CA Sl~ '~ O P GT'AcK I I ~d'-2~ ~u~ -A CH( ~E & KILL MANIFOL[-~ FOR IS~ & ~'OD CASING BOP STACK C ROM MUD PUMP KILL MANIFOLD ' , · . ~ FROM REMOT£ HIGH~I~I"Fl]~ ~ ~--a~ ~"~,,~ DRILLING SPOOL HYDRAULIC CONTROLLED REMOTE OPERATED NOTE: 1. o -- x° 2. Kill ~ Choke Manifolds to meet APl RP53 Class 5M Standards. 3. Kill ;:~nifold Size-Rating 2"-5000 4. Choke ~,anifold Si:¢-Ra~ing 5"-5000 Hydraulic Control System for BOP Stack ~ Choke Manifold to include (S) ~ Station Control Hanifold located remotely with 3000 psi Accumulator ~ 160 gaL: Reservoir ~ Auxiliary Energy source. (5) Station Cont]:ol Hanifold plus variable Choke Control to be located on Rig floor. REMOTE PRESSURE GUAGE SENSOR BOP MANI FOLD"LAYOUT CONOCO, INC. r :c ~U ~ ..~ 0 la VARIABLE CHOKE t~ ~ RE:MOTE CONTROL _ o. ' ' CH~E " . . 20" O.D. CASING B.O.P. STACK ANNULO. I'I o' RtU[~ i, FLOw L,i~. REMOTE ~.~-~.------J REMOTE CONTROL ~ CONTROL - VALVE '_1 'i__ VALVE , J I ~-~ I I ' ~ tl0T [ S: ..... ~ ': 1) Relief lines from ~he drilling spool ~11 be tou~ed ~o accomplish downwind diversion. .. Z) ~ydraulic con,to1 system for th~s stack to ~nclude 180 gal. c~pac~Ly acc~Ula~or ~nd reservoir aod con,to1 manifold on t~g floor wi~h 3000 psi No~k~ng p~essure. .2' BOP STAt:< FOR 20' OD CA~iNG CONOCO I l'l.C. Page £ BLOW OUT PREVENTER FOR 15~,~'~, 9 =A OD IrLD~ LI~[ F1L~ L~ S KOTES: ~) Rt~? SL~CL Size Ratin9 meets APl RP53 R Spec. 6A for CIzss ali ~ydraulic C~er~te4. DO?E to be e~erated on e~ch Lrip & Pressure /TeSted .eeKly. C~ntrOI Ranifold IoCated. re~r~..e ~ith 160 9~1. Accu~;~ulatu~ e~d Reservoir Unit and Auxiliary · £~erg7 Source for sy~?~ activation. of one set of blind RECEIVED SEp 1 8 1981 Nas/fa 0il & Gas Cons. ~chorage Cor~missioe Il I I III II I ! III I t7:, 2# 18 moco V.b.s,s. - 7_OOb -- H CO#OeO ~. H. D. Hal®y Manager of Production Ventura Division Conoco Inc. 290 Maple Court Ventura, CA 93003 (805) 642-8154 September 2, 1981 Mr. L. C. Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' Permit Request Milne Point/Conoco Attached is a permit request for the authority to drill three oil wells on the Milne Poin,i~,,Unit of the Alaskan North Slope. These wells are designated as :B-2, C-1, and D-l; the letter indicating the drilling site location and the number is the sequence in which the wells will be drilled from the respective location. A map of the area is attached which designates the location of these wells. A surveyed location will be provided once the well is staked. Also attached you should find our check in the amount of $300.,00 which according to the Alaskan Administrative Code is the filing fee required. Your contact relative to the permitting of this well is Gary Merriman. Gary can be reached by dialing 279-0611. Very truly yours, H. D. Haley Division Manager of Production DLD-fes encs 1981 CC' Gary A. Merriman SPILL PREVENTION CONTROL 8~ COUNTERMEASURE PLAN PARKER DRILLING COMPANY REVISED JULY 1981 SPILL PREVENTION CONTROL & COUNTERMEASURE PLAN Parker Drilling Co. - Operating for Conoco Inc. TABLE OF CONTENTS I Rig Owner and Identificati · on ................ 2 Oil Spill History · · · · · · · · · · · · · · · · · · · · · · 3. Parker Drilling Company Commitment ............. 4. Professional Engineering Certification ........... 5. Prediction of Flow Rate and Direction ........... A. Mud Tank Capacities .................. B Tank Capacities · · · · · · · · · · · · · · · · · · · · · C. Physical Specifications of Typical FUel ........ 6. Containment and Diversionary Structures .......... 7. Inspection and Records .................. 8. Personnel Training and Spill Prevention .......... 9. BOP Instructions ...................... 10 Kick Control · · · · · · · · · · · · · · · · · · · · · · · · · 11. Drilling Break Control ................... 12 BOP Testing · · · · · · · · · · · · · · · · · · · · · · · · · 13. Surveyed Site ....................... 14. Design and Instructions for Onshore Drilling ........ A. Location of Drillsites ................. B. Control of~Drainage from Dyked Areas .......... C. Disposition of Oily Effluent from Secondary Containment D. Bermed Location Schematic ............... E. Primary Containment Equipment ............. Page 1 2 2 2 3 3 3 5 6 6 7 10 11 12 12 14 15 15 15 16 17 18 F. Casing and Blow-Out Prevention Equipment ........ G. Typical Rig Layout ................... Page 19 20 15. Typical. Rig Inventory ................... 21-30 16. Oil Spill Reporting Procedure ............... 31-31e 17. Reporting of Spills .................... 32 18. Reporting of Spills to Regulatory Agencies ......... 33 19. Spill Report Form ..................... 34-36 20. Responsibility and Authority ................ 37 Immediate Actions Authorized ............. 37 21. Specific Countermeasures to be Executed .......... 39 22. On-Site Equipment. and Materials .............. 40 23. Additional Equipment in the Area .............. 41 24. Oil Spill Action Procedures ................ 43 25. Inspection of Fuel Storage, Water Storage, and Transfer Systems ............................... 44 26. Inspection Procedure for Drilling Fluid System ....... 45 27. Check List for Keeping SPCC Plan Current .......... 46 CONOCO SECTION 28. Conoco - Anchorage Production Division Accidental Discharge~ Contingency Plan ................... ~ . ~23 29. Arctic Oilfield Environmental Services Equipment List ............ 24-42 Open Purchase O~d~r' . ........... 43 30. Crowley Environmental Services Open Purchase Order ............ 44 ~,' Equipment List ............... 45-58 31. ABSORB North Slope Equipment List ......... 59-67 SPILL PREVENTION CONTROL & COUNTERMEASURE PLAN 1. RIG OWNER & IDENTIFICATION a. NAME' PARKER DRILLING CO. b. TYPE OF RIG: Mobile Onshore Oilwell Drilling Rig for depths to 15,000'. c. lOCATION OF RIG: This rig is operated on the North Slope of Alaska at Drillsites selected and constructed under the direction of our Customers. The location of the Drillsite upon which this rig is currently operating is shown on the Survey Plat located on page 14 of this SPCC Plan. d. NAME AND ADDRESS OF OWNER AND OPERATOR: PARKER DRILLING CO. Parker Building 8 East 3rd Street Tulsa, Oklahoma 74103 (918) 585-8221 P.O. Box 455 ~ 812 W. International Airport Rd. Anchorage, Alaska 99510 (907) 279-0476 e. DESIGNATED PERSONS ACCOUNTABLE FOR OIL SPILL PREVENTION AT RIG- Name Title Drilling Superintendent Name Title Tool pusher Name Title Tool pusher Name Title Name Title Name Title Name Title Name Name Driller Title Dri 1 ler Title D~i I ler Name Title Name Title One or }lore Working Copies of this SPCC Plan are to be maintained at the Drillsite by the Parker Drilling Co. noolpusher. NOTE: Page ! t_ SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO CONOCO INC. 2. OIL SPILL HISTORY This facility experienced no reportable oil spill prior to January lO, 1974 (effective date of 40 CFR, Part 112). Forms are included in this Plan for future use; if needed; for reporting spill events page 34, 35, & 36. 3. PARKER DRILLING COMPANY COMMITMENT This Spill Prevention Control and Countermeasure (SPCC) Plan is approved and will be implemented as herein described. PARKER DRILLING COMPANY owns and operates the rig within the terms of Daywork Contracts to perform oil and/or gas well drilling operations under the direct supervision of our Customer. Spill Prevention Control and Countermeasure procedures outlined in this Plan will be implemented either singly or jointly with our Customer's Plan, as conditions warrant. PARKER DRILLING COMPANY intends to meet the requirements of the Environmental Protection Agency Oil Pollution Prevention Regulations, 40 CFR, Part 112. However, the responsibility for actions required and other liabilities which are included in the Regulations are limited to those specified by the terms of the Drilling Contract between ourselves and our Customer. All Regulator~y.Requirements beyond the scope of the Drilling Contract will be met by our Custo- mer within their Oil Spill Contingency Plan. All extraordinary Well Control Measures and Countermeasures outside the limits of any Drillsite are the responsibility and liability of our Customer. 4. ENGINEERING CERTIFICATION I hereby certify that I am familiar with the provisions of 40 CFR, Part 112, and attest that this SPCC Plan has been prepared in ac- cordance with good engineering practices. This Certification includes the same limitations as those imposed under the Management Approval paragraph of this SPCC Plan. Name' A. ~. Has tings Signature' ~~.,~] ~ Registration No. PE-1345 State: California Date: 9/30/80 (expires Pa~e No. 2 SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO CONOCO, INC. 5. PREDICTION OF DIRECTION & RATE OF FLOW The direction of flow of any spills escaping the drillsite is estimated and shown on the USGS Topo Sheet and As-Built Contour Maps; attached to this SPCC Plan. These maps are inserted as revisions to this Plan as drilling operations are started at eaci~ new drillsite on the slope. The actual direction of flow, should a spill occur, may vary from that predicted. Surface conditions vary from summer to winter;~ and change during the winter, Personnel responsible ~for oil spill containment at the drillsite will be prepared to construct flow barriers for any flow direction encountered. The prediction of' the potential rate of flow of an oil spill at the drillsite is not possible. This SPCC Plan provides for the capability to contain rates of flow exceeding that possible from the total storage tankage listed below. The total vol~ume of a potential spill can be predicted only to the extent of the fluid storage capacity shown below. a. Mud Tank Capacities. Tank or TYPE OF Storage FAI LURE VOLUME MUD TANK See Note No. 1 170 Barrels MUD TANK See Note No, I 170 Barrels MUD TANK See Note No. I 170 Barrels MUD TANK See Note No. I 170 Barrels MUD TANK See Note No. I 170 Barrels MUD TANK See Note No. 1 170 Barrels MUD TANK See Note No. i 170 Barrels MUD TANK See Note No. I 170 Barrels b. Fuel Tank Capacities FUEL TANK FUEL TANK FUEL TANK FUEL TANK FUEL TANK FUEL TANK FUEL TANK FUEL TANK See Note No. 2 See Note No. 2 See Note No. 2 See Note No. 2 See Note No. 2 See Note No, 2 See Note No, 2 See Note No. 2 4500 Gal lons 4500 Gallons 4500 Gal lons 4500 Gallons 4500 Gallons 4500 Gat lons 4500 Gallons 4500 Gal lons NOTES !. Steel Mud Tank failures are almost non-existant during rig opera- tions. Not a pressure vessel, Tanks are inspected and repaired (if needed) during rig moves. Total norn~at drilling fluid storage (Mud) is i~QO Barrels. ~ne drilling mud normally contains no oil. Page 3 SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO CONOCO, INC. 2. Steel Fuel Tank failures are almost non-existant during rig operations These tanks are not pressure vessels and have relief vents. The total fuel storage capacity is normally approximately 36,000 gallons. Any changes in the fuel storage capacity at the drillsite will be noted in the space provided on the following page. The Steel Fuel Tanks contain Arctic Heating Fuel or JP-5 Aviation Fuel. The fuel source will vary. Typical fuel properties are shown below. The chemical composition of the various fuels in use are enclosed with this SPCC Plan. Page 4 SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO CONOCO, INC. C Physical Specifications of Typical Fuel API GRAVITY CLOUD POINT POUR POINT FREEZE POINT SULFUR VISCOSITY, KIN. @ lO0OF VISCOSITY, KIN. @-30OF DOCTOR TEST CALC. CETANE FLASH POINT, P.M. CO RROS I ON BTU/Gal. GROSS BTU/Lb. GROSS DISTILLATION: IBP 5% 10% 20% 30% 40% 50% 60% 70% 80&. 90% 95% EP .Recovery Residue Loss 42.6 -56OF. -60OF. -60OF. 0.03% of 1% 1.6 cs 7.5 cs NEG 45.5 110OF. lA 133,500 19,720 330 353. 367 375 385 395 406 419 432 448 469 485 506 99.9 1.0 0.0 Page 5 SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO CONOCO, INC. 3. Drillsite Fuel Storage Modifications Tank Tank Da te Vo 1 ume Type Add or Delete 6. CONTAINMENT ,/ DIVERSIONARY STRUCTURES Containment or diversionary structures and equipment to prevent oil from reaching navigable waters are practicable. Typical secondary containment for the Drillsite is shown on page 17. Equipment available for containing spills at the DrillSite is listed on page 40. This list of equipment is designated to deal with any large spill volumes which could be reasonably anticipated. 7. INSPECTION & RECORDS The inspections made each ,tour by the Rig Crews follow the written procedures shown on pages 44-45. These~procedures are enlarged upon verbally, as required to meet existing operating conditions,- by the Rig Toolpusher during scheduled sessions. Inspections made daily by the Rig Toolpusher include those shown on page 44. AdditiQnally, each Toolpusher conducts an industry developed 'and accepted inspection of the entire rig, daily. A record of the inspections outlined above is to be kept by making the following entry on the IADC Daily Drilling Report for each Tour. "SPCC Rig Inspections Complete". Page 6 SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO CONOCO, INC. By signing of the IADC Daily Drilling Report, both the Driller and the Toolpusher authenticate that the inspections have been completed. The Conoco, Inc. Drilling Foreman has ultimate responsibility for insuring the accomplishment of these inspections. His sig- nature on the IADC Daily Drilling Report further signifies satisfaction of the inspection requirements. 8. PERSONNEL TRAINING &~SPILL PREVENTION PROCEDURES The Parker Drilling Co. Toolpusher, on-site, is responsible for coordination and execution of SPCC Training, with the on-site Customer Drilling Foreman and all other Contractor and Service Company personnel. The Toolpusher will. record, on his Morning Report, the completion of each SPCC Plan Training Session. The following is .a list of subjects to be considered duri~ng SPCC Plan Training Sessions. a. The Operation & Maintenance of all equipment utilized on the Drillsite which stores, transfers or consumes fuel and/or lube oils, manufacturer's equipment~manuals, films and other training aids will be used as applicable. b. Explain the specifications for construction of the Drillsite. This includes the construction and maintenance of the reserve pit, berm around the Drillsite, and the drainage ditches on the Drillsite. These specifications are listed on page 17 of this plan. c. Give to all Rig Crews, an explanation of the Minimum Inspection Procedures included in this Plan on pages 44-45 Additional specific instructions should be provided the Derrickmen and the Motormen regarding the execution of the inspections and reporting the results; as well as special instructions required for abnormal operating conditions. d. Familiarize all Drillsite personnel with the utilization of all special oil spill containment and clean-up materials and equipment listed on pages 40-42, utilizing manufacturer's representatives and literature for this purpose. .~, Familiarize Drillsite personnel who operate support equipment listed on page 40 with their work assignments during an oil spill containment and clean-up operation. Page 7 SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO CONOCO, INC. e. Review with all Drillsite Personnel, this Spill Control anti Countermeasure Plan, as required by Environmental Protection Agency Regulations 40 CFR, Part 112. · f. Review the following excerpt from the "Federal Water Pollution Control Act of 1972", Sec. 311, (b), (1), reads as follows' "The Congress hereby declares that it is the policy of the United States that there should be no discharges of oil or harzardous substances into or upon the navigable waters of the United States, adjoining shorelines, or into or upon the waters of the contigous zone." Note- "Navigable Waters' have been defined in such a manner that virtually all lakes, streams, ocean and sea shore lines are included in the meaning of the section quoted above. Section 311 (b) (5) reads in part: "Any person in charge of a vessel or of an onshore facility or an offshore facility shall', as soon as he has knowledge of any discharge of oil or a hazardous substance from such vessel or facility in viol.ation of paragraph (3)of this subsection, immediately notify the appropriate agency of the United States Govern- ment of such discharge." Note: Reporting procedures are given below, and in a subsequent section. g. Review with all Drillsite Personnel, the following excerpts from 50 CFR Part 110 of the Environmental Protection Agency Regulations. Paragraph 110.1 (1) reads' "Sheen means an iridescent appearance on the surface of the water." Paragraph 110.1 (m) reads: "Sludge means an aggregate of oil or oil and any other matter of any kind in any form, other than dredged spoil having a combined specific gravity equivalent, to or greater than water." Paragraph 110.3 reads in part' "--discharges of such quanti- ties of oil into or upon the navigable waters of the United States or adjoining shorelines determined to 'be harmful to the public health or welfare of the United States, at all times and~ocations and under all circumstances and conditions, -- include discharges which' Cause a film or sheen upon or discoloration of the surface of the water or adjoining shorelines or cause a sludge or emulsion to be deposited beneath the surface of the water or upon adjoining shorelines." Paragraph 110.5 reads in part: "--no person shall discharge or cause or permit to be discharged into or upon the naviga- ble waters of the United States, the adjoining shorelines, or Page 8 SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO CONOCO, INC. into or upon the waters of the· contiguous zone., .any oil, in harmful quantities as determined in paragraphs 110.3 II and 110.4'of this part, --- . Note- Simply stated; causing a sheen on any water surface or sludge in any waters is a violation of Federal Regulations. h. Review with all Drillsite Personnel; excerpts from Title 46 of the Alaska Statutes. Sec. 46.03.760 reads in part' "No person may discharge, cause to be discharged, or permit the discharge of petroleum, acid, coal or oil tar, lampblack, aniline, asphalt, bitumen, or residuary product of petroleum, into, or upon the waters or land of the state ---". Sec. 46.03.760 (a) reads in part: "A person who violates Sections 710, 730, '740 or 750 of this Chapter is guilty of a misdemeanor and upon conviction is punishable by a fine of not more that $25,000 or by imprisonment for not more that one year, or both". i. All DrillSite Personnel are to be specifically instructed that the policy of Conoco Inc. and Parker Drilling Company, is that: "Any and all Personnel will report any and all oil spills to their immediate supervisor." This policy is to be implemented by: (1) Oil Spills shall be immediately reported to the individuals' Supervisor. (2) The Supervisor will immediately report any and all oil spills to both the Parker Drilling Company Toolpusher and the Conoco Inc. Drilling Foreman on- si te. j. All Parker Drilling Company personnel will follow the "Contractual' BOPE & Well Control-Procedures" which are included in this SPCC Plan on page 10. Page 9 WELL CONTROL PROCEDURES B. O. P. DRILLS The Cont'ractor's tool pushers, drillers, and all crew members must be completely familiar with the installations, operation, and maintenance of all components of the preventer assembly including controls for its operation. B. O. P~ drills are to be conducted daily with each crew to assure equipment familiarity and proper operation. :Pr°per notation will be made on the tour report by the driller to include which drill was conducted and the time elasped to complete the drill. He'will also take slow circulation rate pressures ( P low) and record in order to more carefully control the well in event of a kick. The following procedures are to be included in B. O. P. drills' If the well is drilling - "Pit Drill" Step 1. Read and record on the tour sheet the circulating stand pipe pressure and pump strokes per..minute. Step 2. Simultaneously raise Kelly and stop the pump. Step 3. Open the choke line and Hyraulic stack valve. Step 4. Close Hydril (clos.ing the Hydril should only be simulated in order to extend the life of the rubber element.) Step 5. Close the choke. Step 6. Read and record drill pipe and casing pressure and pit level. Step 7. Open Hydril. Step 8. Open choke and close Hydraulic stack valve. Return to drilling. While tripping - "Trip Drill" Step 1. Installing the inside B. O. P. Step 2. Record the pit level. Step 3. Start pipe back to bottom (Run one stand). Page 10 Step 4. Record on tour sheet all times required to complete steps '1 thru 3. The time required from the start of the B. O. P. drill until the well is put on choke or one stand run back in the hole should not exceed three mi nutes. Occasionally, an unannounced drill should be instigated by the Contractor' s representative. PaQe 1 1 INSTRUCTIONS FOR KICK CONTROL Step 1. 'Stop pump and rotary. Step 2. Pick up Kelly. Step 3. Open HCR valve. Step 4. Close annular B. O. P. Step 5. Finish shut-in at choke manifold. Step 6. Record drill pipe pressure, annulus pressure, and pit gain. Step 7. Begin kill procedure. DRILLING BREAKS In case of a drilling break, stop rotary, pick up Kelly, stop pump and check for flow. If the well ~s flowing, shut it in and begin kill pro- cedure. If no flow exists and well conditions permit, drilling can continue. On each trip out of the hole, close the blind rams as the bit clears the rotary. TESTING B. O. P. EQUIPMENT Pressure Test - Ram-type blowout preventers and related control equipment Shall be tested to the rated working pressure of the stack assembly, or at the working pressure of the casing, whichever is the lesser. Annular- type preventer shall'be tested to 70 percent of these pressure ~.equirements. They shall be tested: (a) when installed, (b) before drilling out after each string of casing is set, (c) not less than one each week while conducting drilling operations, and (d) following repairs that require disconnecting a~pressure seal in.~he assembly. Actuation- While drill pipe is in use, the ram-type blowout preventers equipped with pipe rams shall be actuated at least once each day. If a tapered drill string is in use, the smaller size rams shall be actuated on the appropriate size pipe, once each trip. The blind ram shall be Page 12 actuated.while out of the hole once each trip. Accumulators or accumulators and pumps shall maintain a pressure capacity reserve at all times to provide for repeated operation of hydraulic preventers. An operable remote blowout preventer control station shall be provided in addition to the one on the drilling floor. Page 1 3 · o . 3F MILNE PT. VICINITY MAP """ -li~. :-. I-:.,.,.,' '/~ i I ,-.L'* "~ ........" ............. ~ '~' " ': ' '" ........ t, ' .'. ""~ : ' : -': ,..T.'"'.:- ,.-' ~-.,--T/ - .-~Z2.,. ............. ~__ ,.....~,..~,:,. ;.~,, .. .-.. .. :RECTION ' ' ' " -, .,,; :,.,. .- - ~:. '"..,'.2 -, · · , ;, ... ~?~ .. -.. ..:;.,' .,.~.. · ",. · -, FROM 'i '\/- ' '"'L~ ,."" '''''~'':, ':" . -PRd~ABLE ~J:R~TION . ..... ;-'.:..:'.~.f .- ,,', OF.' BPILLA'OE' 1I, Conoce Inc. Milne Pt. Unit Preposed Drilling Supplement to SPCC 1981 ~ ¢-' , ;- ,t t ... I i . ' ~','~,-- i k~ ~ ~, · · '. - ';. ..-~ >'. . .... - . . . .~, ..---..,~ . . , ~ -. . , L ~;~ ~..~ ~ ~ ~- ~.-,~ -~ . i ~ ~-- ~ . ~ ~ ~ ~,-'J . -'~ i,t-~' ~-pROPOSED ~ L': I · - ' 'k . k '~'.L ~'~ 'x. '/~ I ' · - ~ ~.. , '-~? I MILNE PTVICINITY MAP ,, ... . .. ., .... .... '.~_. % . . .... .~ ,., · . . j · ,¢ , .--, ...... ~;~-~.~.~~ ..... PROBABLE ~IRECTION . '., ~ ~', '.' -. ' ' · ' '~~ : ', ' , "; ' ' ' . . ~ · /' - OF. SPILL.~G~ FROM 'i' ',J' '-' ~ (.-,-~ .... .. PROBABLE .~R~TION ,~~J.:,~{---:, :~--L . · . . ..... --;-.',~ ~ · ~ ~ · . ,,.% ~ '. . ~..... _ - · ' - ~. "",-t ......... .;. >,' . . .-' ,-' ...{'~ L~', - -, , .: .: - ';,.,:,' '.' ...... " "/. ~ ~ . · ' ~' ' ~. ," W ' :..:~. ~-[ :- .... . . ,- .... ~' T ; .. , ~ . · -.'. :.~ ..... , ~ ~.. , , t , .~ ,. ~, ~ ... ~,-. ~ ..~, · ~ ""' ~ '" ~ ' 1Z~-A Conoco Inc. Milne Pt. Unit Preposed Drillin~ ~98~ Supplement to SPCC SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO CONOCO, INC. 14. DESIGN AND OPERATING~INSTRUCTIONS ONSHORE DRILLING OR WORKOVER RIG a. LOCATION OF DRILLSITES This rig will be located on drillsites designed by Conoco on the North Slope of Alaska. Mobilization and demobilization of this rig is conducted only under conditions approved by the applicable Governmental Agencies. Every effort is made to coordinate the location of these drill- sites with the various Governmental Agencies and all operations personnel in order that the selected drillsite locations will meet the subsurface requirements, provide the minimum risk of a discharge or spill reaching navigable waters, and minimize any other environmental changes. The location ultimately se- lected is approved by the Governmental Agencies having.jurisdic- tion. The current drillsite location is shown by the surveyor's plat included on page 14 of this SPCC Plan. b. CONTROL OF DRAINAGE FROM DYKED AREAS Drilling and support operations are conducted wi thin the oonfines of the drillsite. Drainage of fluids from this area (including the reserve pit) is not part of the operational plans. The drillsites are constructed as shown on page 17 of this SPCC Plan. The material utilized for the drillsite construction is from local sources, as near the drillsite as possible. The ma- terial source and its extraction is approved by appropriate Governmental Agencies. The actual design of the drillsite is controlled by our Customer and/or Federal and State Regulatory Agencies. Construction of these facilities is directed by 'our Customer. All Secondary Containment features and alternate Oil Spill Contingency Plans are the responsibility of our Customer. Construction equipment and liquid pumping and transport equip- ment is kept operational at the drillsite. This support equip- ment is available for the maintenance and repair of all secondary containment structures, and for recovery and clean-up from oil spills. ~'This equipment is listed on page 40. Additionally, absorbent materials are available on the drillsite as listed on page 40. These materials are available for oil spill control and clean-up. The Parker Drilling 'Company Rig Toolpusher will immediately utilize this equipment, materials and the on-site manpower for control and clean-up of any spills. The equipment, material and Page 15 SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO CONOCO, INC. NOTE: ma. npower on-site is adequate for the complete control and clean-up of any spill volume up to the total fuel storage capacity on the Drillsite. The Parker Drilling Company Rig Toolpusher will direct the clean-up operations as specified on page 39 of this plan, for any oil spill occurring within the confines of the drillsite and/or campsite. c. DISPOSITION OF OILY EFFLUENT FROM SECONDARY CONTAINMENT The inventory of equipment for the drilling rig includes an incinerator. Disposition of oily waste materials will be in accordance with the following procedures. (1.) All used engine oil, machinery lubricants of any kind, and small volumes of spilled and recovered fuel oils will be burned in an incinerator. (2.) All absorbent materials used for oil spill clean-up which are combustible will be incinerated. (3.) The Parker Drilling Company Rig Toolpusher will direct operations for the control and clean-up of any oil spills. An outline of his responsibilities follows: (a.) Immediately preserve life and equipment. (b.) Stop the spill using proCedures consistent with the safety of life, equipment and operations. (c.) Immediately contain the oil spill. (d.) Recover the spilled material for use, if salvage- able. (e.) If the material is not salvageable, burn the material, if such burning at its present location presents no hazard to any personnel or-equipment; or: (f.~) Transport the spilled material to either a pre- selected burning site or the Drillsite reserve pit. (g.) Utilize absorbent materials as required for final clean-up of spill area, after removal of spilled material. All burning operations will be conducted under the direction of our Customer's On-Site Representative and the terms and conditions of our Customer's burning permits. Page 16 d.~ Bermed location schematic. , I l ', ~ ~"i". L ~ I :f:'~ ~.'~ Opllonel/ [ ' '' ,%~r,,mum I , 25,000 able. I I Cellor~ * ..'/',." . Eeserve Pit 4'~ ' ' . '~Droin Line. Slope = l' per 50' Deep .- To Reserve Pit s~tio. A - A' . NOTES The Cell'ar constructed around the Well under the Drilling Rig is excavated and lined with an impervious structural material. The drainline shown is representative and may be replaced by a pump with its discharge into the Reserve Pit. The Area within the dotted lines is occupied by the Drilling Rig shown on page ~0. This Area is normally surrounded by ditches which drain into the Reserve Pit. Additional Ditchings inside the Area are used as needed. 3. The Reserve Pit collects all surface fluids from the Drillsite. Its size and shape will vary. The capacity may be increased by a factor of three to five. Operational Plans developed by our Customers and local ground conditions will control the final design. 4. 5. The Fuel Storage /~rea @ the rear of the Rig receives little vehicu]ar traffic'. This also provides safety from Wellbore activities. Normally, the steel dischar[~e lines from these tanks are buried. Ti~e Orillsite size ,arid shane will vary to n~eet our Custo:ner's require- ~T~ents and to, best suit existing terrain conditions at any specific ',.:e 1 l s i re. Page 17 SPCC PLAN FOR PARKER DRILLING COMPANY CONTRACTED TO CONOCO, INC. (4.-) The Parker Drilling Co. Rig Superintendent, with the ap- proval of our Customer's Drilling Foreman, will supervise the execution of burning operations for the disposal of all oil waste materials remaining in the reserve pit upon completion of drilling operations, and at any other time justified. This procedure will be followed for disposing of any oily waste residue on any portion of the drillsite and/or campsite. e. PRIMARY CONTAINMENT EQUIPMENT The Layout of Parker Drilling Co. as assembled in an operating status, is shown on page 20 in this SPCC Plan. An Inventory of rig equipment is located on page 21. Any changes in major items of primary containment equipment (fuel and/or mud tanks) will be recorded in the space provided, reflecting changes in equipment from that listed there. The following spec.ifications apply to the 'fuel storage and trans- fer equipment included in Parker Drilling Co..Rig inventory. (1.) All. fuel storage tanks are of steel~ construction. All fuel storage tanks are atmospheric vessels, with permanently in- stal led vents. (2.) The fuel discharge connection on each tank is equipped with manually operating valves. (3.) The-fuel tanks have no autOmatic fluid level control devices. These tanks are installed, unprotected from the weather. · Arctic conditions frequently cause failure of automatic control equipment. The tank fuel levels are observed and controlled manually. (4.) Fuel is transferred to and from the storage tanks through steel lines, and/or flexible arctic grade fuel handling hoses. Expansion, contraction and vibration is not trans- ferred through these flexible sections. All lines have threaded connections, including quick-connect couplings and/ or unions. All threaded connections are accessible for in- spection and repair, if required. (5.) All liquid mud storage tanks are of steel construction. The mud tanks are atmospheric tanks with open tops. The fluid level is controlled manually in eaCh tank. (6.) All liquid mud is transferred through steel and/or high' pressure steel braided hoses, specifically designed for this application. Page 18 SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO, INC. (7.~ Drip pans are located under rig floor machinery to catch and collect lubricating oil leakage and spillage. (8.) POL Products are shipped to the drillsite in drums which have tested leakproof. Drum handling procedures are utilized to minimize damage at the drillsite. These drums are stored at central point (s) to isolate the effects of any leakage or spillage. No other means of transporting these products to the drillsite is currently available. f. CASING & BLOWOUT PREVENTION EQUIPMENT (1.) The Well Casing Programs are designed by our Customer and must be approved by Alaska State and/or U.S. Government Oil and Gas Regulatory Agencies. Parker Drilling Co. does not, in the preparation and possible implementation of this SPCC Plan, accept responsibility for or imply approval of any Wel 1 Casing Program. The Casing Programs are designed to provide the capability of controlling any wellhead pressure that is expected to be encountered by each individual component. (2.) The Blowout Prevention Equipment listed in the Parker Drilling Co, Rig Inventory, meets the known requirements for well control on the North Slope' of Alaska and those of the Alaska Division of Oil and Gas Commission. (3.) Each well program is designed, utilizing the most current data available regarding subsurface conditions, to meet the requirements of sub-paragraphs i and 2, above. Casing and BOPE of greater containment capacity will be utilized at any · time the need develops. (4.) Further, our BOPD is Periodically tested (and repaired as required) to insure continued performance of this equipment as specified by the manufacturer. Page 19 PARKER ORILI,. I I',I G RIG r,fo. 128 LAYOUf l 15. RIG Ii~VENTORY Mast and Sub--structure Lee C. Moore 136' x 1,025,000 GNC helicopter capable hi-floor mast com- plete with 6 sheave crown block, crown safety platform, winterized rack- ing platform, erection equipment, ladder, tongs, counter weights, with a 21' floor, cold temperature construction, Model ~.7415B, Ser. N. 13624. Draw~vorks TBA 2000 single drum drawworks, Ser. N. 619-01 compIete with air controls, Parkersburg 40" type 342 hydromatic brake, Ser. N. 48933, OIME four engine flat set oilbath compound with 2 way drown-o-marie. Catworks · OIME independent catworks, with two Foster Automatic catheads, Breakout Ser. N. 24AH504, makeup Ser. N. $7AH249 torque tube drive and oilbath chain rotary drive. 'Compressors . - ,.. Three - Quincy Model 3!5-15 - Ser. N. 827974-L 827967-L Spare 826362-S Power 4 Caterpillar D343B turbo charged diesel engines, Ser. N. 62B10305, 62Bl1441, 62B10537, 62B10816, all with radiator, rated at 345 HP con- tinuous, 425 intermittent, 500 HP maximum each, complete with Barber Kill Switch. Twin Disc torque convertors, Ser. N. :247128, 2-17780, 247784, 247775 and power shift transmissions Set. AT.: 395521, 395518, 397287, 365527. Winterization · Noruhwest Tent and Awning neolon rig enclosure, with 1 O0 mph wind load des' ~,' . 15FI. Driilin~ Line One t-1/4 x G, 0O0' dr~i line. Two t-!/4 x 3, 2~0' dri~ lines. Page 21 ~?ravelling Equipment Ideco Shorty 5 sheave, 265 ton travelling block - hook combimation IVlodel IJTB-265, Ser. N. 208. Set (2) 2-3/4" x 108" elevator links. Continental-Erasco LA-400 quick change assembly Ser. N. 6597-0389. 4-1/2" x 40" hexagon kelly. Varco 4KRS Pin drive bushing. Rotary Table Ideco 23-D Model SPR23D, 24" rotary table, Ser.. N. 306 ~viih solid Varco pLu drive, master bushing, Set. N. S27E. Power Tongs Lamb- Power Unit- Model LS353, Ser. N. 337 · Tong Model 16,000 Set. N. SN382 C Range 2-3/8 of 16" Ke!ly soinner -- Foster - TYPe 77, Ser. N. 77-02-10 hydranlic, 30 HP hydraulic unit, Ser. N. JH6392012. \Veicht Indicators Type D - lVith National Type D Anchor. Cameron- Type G- Ser. N. 73J5278 Automatic Driller Swaco Unit 681 Survey \Vinch Commercial Electric Drive C°, Model .~VIl%%G 15DItS, Ser. 'N. 210, line measuring device w, ith transmissions powered by 7-1/2 HP electric motor. Air IIoist Ingerso! Rand I?.U air hoist complete, Set. N. 41789. Page 22 l Acehmu!ator - Tank Cap - 244 gal. Koorney- T-15160-3S, Ser. N. 5339, with triplex pressure.pump, model T315-15-3, Set. N. 731376B-514 with two air pumps. Koomey remote control station ERC-6, Ser. N. 5339. B. O. P.'s One 20" Shaffer Spherical preventor with 20", 2,000 lb.. flan~ed bottom, BH~I 217, Set. N. 4427. One 13-5/8" Shatter Spherical preventor, 13-5/8", 5,000 lb. with hub bottom, HN-210, Ser. N. 59965. Two I3-5/8" Shatter LWS Autolock single gate preventors with hub top and bo!tom, ~vo 3" hubbed outlets, Set. N. 139659-51 and 139659-49. One 13-5/8" Shatter L'vVS Auto!ock single gale shear ram preventer, . hubbed top and botlom with two 3" hubbed outlets, Ser. N. 13969648. One 13-5! 8" 5,000 PSI hubbed spool with two 3" hubbed outlets. One 13-5/8" 5, 000 PSI hubbed spool with two 3" hubbed outlets - spare. Four 13-5/8" 5, 000 PSI CIW clamps. Twenty-One 3" 5, 000 PSI CIW clamps. Three 3" 5, 000 PSI CI'W clamps - spare. -. Seven 3" flanged 5,000 PSI Shaffer manual valves, Set. N. B02!0, B0207, B0130, B0151; B0202, B0133, B0212. One 2" 5, 000 PSI Shatter manual valve Set. N. Two 3" flanged to hub 5,000 PSI Shatter, changeover flanges. Four Shaffer 3" PSI hydraulic valves, Set. N. B0477, B0474, B0224, B0475. Six 3" flanged to hub 'adapters. Three 3" hub to hub adapters. One 3" hub lo hub adapters. 3" spare. One 3" welded hub 5, 000 PSI - In Use. Page 23 13. O. P. 's - Continued Four 3" 5,000 PSI blank hub. Two 3" 5,000_PSIblank flanged Two 3" four way block cross studded 5,000 PSI. One 3" three way cross flanged 5,000 PSI. One 3" manual Shaffer adjustable type 34 standa~t trim choke, .. · One Swaco automatic adjustable choke, Set. N. 362270, Unit Alo. 17031' with 2/1 6" choke openings. Two 3" 5, 000 PSI hubbed Shaffer checked Valves. Two bulk assemblies for 13-5 / 8" CIAV clamp - spare. Two Ten ton Coifing chain hoist A.'o. M-1007-F. TWO Three ton Coifing Chain Hoist No. M-304-F. pump . Three Hallibur!on HT400 triplex mud pumps, Ser. AL ITT825, IIT8609 complete with Gist fluid ends, Ser. N. 167, 165, 164 and 168. Mud System , Eight Helicopter portable steel mud tanks with internal piping and walkways.. 12' x 8' x 10', approximate total capacity 1,000 Bbts. Double Thompson Shale Shakers, Model B54-D, Ser. N. B54D-285. Four mud mixing units. Cat. D330, Ser. N. 4B6622, 4B6634, 4B6213, 4]E6636 with Ash centrifugal pumps, Type B-6-5, Set. N. 13540-Lr~$, 13541-UH, 13542-UH, 13543-UH. Two Automatic )/~ud Hoppers - Thompson with Crofts, Set. lxL 320 1116-6' and EXP 3455661 right angle drives. One conventional R~ud Hoppers. One Swaco Degasser, Set. N. pump Set. N. 20T224689. 8_o complete IR type 20 A%odel 255, vacuum One Pioneer 12 cone desilter, . ~:~' X. So- . . CP-~-~.5'~ w_~th on~ 30 ~,P ele~'+~';'~ .......motor, S~'- ' ~ 03o3S-059_ 5,%ode~ J1 ~- "" .. . ~. ~_o, lO cone silt master, Set. ~. Page 24 I .~'Iud System - Continued One Pioneer Centrifuge, Ser. N. C1304 complete with a Power Unit Ser, N. SPU-5 with Ash pump model tB65, Set. N. 13544UI-I. One Ash pump model B65, Set. N. 13544UH. One Pioneer desander model S2-12, Set. l~. 7363 with Caterpillar, Cat. D320, Ser. N. 4B6639, with Ash pump, Set. N. 13452UH. Two Kelly Hoses 3" ,'.R. Iax. W.P. 4, 000 PSI- Set. !~l. IVIAC-0404 MKA-007R Alarm. System One R{easurand, Model 2013, Set. N. 55. .. \Vater Tanks . . Eight steel enclosed water tanks, approximately 900 bbls. total. Fuel Tanks Eight steel enclosed diesel fuel tanks, approximately 900 bbls.... Lieht Plants Three Caterpillar D-3306, 125 KW, 60 cycle generalors each powered by Caterpillar D-3306 turbo charged diesel engines, Set. BI. 66D1.0106 Gen-:~100TI-I3651, 66D10!01.- Gen #100TH3658, 66D10105, Gen- 1002H3660. pog House Helicopter, insulated aluminum top mounted dog house with knowledge box, storage bins. V/elders . . One Lincoln Shield Arc, SAr~ 300-220 electric welding.machine, Set.. N. A7177~0, complete with necessary leads, diesel power 220F, Set. N. 695~54-6.169. One Lincoln S}~ield Arc, SAE 300, DC welder, Type S-7038, Ser. N. '7 Tv,'o Oxy Act!yenc sets complete. Page 25 illl I I · Pipe'Racks- Cahvalks Four sets (8) steel pipe racks. Two Catwalks, Boilers Four Napanee 50 HP, model 33650B, Set. N. 75937, 75938, 75939, 75940 automatic boilers. One lot of heaters, blowers, piping and controls for heating. Air Heaters One Air Heaters !nc. Model IDF-20F, Ser. N. 117, maximum burner capa- city of 3,500, 000 BTU with Iron Fireman "~Vhirlpower" Space Conditioner, model C-2400 electric controls and. other necessary appurtenances. One master air heater, Ser. N. 2256581. One master air heater, Set. N. 2256583. Drill Pipe and Drill Collars 10, 000' plus (340 its) of 4-1/2" Grade E drill pipe, plastic coated, eqUipped with 4-1/2 EH connection, flush - hard banded. 5, 000' plus (170 its) of 4-1/2" Grade X-95 drill pipe, plastic coated, equipped with 4-1/2 EH connections, not hard banded. 'Ten 8" O.D. x 2-13/16 I.D. x'30' with 6-5/8 A.P.I.~ regular connections with zip lift recess of flush-hard bandea. Thirty 6-3/4 O.D. x 2-13/16 I.D. x 30' with 5" H-gn connections with zip lift recess, flush-hard banding. 'Subs One upper kelly cock. C.~e lower kelly cock, 4-1/2 Et{ box x 4-1/2 EH pin. Two saver subs, 4-1/2 EH bo×~x 4-I/2 El{ pin. Two chan%eover subs, 4-!/2 EH boxx 5" H-90 Din. Two changeover subs, -:-I/o~ ~{ box x 6-5/8 ~',~,~-,-"_ ..~.~.~.. p_..;- C'~..~. '{-I/'~.~ ~l ~in >: ~,- 5/~ -e~,~a-. box. Page 26 ii i i I ii iii i m ii ii ii ii · ill J · Il 11 Il III I I Subs- Continued Two 6-5/8 reo~alar box x 6-5/8 regular box, Two 5" H-g0 Box x 4-1/2 reda!ar box. Twelve throw away subs, 4-1/2 EH box x 4-1/2 EH pin. Two pick up subs - 5" I1-90 pin. Two pick up subs - 6-5/8 regular pin. One stabbing valve, X-over, 6-5/8 regular pin x 4-1/2 EH box. One stabbing valve, X-over, 5" H-90 pin x 4-1/2 EI4 box. Two changeover subs - 6-5/8 regular pin x 5" H-90 box. One inside B.O.P., 4-1/2 EHx4-1/2 EH. Two hydro back pressure valves, STOP ED. 1937, Ser. AL 51306 - 6'5['8" Reg. box - Pin complete with #31031 STOP Ring #18345-4 drop valve Ser. N. 50381. 5" H-90 box pin complete with 21031 STOP ring and one 8345-4 drop valve. Handling Tools One 8" collar elevator, MGG 7-1/2 7-1/2 ID. One 6-3/4 collar elevator MGG 6-3/16 I.D. Two 4", 1 8° ~IGG, pipe elevators. Slios One set 5-1/2 x 7" Woolley type A col lar slips. One set 6-3/4 x g-l/4" Woolley type A collar slips. Two sets 4-1/2" W0olley drill pipe slips. Casin~ Tools ()ne '20~' [!-150 Web Wilson. One I6" I{-!50 Web Wilson, 150 ton elevator plus pickup elevator. !50 ton elevators plus~pickup elevator. One !3-~/~" I{-150 Web Wilson, 150 ton elevator plus pickup elevator. One 9-5/3" ?'~-!50 Web '~"'"'"° ** ~,~.>on, 150 ion elevator plus pickup elevator. t:-!50 %Veb %Vilson, ~50 ton elevator plus ~ckup elevator. Page 27 Iw Casing Tools - Continued Slips One type HCS 20" hinged spider, inserts for 16" and 20" casing. One set each CMSX casing slips for 20" and 16" casing. Combination One B.J. 350 ton, 13-3/8 slips and elevators, complete with 13-3/8, 9-5/8" and 7" inserts with Varco solid master bushing complete with 13-3 / 8", 9-5/8" and 7." casing inserts with Varco slips for 7", 9-5/8", and 13-3/8" and 16" casing. Works. hop One 40" x 38" integral with rig shelter. Mixing skid complete. Incinerator LI Il III I I __L____ HOW'ELL Refractories- model C¥100, Set. 2xl. 1052. Water Pumo and Line G-D Duplex FFFXFE, Ser. N. 625496 and Detroit diesel model PTA-41081.. 5, 200' lighting line. Fishing Equi?m ent 149' (5 its) of 10-3/4", 55.5# wash pipe.. 150' (5 jts) of 8" 31# wash pipe. 10-3/4 and 8-1/8" wash pipe drive sub. 10-3/4' and 8-1/8" conventional shoe. 9-5/8 and 7" junk subs. 10-3/4" elevators with 8-1/8" inserts.. Bowen series 150-8-!/8" overshot assembly #9815 with: 6" grapples 6" mill control packs 6-3/4 grapple 6-3/,! cut lipped guide 6-3/4 pack off Page 28 Fis{]ing Equipment - Continued , 9" cut lipped guide 9" pack off 8" back grapple 8" pla'.~ control packer One 8-1 / 8" O.D. Bowen Junk Basket complete with conventional'type "A" shoe, mag-netic insert assembly, Shoe #61955. One junk sub 9-5/8 x 6-5/8" pin'box. One junk sub 7" x 4-1/2" reg'ular pin box. O~..e 11-!/4" O.D. Bowen Junk Basket complete with convention~! type "A" shoe and ma2-netic inser~ assembly #61977. Iht ercorn System · . SOund Service - 8 station telephone system. · · Fire Fi~htin~ Ecuioment Two 2 wheeled Ansuls, model VffDC-150D · . 14 hand Ansuls 30#. Safety Equipment Si:.: Sco~ airpacks with Bauer compressor model TA!3E, Ser. N. 97762 with spare bottle. One Safety Supply resusitator. Two First Aid Kits. Stretcher baskets. Tractor and Crane Caterpillar D-5 crawler tractor, Ser. N. 963495 complete with cab angle dozer Prentice hydraglic crane Ser' ~. 8T-Z1208-7307 with hydraulic · Forl: L:ft Caterpillar To;'/ ..... or. model VSOB, Set. N. 83Rff345 complete with cab. Page 29 Toolpushers Unit 1973, 4 %~heel drive Ford Crew Cab, model F260, Set. lXl. F268CR68851. Storage Cabinets Three helicopter portable bins, side. 6' high x 8' wide x 4' deep, 8 bins per .Shale and Sand Augers Two 6" x 22' screw conveyors with 7-1/2 tIP electric motors and'shaft mounted gear reducers, Coutlf Model. Three '~Vestinghous e. Ex_haust Fans One Squirrel Gage:. One conveyor belt for shale remover - Univer~sal Trof belt model ~o. KL!8-4500, Ser. N. 1071548. Portable Centrifuge Pumps One e!eclric 3" pump Model 15CCE, Barns Two Yellow Dogs. Three Inch Pumps. Page 30 SPCC PLAN FOR PARKER DRILLI~G CO. CONTRACTED TO CONOCO INC. 16. OIL SPILL REPORTING PROCEDURE The policy of Parker Drilling Company is that: "Any and all Oil Spills will be reported." Oil Spills will be reported in accordance with the enclosed Oil Spill Reporting Procedure Chart and the following instructions. a. For the purpose of this policy, Oil Spill is defined as an accidental spill of unrefined crude oil and all refined crude oil products. This is intended as a simplified definition for the implementation of this SPCC Plan and does not supersede the meaning or intent of the definitions given in the regulations. b. Any and all Oil Spills will be reported by any and all personnel having knowledge of such Oil Spills to their immediate supervisor as soon as possible. Parker Drilling Co. Rig crew members will inform their Driller of such events. Other Drillsite personnel will notify their immediate super- visor or the Parker Drilling Co., Rig Toolpusher. This applies to all miscellaneous individual service and/or support personnel, either permanent or transient. c. The Parker Drilling Co. Drillers will notify the Toolpusher on-site as soon as possible. The Parker Drilling Co. Tool- pusher will ntoify the Customer Drilling Foreman as soon as possible. d. The Drilling Foreman and the Toolpusher will, either jointly or separately, evaluate the reported Oil Spills and make all verbal reports which conditions warrant. The attached Oil Spill Reporting Chart and Personnel Directory will be utilized. e. The Parker Drilling Co. Rig Toolpusher will. discuss Oil Spills reported to him with the Alaska Operations Manager. The report found on page 34, will then be completed as required. These written reports will be submitted as shown on the Oil Spill Reporting Chart. One copy of this Report must be kept with the SPCC at the Rig. f. The Parker Drilling Co. Rig Toolpusher will record all verbal Oil Spill Reports on his Morning Report. The name of the individual(s) receiving verbal report(s), time of day the report~(s) is given and a summary of all verbal instructions received should be included in this record. Page 31 SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. g. Parker Drilling Co. Management will process all verbal and written Oil Spill Reports, and will insure that the Customer's Operations i)ffice receives full details of the event. h. Parker Drilling Co. Alaska Division staff will supervise all liaison and administrative support required for the up-dating, revision and submission of all Oil Spill Reports, Containment Efforts and Restoration Operations. i. The subsequent written reports requested by the EPA regulations mean that: A written report will be submitted to the EPA in addition to the initial "verbal" notification of an Oil Spill. The Parker Drilling Co. Alaska Division staff will notify the appropriate Customer representative and insure that the proper written reports are submitted to Government Agencies as required. j. Listed below are excerpts and paraphrased information from the Regulations regarding the reporting of Oil Spills'. This informa- tion is provided as a guideline for the preparation of written reports. U. S. Environmental Protection Agency 1. All "discharges" or "reportable spills" must be reported to the U. S. EPA immediately. These are defined as: a. Discharging more than 1000 gallons (24+- barrels) into the U. S. Waters at one time; or b. Creating a "sheen" on U. S. Waters (.discharged oil in harmful quantities as defined in 40 CFR, Part 110) must be reported to the U. S. Coast Guard. Creation of "l.sludge" in U. S. Waters is reportable in the same manner as a "sheen". The reporting of the release of "oil" other than described above is not required under Federal Regulations. 2. Immediate Verbal Reports should include the following: a. Date and time spill occurred or was first observed. b. Where spill occurred and present location. c. Estimate of amount spilled and type of material. d. Environmental conditions: Temperature, wind direction and speed, wave action, currents, ice, snow. e. If from barges or vessels: Name of craft, registry, owner or consignee, deadweight tonnage or draft. Page 31a SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. f. Description of area likely to be affected such as river banks, beaches, properties, wildlife areas. g. Cause of spill, if determined. h. Action being taken to combat spill. i. Agencies or persons notified. Subsequent Written Reports Written reports of "discharges" are required as shown by the following regulation excerpts. However, the written report should be submitted as soon as possible. Within 60 days of the occurrence of either of these two conditions the operator must submit to the EPA Regional Administrato~ the following: a. Name of the facility. (Rig and name of current well). b. Name of the owner or operator Parker Drilling Co, and name of the Customer acting as Operator of Wellsite of the facility. c. Location of the facility. (See Location Plat.) d. Location of the facility operation (date of first drilling rig operation after January 10, 1974). e. Maximum storage or handling capacity of the facility and current normal daily throughput. f. Description of the. facility, including maps, flow diagrams, and topographical maps. Those included in the SPCC Plan suffice. Fuel system fl ow diagrams or well control system diagrams could be required. g. A complete copy of the SPCC Plan with any amendments. h. The cause of such spill, including a failure analysis of the system or subsystem in which the failure occurred. Lease production facilities may be divided into drilling, production, and gathering systems for indentification purposes in repo~ting to the EPA. These major systems can be broken down into various components o'r subsystems. The failure analysis is to examine and explain the reason for the failure Page 31b SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. resulting in the spill event. The analysis should be explicit, definitive, and not general. For instance, it would be inadequate to report simply that the cause of a spill was the failure of a storage tank. The failure analysis should indicate in some detail the nature of the failure that caused the spill. i. The corrective actions and/or countermeasures taken, including an adequate description of equipment repairs and/or replacements. j. Additional preventative measures taken or contemplated to minimize the possibility or recurrence. 4. Reports are to be made to: Mr. Raymond W. Morris, Chief, Oil Programs Telephone @ Anchorage Office: Day- 271-5083 ~' ~. Home: 344-9327 Address: Alaska Operations Office Regi on X U. S. Environmental Protection Agency 605 West Fourth Avenue Anchorage, Alaska 99501 5. Alaska State Department of Environmental Conservation a. EPA Regulations 40 CFR, Part 112.4 required all information provided'the EPA "shall be sent at the same time to the State agency in charge of water pollution control activities in and for the State in which the facility is located". b. Alaska SDC Regulations 46.03.750 (d) state: "A person in ~charge of a sea--going vessel or of an onshore or offShore facility_, as soon as he has knowl'edge of any discharge from the vessel or facility in violation of a provision of this chapter shall immediately notify the department of the discharge." Page 31c SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. c. Immediate Verbal Reports should include the same information listed for submission to the EPA. d. Subsequent written reports which are furnished the EPA should be furnished the Alaska State Department of En- vironmental Conservation. e. Reports are to be made to: Mr. Douglas Lowery Northern Regional Environmental Supervisor Telephone @ Fairbanks Office: 452-1714 Night: 456-4861 Day: 452-1714 Mr. John Jannsen Home: 488-2834 Address Northern Region Alaska State Department of Environmental Conservation P. O. Box 1601 99701'] 675 - 7th Avenue Fairbanks, Alaska 99701 Note: All area codes for all Alaska Telephone numbers is 907. Page 3!d 16. OIL. SPILL REPORTING PROC~DURE~. CHART SPCC PLAN FOR PARKER DRILLING CO.--RIG NO. 128 U.S. ENVIRONMENTAL PROTECTION AGENCY U.S. COAST GUARD ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION Written t PARKER DRILLING CO. Divisioa ,V,c~nager, Alaska ,~ Verbal Initial Verbal Written PARKER DRILLING CO. Alaska Operations Manager Initial Verbal Written PARKER DRILLING CO. Rig Toolpusher Initial Verbal Written Initial Verbal Initial Verbal Initial Verbal Individuol Support Services & Equipment, "rcr" Tr ck, ,~i G, ,, d RO O,qS~ ",'/ireiine Logging & Cementing Services Written 1 CUSTOMERS ALASKA OPERATIONS OFFICE CUSTOMER ON-SITE DRILLING FOREMAN ,_ Support Equipment Controctor Foremon Page 3!e SPCC PLAN FOR PARKER DRILLING CO. DIRECTORY FOR OIL SPILL REPORTS Area Code - 907 PARKER DRILLING CO. NAME Alaska Operations Office Bob Bullard Jack Cooper Mr. Raymond Morris, EPA Mr. Douglas Lowery, ADEC U. S. Coast Guard TELEPHONE NO. 279-0476 344-7861 349-4241 Day: 271,5083 Night: 272-8812 Day: 452-1714 Night: 456-4861 Day: 271-5137 Night: 272-8812 Page 32 SPCC PLAN FOR PARKER DRILLING CO. 18. DIRECTORY FOR OIL SPILL REPORTS A. U. S. Environmental Protection Agency Anchorage Office Night Number Note: This night number is the FAA Duty Officer. Reports given to this number are transmitted to the U. S. Coast Guard Duty Officer. The report is recorded, screened and trans- mitted to the EPA. Mr. R. W. Morris, Chief, Oil Programs Mailing Address: Alaska Operations Office Region X U. S. Environmental Protection Agency 605 West Fourth Avenue Anchorage, Alaska 99501 271-5083 272-8812 344-9327 (H) B. U. S. Coast Guard Captain of the Port and Marine Inspection Office Night (FAA Duty Officer) Emergency Number Dial 211 Ask for Zenith 5555 271-5137 272-8812 C. Alaska State Department of Environmental Conservation Northern Regional office, Fairbanks Mr. D. Lowery, Northern Regional Environmental Supervisor Mr. J. Janssen Mailing Address.~' Alaska State Department of Environmental Conservation Northern Region P. O. Box 1601 99701 675 - 7th Avenue Fairbanks, Alaska 99701 452-1714 456-4861 (H) 488-2834 (H) (H) Denotes Home Telephone Number Page 33 SPCC PLAN FOR PARKER DRILLING CO, CONTRACTED TO CONOCO INC. 19. SPCC PLAN, OIL SPILL REPORT FORM Instructions: This form is designed to provide all initial report information. More information may be required at a later time; should initial report conditions change. The Drilling Foreman and the Toolpusher should keep notes (including times and dates) of subsequent occurrences, orders received and given and actions taken by the various individuals and organizations involved in an Oil Spill. Fill in this FORM completely. Should any information blanks "not apply" mark them N/A. a. Time of Day and Date Spill Occurred or First Observed b. Date of this Report Location of Spill (Describe Location, give map coordinates, name of site, etc.) c. Present Location of Spill (Describe movement if any, of Spill; cause of movement.) d. Estimate of Spill Volume e. Type of Material Spilled f. Environmental Conditions Summary (Give ground conditions, water conditions, incquding currents or tide, temperature, wind direction and speed, visibility, ice and/or snow conditions and de~th). Page 34 SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. Attachment No. 1 f. (continued) g. Barge and/or Vessel Data (give name of crafts), registry, owner or lessee, deadweight tonnage or draft, total storage capacity of spilled material, etc.. h. Area Likely to be Further Affected by This Oil Spill (desCribe terrain such as beaches, ponds, wildlife areas, streams, etc.) i. Cause of Spill j. Action(s) Taken to Combat Spill Page 35 SPCC PLAN FOR PARKER SRILLING CO. CONTRACTED TO CONOCO INC. Attachment No. 1 j. (continued) k. Agencies Notified of Oil Spill Occurrence Si gnature Print Name This Report Prepared by: Page 36 SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. 20. RESPONSIBILITY AND AUTHORITY a. This Oil Spill Contingency Plan, as a part of the SPCC Plan for the Parker Drilling Co. consitutues an assignment of responsibility and authorizes actions to be taken in the case of any Oil Spill. The included Oil Spill Action Procedures Chart summarizes these assignments. b. The actions assigned and authorized will be implemented in case an Oil Spill occurs on any Drillsite associated with Parker Drilling Co. while located on the North Slope of Alaska. c. The Toolpusher will implement the actions outlined in paragraphs which follow this Oil Spill Contingency Plan in a manner consistent with existing conditions. He will instruct his Drillers and any other Parker Drilling Supenvisory personnel on-site to immediately execute the actions specified in Section 21'~ within existing capabilities. The Toolpusher is authorized and directed to utilize all available local materials, equipment and personnel in the execution of these actions. d. Parker Dr, illing Co, Division Manager, Alaska and the Alaska Operations Superintendent, with the appropriate Customer Operations personnel, will jointly establish predetermined Authorites, Lines of Communication, and Procedures for implementing the provisions of this Oil Spill Contin- gency Plan and any Appendix attached to it. IMMEDIATE ACTION AUTHORIZED AND DIRECTED Any and all individuals, contractors, support personnel': service company personnel and Parker Drilling Co. employees are responsible for and authorized to execute the actions listed below immediately upon detection of an Oil Spill. The Toolpusher singly or jointly with the Customer Drilling Foreman, will ensure that the procedures outlined in the following para- graphs are implemented to the limit of the capabilities of the personnel available. a. Preserve Human Life. This includes extinguishing of all smoking materials and fires which might ignite the spill. This condition is to continue until directed otherwise by the Toolpusher. Page 37 SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. b. Protect Equipment. In ad'dition to the action specified above, stop the cause of the the spill. This action includes shutting down fuel pumps, closing fuel line valves, and righting turned over and/or ruptured drums. c. ImmediatelS Contain the Spill. To the limit of their capability , all personnel should make an effort to contain the Oil Spill by: l) Directing the spill into ditches, drains and the reserve pit or other safe holding sump. 2) Utilize pumps, jets and/or pump-equipped tank trucks to pick up and/or transfer the spill to a safe holding tank or sump. 3) Process all salvageable spill material for reuse. 4) Inspect the entire area to ensure that all spilled material is contained and recovered. d. Report the Spill Event. Simultanteously with actions listed above, the Spill Event is to be reported to the Tool pusher. e. Clean up the Spill. Personnel will clean up and remove spilled material by continuation of the actions outlined and as directed by the Toolpusher using the following procedures: l) Distribute absorbent materials such as gel, barite, various lost circulation materials, or sheet absorbent or.snow over the area affected. 2) Collect all used absorbent materials carefully and completely. 3) Dispose of the collected oil spill material and used absorbents in the incinerator to the maximum extent possible. 4) Burn all other unsalvageable collected oil spill materials under the direction of the Customer's On-Site Representative. Page, ~ 38 SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. 21. SPECIFIED OIL SPILL COUNTERMEASURES TO BE EXECUTED The Parker Drilling Co. Toolpusher is authorized and directed to assume control and execute the actions outlined below in a manner consistent with his best judgement. a. Execute any action deemed necessary for the preservation of human life. b. Detect, contain and clean up all oil spills of any size occurring on any Drillsite associated with a Parker Drilling Co..operation, and the immediate vicinity thereof. c. Construct any dams, ditches or other flow controls which will provide immediate containment. d. Burn any and all unsal~vageable oil spill materials and/or waster under conditions of ~axi'mum personnel and equipment safety, as authorized by Customer Representaitves. e. Repair and/or modify any equipment as required to stop any leakS or spills. f. The Toolpusher will not commit equipment and/or personnel beyond the in~nediate vicinity of the Drillsite for oil spill countermeasures unless so doing will not jeopardize current on-site operations, and/or such action is authorized by the Customer Drilling Foreman. .~. The Parker Drilling Co. Alaska Operations Manager will, upon authorization from the Division Manager, Alaska, arrange for, coordinate and direct the mobilization of additional manpower, equipment and materials (those not locally available at the Drillsite) required for any Oil Spill Counter- measures. This effort will be coordinated with the Customer's Alaska Operations Office. h. ,All Well Control Procedure Operations will be conducted under the authority and direction of our Customer. i. The Parker Drilling Co. Toolpusher'will direct the Rig Crew actions during the execution of all Well Control Procedures. He will coordinate with the Alaska Operations Manager and the Customer Drilling Foreman, on-site, all Well Control Procedures. The Parker D~?illing Co. Division Manager, Alaska, will determine the source of authority for the direction of specific operations for extraordinary, long term Well Control Procedures. This determination will be furnished the Tool pusher as a written authority. Page 39 SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. 22. MINIMUM ON-SITE COUNTERMEASURE EQUIPMENT AND MATERIALS .. A. The following list of materials and equipment is normally maintained at the Drillsite by our Customer. This equipment will be utilized as made available by them for Oil Spill Countermeasures on the Drillsite. l) Equipment' 1 .- Bulldozer' Caterpiller D-8 with Blade and Ripper I - Loader/Forklift: Caterpillar 950 with Bucket and Forks 1 - Loader/Forklift: Caterpillar 960 with Bucket'and Forks I - Winch Truck' Bed Tandem with Gin Poles and Lowboy Trailer I - Tanker Truck- 100 bbl. capacity, equipped with pump, 50 ft. of suction and discharge hose. I - Pump- Portable Centrifugal, 300_+ gpm, engine driven with 50 ft. of suction hose and 150 ft. of discharge hose. i - Tank' Skid Mounted Portable, 50 bbl. capacity I - Pump- Positive Displacement, 4" x 6" Duplex, engine driven, portable. I - Skimmer Head' For 3" Suction Hose. I - Motor Grader' Caterpillar Model El4 wi th steel frame Leveling Drag. 2) Materials- Bentonite' For use as absorbent and well control. Weight Material. For well control and possible absorbent use. Lost CirCulation Material' Miscellaneous materials such as nut hulls, wood fibers and cellophane flakes for well contrOl and absorbent use. Absorbent Sheets' (10) Rolls, 3/8" x 3' x 150' Timber and Lumber' Miscellaneous timbers, pallets and structural lumber for use as floating absorbent booms, construction of flow barriers and dikes. page 40 II SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. Rope: (1000) Feet, 1/4" sisal, for use in floating boom construction and control. Empty Drums' Complete wi th bung hole plugs, for collection and transportatiOn of oil spill material. 23. ADDITIONAL EQUIPMENT Additional (or resupply) materials and equipment are available on the North Slope, in the Deadhorse - Prudhoe Bay area, as shown on the attached list of North Slope Supplies and Service. Page 41 SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. The following equipment and supplies, located in the Deadhorse Area, may be used in an emergency: A. High Pressure Pumps, Cement and Bulk Handling Equipment. 1 ) Dowel 1 2) Halliburton Telephone 659-2434 Telephone 659-2492 B. Mud and Weight Materials l) IMCO Service Telephone 659-2492 C. Oilfield Trucks, Floats, Tank Trucks, Vacuum Trucks, etc. l) Mukluk Freight Lines Telephone 2) Kodiak Oilfield Haulers " 659-2686 659-2648 D. Contruction Equipment- Dozers, Fork Li'fts, Scrapers, Dump Trucks, Front End Loaders, Water Trucks, Belly Dumps, etc. l) Frontier Rock and Sand/Telephone 2) Kodiak Oilfield Haulers " 3) Alaska General Const. Co " 4) S. & G Construction (Equipment on remote North Slope Wel 1 si te) Tel ephone 659-2565 659-2648 659-2445 272-4512 E. Helicopter and Air Transportation 1) ERA Avionics 2) Sea Airmotive Telephone 659-2465 Telephone 659-2646 F. General - BP Alaska and ARCO have large stockpiles of materials and equipment that they will make available for emergencies. l) BP Alaska Telephone 659-2662 2) ARCO Telephone 659-3106 NOTE: These are Deadhorse telephone exchange telephone numbers with the number...(805) being the area code. Page 42 SKILL ACTION PROCEDURES' CHART ii ii U.S. ENVIRONMENTAL PROTECTION AGENCY U.S. COAST GUARD ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION Notify and Execute Coordination and Specific Procedural Instructions MAJOR CONTAINMENT & CLEAN-UP EFFORT RESOURCES NEEDED To Support ! MOBILIZE ALL LOCAL PERSONNEL 1~ EQUIPMENT As Specifie~ By Customer CUSTOMER'S ON-SITE DRILLING FOREMAN _ oTHERi~ Cus'F'oM E RS Alaska Operations Office Notify Direct Operations PARKER DRILLING CO. Division Manager Alaska Operations PARKER DRILLING CO, Alaska Operations Manager / Notify Direct Operations As Required As Specified By Customer PARKER DRILLING CO. Drillers ~ Foremen On-Site SUPPORT CONTRACTOR Foremen On-Site Notify ALL ON-SITE PERSONNEL -- IOIL sPiL"L t DETECTION ! Notify~' , Action Action PARKER DRILLING CO. Tool'pusher 1 Operations IMMEDIATELY INSURE PERSONNEL ~ EQUIPMENT SAFETY ii, IMMEDIATE CONTAINMENT ~ 8~ CLEAN-UP EFFORT SPCC PLAN FOR PARKER DRILLING CO. Page 43 SPCC PLAN FOR PARKER DRILLING CO. CONTRACTED TO CONOCO INC. 25. MINIMUM INSPECTION PROCEDURE FOR FUEL AND WATER STORAGE AND TRANSFER SYSTEMS OF MOBILE ONSHORE DRILLING RIG EACH TOUR BY MOTORMAN A. Inspect all engine fuel Day Tanks and associated fuel lines and valves for freedom of fuel flow and leaks. B. Check fuel supply lines from fuel bulk storage tanks for leakage. Insure that supply lines laid for miscellaneous use such as BOP Accumulator, Construction and Truck Equipment Fill-up, Camp Truck, Hot Air Heaters and Boilers, etc. are intact and all control valves are functional and in the correct operating position. Insure that no ice blockage exists from accumalated water. C~ .Inspect all bulk storage fuel tanks. Insure that all vents are open, all bottom valves are functional and in the correct operating position. Gauge each tank and report fuel volumes as directed. Bottom tank'~valves will be left closed at all times fuel not being transferred. D., Coordinate with all Other personnel the transfer of ail fuel to, from, or on the Rig-Site. Report each occurrence to the Driller. Insure that all valves are left in the correct position and that all transfer hoses and' lines remain intact after each transfer. E. Inspect water storage tank(s). Insure that valves and lines are intact and that overflow or top vent is open. Report supply and availability of water as directed. F. Check each water supply line along entire length for leaks, control valve positions and to insure lines are open (not frozen). G. Motorman should report results of inspection to Driller. Driller will give instructions, as required, to the rig crew for correcting noted discrepencies. Driller will also report abnormal conditions to the Tool pusher immediately. H. The completion of this Inspection Procedure is to be recorded on the IADC Report each tour. Page 44 SPCC PLAN FOR PARKER DRILLING CO~ CONTRACTED TO CONOCO INC. 26. MINIMUM INSPECTION PROCEDURE FOR DRILLING FLUIDS SYSTEM, MOBILE ONSHORE DRILLING RIG, EACH TOUR BY DERRICKMAN A. Check Drilling Nipple, Flowline, and Shale Shaker Box for leaks and flow stoppages. Shale Shaker Screen, back side of Shale Shaker Screen including by-pass and overflow should be checked for proper functioning and fluid flow. B. Inspect Blowout Preventor Equipment, including Kill-Line and Choke Mainfolds with its associated relief lines to burn pit and reserve pit for fluid flow and presence of frozen fluids. Position of each valve in the system should be determined in accordance, with BOP Operating Procedures. C. Inspect outside of mud tanks including bottoms for fluid flow. Verify that there is no fluid flow beto~ the Cutt.ings~, know or ice. All discharge jetS and cleaning hatches between tank flowlines should be free of leaks. D. Check mud pumps, pump suction lines, pressure safety valve relief lines and high pressure mud lines in substructure to the rig floor, cement units and mud hoppers for leaks and/or freeze-up. E. Check equipment on top of each Mud Tank for proper operation. Mud by-pass troughs and lines should be clear to prevent overflow. De-~asser inlet and discharge lines and associated control valves should be open for flo~ and unfrozen. De-silter and De-sander inlet~ discharge and underflow lines should be unblocked with control valves free. Check for excessive fluid underflow. Check Mud Hopper(s) for proper operation. F. Dry Mud Materials should be protected during storage. Any large quantities of concentrated chemicals lost from dry storage or while transporting on rig site are to be recovered. G. Derrickman should report results of inspection to his Driller. The Driller will give instructions, as required, to the Rig Crew for completing action to correct noted discrepencies. The Driller will also report all abnormal conditions to the Toolpusher immediately. H. The completion of this Inspection Procedure is to be recorded on the IADC Report for Each Tour. Page 45 SPCC PLAN FOR PARKER DRILLING CO: CONTRACTED TO CONOCO INC. 27. CHECKLIST FOR KEEPING SPCC PLAN CURRENT NOTE: Minor Revisions to the SPCC Plan may be made at any time without engineering re-certification. This SPCC Plan should be kept current by making revisions when applicable. A. Fuel Storage Revise the Plan to. show any additions or deletions of fuel storage tankage. The physical and chemical properties of the stored fuel should be inserted on a current basis, Sn Part 1 of this Plan. B. Drillsite Area As-Built Revise the Plan at each new drillsite to show the "Predicted direction of flow" for any spills which escape the drillsite. This should be done by inserting into the Plan, as As-Built Contour Map of the area within approximately 2500 feet of the well. The As-Built Contour Map, used together with a USGS Topo Sheet, 1:63,360, which includes the drillsite vicinity; should be marked to show the predicted direction of flow. Sites should then be selected along the predicted flow path for construction of flow barriers (.dams). This dam construction would then takeplace , should a major spill occur. These drawings .and maps should then be inserted into this SPCC Plan. C. Drillsite and Campsite Specifications and Drawings The drawings and specifications prepared for the construction of each location should become a part of this SPCC Plan for that particular operating location. D. Changes of Riq Equipment Any additiOns or deletions of fuel or liquid mud storage equipment must be recorded. E. Add/change names of Conoco Inc~ personnel to Oil Spill Reporting Chart, and Directory for Oil Spill Repo.rting and to Part 1 of SPCC Plan as re- assignments are made. This should be done 'for Conoco and the governmental agencies al so. F. Each working copy of the SPCC Plan must include a copy of all Oil Spill Reports. G. Copies of the~SPCC Plan must be kept at all the sites of operation by Conoco personnel and the Parker Drilling Co. Page 46 DF- SP ~RILLING C. ,. MILNE PT. VICINITY MAP ~' -' MILES I ~ . _ . , -.~ {,- '-~ -. _ . . . ~..- ~ . .., ,~.. -~;;; }; ,/':*''.' ../b ,.- :.-:.:-q' ~/,:'..// ' .. . ~ ~ . · ~ ~i.. ,,...n ~ .. , , - ,.. ~ ~ / '.. '~ ..... ~ .... 28 Conoce Inc. Milne Pt. Unit Prepesed Drilling Supplement t~ SPCC 1981 MILN P'I'. UNIT ~ kGwYDYR B&Y 6 aCCESS RD.,~/ ' ~ILNE PT. VI~INITY MaLEs -PROBA DF ~RILLING ,, . . , --' i ".:' - '-- · ::-~--=-~"", '!1~;,1~1 .... :' ,ECTIONi , , ..... ', . .~. ..... ...,. , .:.~0]._ .~ .. '~, . ' .". ',-. . ' .- '.' FROM '~: ,~ - ' ~,' ~,~ -~; PROBABLE DIR~TION .~ i " ~.'- ~. ~ -- . s~ ~ ' .. : '--:'~ i '- OF ~PILL~GE FROM ~' '~:~ · ~ . -, ~ -' .' .., ~ ,~c~..:~D~ 'EQCAmION' Conoce Inc. Milne Pt. Unit Preposed Drillin~ Supplement to SPCC 1981 ACCIDENTAL DISCHARGE CONTINGENCY PLAN NORTH AMERICAN PRODUCTION CONOCO INC. ANCHORAGE, ALASKA ACCIDENTAL DISCHARGE CONTINGENCY PLAN ADVANCE PREPARATION-AND ACTION PROCEDURE ANCHORAGE D I V I S I ON CONOCO INC. TABLE OF CONTENTS INTRODUCTION ...................... This supplement to the Conoco Inc. Production Department Oil Spill Contingency Plan consists of three sections' ADVANCE PREPARATION. . . . . . . . . 2 - 7 ACTION PROCEDURE...... . . . 8 - 15 SUPPORT GROUP RESPONSIBILITIEs' . . . 16 - 18 TASK FORCE Director (Division. Manager) ............. Advance Preparation Action Procedure ........... Coordinator (Division n r ........... Advance Preparation ................ Action Procedure........----.. On-Site Supervisor (produCtion SuPerintendent) Advance Preparation ................ Action Procedure ......... Technical Advisor (6i~i~iJn E~gin~e~) ] ....... Advance Preparation · . Housing, Office Space, Jn~ Ad~i~i~t~a~i'~e A~sis~a~c~ (Division Administrative Manager) ......... Advance Preparation ................ Action Procedure . Communications SupervisOr (6i~i~i~n'D~iilin~ ~u6t])] Advance Preparation · · · · · · · · · · · · · · · · Action Procedure S~a~e'a~d F~d~r~l Age~cie~ Liaison with Local, (Coordinator, Environmental Affairs) ........ Advance Preparation ................ Action Procedure .................. Safety (Safety ~'oordinator) ............. Advance Preparati on ................ ii Page 1 2 2 8 3 3 8 4 4 9 5 13 5 5 13 5 5 13 6 6 14 6 6 ACCIDENTAL DISCHARGE CONTINGENCY PLAN Page SUPPORT GROUP Vice President, Production .............. 16 Director of Environmental Affairs . . . 17 Representative of Continental Pipelin o p n . , . . 17 Representative of Supply and Transportation ..... 17 Representative of Communications Division ..... 17 Representative of Production Engineering Services . . 18 Representative of Public Affairs Director ...... 15 Representative of Safety Division .......... 18 Representative of Insurance Director ......... 18 Representative of Medical Division Director._.. . 18 Representative of ROW and Claims Division Manager. . ] 18 Representative of General Counsel .......... 17 ACTION REFERENCES, CONSECUTIVE - Discovery ........... . ........... 9 Reporting ............... --- . . . 9-14-15 Action Determinatio~ (on-Site).. .......... 10 Containment....... .............. 10 Removal or DiSperSal. . . .............. 11 Cleanup and Restoration ............... 11-12 Final Summary. Report ................. 13-14 ACTION REFERENCES, ALPHABETICAL - Absorbents .................. 11 (Cont~i ~m~n~) 10 Booms ................. Chemicals 10 11 12 .................. 8 Communications · · · · · · · · · · · · · · · · · · -- -- -- Direction Over-all .................. 8-17 Dispatching ..................... 12 Housing ...................... 9-13 Office Space ] .... , ............... 9-13-15 Public Relations ................... 8-14-15-16 Press Regulations ......... . . . 8-14-15-16 Regulatory Agencies C~n~a~t~ ] ~ ......... . . 13-14-15 Skimming 10-11 '0~ ~i~e .................. 9 13 Supervision - . ................ - Transportation .............. .' . ....... 9-12 SAMPLE SPILL REPORT .................. 18-19 ANCHORAGE TASK FORCE ............ ...... 14-15 SUPPORT GROUP DIRECTORYRe 0 Y ' ' 'E'T'R' ' ' .......... 21 ANCHORAGE NOTIFIC.ATION DI .......... 22 AREA OF OPERATIONS .................. 23 iii ACCIDENTAL DISCHARGE CONTINGENCY PLAN ADVANCE PREPARATION AND ACTION PROCEDURE INTRODUCTION This plan outlines the general procedure which the Anchorage Division will use for the quick and orderly handling of a spill, Prevention of pollution, of any kind is a primary concern of this Division and each employee shall tho'roughly familiarize himself with the Division's obligations, and instructions on pollution prevention and conduct himself accordingly, Please ask your supervisor for clarification of instructions or regulations not clearly understood, -1- SECTION I ACCIDENTAL DISCHARGE CONTINGENCY PLAN ADVANCE PREPARATION ANCHORAGE DIVISION TASK FORCE DIRECTOR (Division Manager) ALTERNATE (Appointed) The Director shal 1 - 1. Determine that all task force members are assigned and that they have studied the oil spill contingency plan and are aware of their responsi- bilities. Determine, also, that they are kept current on all regulations and procedures that are necessary to carry out the division and/or departmental contingency plan should a spill occur. 2. Meet with the Support Group representative of public affairs and the other CoordinatOrs to determine the handling of pUblic questions and press releases. The Divi.sion Manager is the only division employee authOrized to issue public statements. 3. Schedule a task force meeting as soon as possible, and as often as needed but at not greater than. six month intervals, to a. Determine that task force members have planned together how to work together effectively in the discharge of their duties. b. Ascertain that materials and equipment are readily available. c. Assure that the Division is keeping abreast of recent developments in pollution control. d. Discuss pro61ems which are of concern to the task force and assign members to evaluate and submit recommendations. -2- Accidental Discharge - Anchorage Task Force Advance Preparation 4. Notify all third parties doing business with Conoco Inc. of the Company's pollution prevention obligations and instruct them to notify each of their employees in writing before they enter company operating areas. 5. Determine when consultation with individual support group members is advisable and make the necessary arrangements. COORDINATOR (Division Manager) The Coordinator shal 1 - 1. Coordinate over-all Division discharge response operations. 2. Assure that all operating personnel have received instructions on the Division's obligations in preventing pollution. 3. Direct the actions of the Fire and Pollution Prevention Inspection teams which will evaluate individual drilling vessels and/or platforms'and submit recommendations quarterly. 4. Furnish to operating employees a brief of all new regulatory requirements and regulations as required to meet both company as well as regulatory agenci es requirements. 5. Check with all task force members frequently and receive their recommenda- tions as to the need for additional evaluations., studies or meetings. 6. Determine if any employees do not understand what is expected of them in regard to advance planning or discharge action procedures and provide clarification. 7. Be knowledgeabl~ of OSC plans of other area operators in the event assistance is required. -3- Accidental Discharge - Anchorage Task Force Advance Preparation 8. Develop a program to familiarize all field supervisors with the Production Departmen. t and Anchorage Division Accidental Discharge Contingency Plans. Such program to include: a. Maps of areas of regulatory responsibility, pre-selected bases of operation, spill sensitive areas (near water and/or populated areas) with pertinent.information, normal currents, tides, wind, traffic, etc. b. Additional details as available on current contractor list, new materials and improved equipment. In addition to those available, discuss those which need study and development. ON-SITE SUPERVISOR (Production Superintendent) The On-Site Supervisor shall - 1. Have rough plans of actions he would take for small to large discharges in the various areas under his supervision, then: 2. Meet with his foreman and other key people and refine the plans into an action plan for each area in which, a discharge of consequence might occur. Since these plans will be limited to the material and equipment then available, they should be reviewed twice yearly by the same group in view of new information. 3. Review frequently the inventory list which is attached to the Accidental Discharge Contingency Plan and make additions, reVisions and evaluations. 4. Notify supervisors that all service people have been notified of the Company's pollution prevention obligation. It is division personnel's responsibility to see that such rules are followed. -4- Accidental Discharge - Anchorage Task Force Advance Preparation TECHNICAL ADVISOR (Division Engineer and Staff) The Technical Advisor shall - 1. Provide to the task force current technical evaluation of new procedures, products and equipment. 2. Recommend tests or studies on equipment and techniques that have potential. 3. Provide technical recommendation on the use and maintenance of exiSting equipment. 4. Contact the PES member of the support group for advice and assistance. 5. Provide and keep~current maps of division operation areas. 6. Stay abreast of pollution control problems through trade ma§azines and industry literature. Attend pollution control conferences as approved by Headquarters management. HOUSING, OFFICE SPACE, AND ADMINISTRATIVE ASSISTANCE (Division Admin. Manager) The Division Administrative Manager shall - 1. Keep current a list of offices and possible housing that may be available for assignment to other than division personnel if required. This person- nel might include Support Group members, representatives of non-operators, the press, and local, state, and federal authorities. COMMUNICATIONS SUPERVISOR (Division Drilling Superintendent) The Communications Supervisor shall - 1, Plan and discuss with the Task Force how to handle'communications within the Division as~'necessitated by a major discharge in various areas of the Division. If serious weaknesses are apparent, he shall recommend practical solutions. 2. Pre-plan the best use of telephones available for communication within and outside the Division. -5- Accidental Discharge - Anchorage Task Force Advance Preparation LIAISON WITH LOCAL, STATE, AND FEDERAL AGENCIES (Coordinator, Environmental Affairs) The Coordinator Environmental Affairs shall - 1. Keep the Division management informed on state and federal prospective and newly passed legislation pertaining to discharges. 2. Attend meetings held by regulatory personnel and by industry organiza- tions. He will keep a current list of such meetings scheduled. He will inform the Division Manager of all pertinent regulatory developments and will act as liaison between those agencies, the Division and the Headquarters Conservation Coordinator. 3. Keep current the ~ask Force and Notification Directories and Support Group 1 i st. 4. Secure and distribute copies of regulatory changes to appropriate Division personnel. 5. Establish a prOcedure for reporting and. maintaining records' of all discharges in the Division. This record also contains sighted slicks of unknown origin in our area of operations. SAFETY (LSafety Coordinator and/or Training Coordinator) The Safety Coordinator and/or Training Coordinator shall - 1. Serve as a member of the Fire and Pollution Prevention Inspection team. 2. Assist the Division management in providing follow-up control to Fire and Pollution Inspection t~am's recommendations. 3. Stress through meetings, inspections and daily contacts, the need for a constant search for malfunctioning equipment, unsafe practices and other sources of potential pollution. 4. Promote discussion of pollution control at each safety meeting. Accidental Discharge - Anchorage Task Force Advance Preparation 5. Discuss safety aspects of discharge response actions at training and employee planning meetings. Attempt to identify safety problems which might arise and pre-plan for them. -7- SECTION II ACCIDENTAL DISCHARGE CONTINGENCY PLAN ACTION PROCEDURE ANCHORAGE TASK FORCE DIRECTOR (Division Manager) ALTERNATE (Appointed) The Director shall - 1. Direct the task force discharge response and determine that all reporting and communications channels are established to adequately inform company offices and regulatory authorities of status, progress'and plans of discharge response. 2. Release information to the press and public after consultation with Headquarters and/or the Support Group representative for public affairs. In a major emergency, the public affairs representative out of Headquar- ters office will be on the scene and will handle all interviews, state- ments, and press releases. 3. Handle all contacts concerning assistance from sources not ordinarily available to the Division, if required after consultation with Headquarters management. 4. Call for assistance from individual support group members at his discretion. 5. Provide management with estimates of damage, potential hazardous conditions, and expenditures as soon as possible. COORDINATOR (Division Manager) The Coordinator shall - 1. Direct the entire Division discharge response and provide coordination between all members of task force. -8- Accidental Discharge - Anchorage Task Force Action Procedure 2. Coordinate essential transportation, communication, office space and housing needs for personnel and representatives from outside the Anchorage Division. 3. Contact weather reporting service and obtain current and forecast weather and water conditions. ON-SITE SUPERVISOR (.Production Superintendent) The On-Si te Supervisor shal 1 - 1. Provide material, equipment, personnel and transportation to and from the discharge area. Requests for personnel or equipment not ordinarily available to the Division shall be approved by Division management. 2. Assume on-site supervision, at the direction of the Division Manager, following the course of action determined best under' the circumstances. 3. Major Discharge Action Plan a. Discovery - Stopping and Reporting Discharge The ranking employee on location at the time of discovery shall deter- mine source and cause of any discharge and if it is continuing, stop it, if possible. The usual safety consideration will apply. He will then immediately report the discharge details as outlined in the Record of Accidental Discharge (.sample attached) to his supervisor. If necessary to avoid delay he will report direct to Division manage- ment. The discharge will immediately be reported to the appropriate agencies. ~' b. Di. sco.v..ery- SafetS Considerations The ranking employee on location shall direct unauthorized personnel and transport equipment away from the discharge area. -9- Accidental Discharge - Anchorage Task Force Action Procedure c. Determination of Action to Take The -foreman and superintendent will consult i~ediately with the division manager on the most appropriate action under the circum- stances. Consideration will be given to four categories: (1) Determine appropriate measures to stop or reduce discharge if it is continui'ng. (.2) Contain and remove. All discharges will be contained and removed if conditions permit this method of operation. It will be necessary to utilize containment booms, skimming apparatus, hay or other absorbents and other removal equipment. (3) Leave alone if conditions do not permit containment and removal. Under certain conditions natural disposal is the best operating procedure. This method utilizes natural wave and current action to disperse and bacterial action to dispose of the dis- charge. Natural disposal shall not be used under circumstances which may be harmful to aquatic life or wildlife or injurious to life or proper, ty. (4) If the discharge cannot be contained and removed, an effective method for handling the discharge, especially at some distance from shore, is by chemical dispersion. Approval from the appropriate authorities must be obtained before using dispersants. d. Containment If this me%hod is used, the on-site supervisors will immediately deploy the company-owned floating booms and other equipment as obtained by Di vi sion management. -10- Accidental Discharge - Anchorage Task Force Action Procedure e. Removal or Dispersal One of the following methods of disposal may be started. (1) Skimming - Contained oil may be picked up by vacuum Pumping equipment, skimmer pumps or similar mechanical means. (a) Oil recovered by this method may be separated and returned to storage for later separation or burned, if necessary, in suitable burning pits, after obtaining the necessary burn permits. (2) Absorbents such as straw, hay or sawdust may be used to pick up oil in relatively calm waters or to protect shore lines. The material is spread on or ahead of oil on water or along a shore preferably before oil reaches shore. After saturation, it is picked up manually or with mechanized equipment. Straw, hay, and sawdust must be disposed of in an approved method. (3) Chemical disperson by boat spray application of a non-toxic chemical can be used, subject to approval of the Division Manager, and i~he appropriate regulatory authorities. f. Cleanup and Restoration Cleanup of land areas, beaches, boats, boat harbors, bulkheads, etc. shall be necessary if contaminated. On the ground surface, if allowed to weather, oil tends to form a mat which facilitates removal. · (1) CleanUp will require the removal and disposal from shore areas by manual or mechanized methods -- depending on the concentra- tion and area involved. Hot water generators may be used where practical. Accidental Discharge - Anchorage Task Force Action Procedure (2) No attempt will be made to burn oil on land or water without Division management approval. (3) Chemical cleaning of land areas will not be attempted without Division management approval. Selection of materials for clean- ing structures and other surfaces will be based on technical advice in regard to specific conditions. Detergent scrubbing and washdown normally will be the most practical on hard sur- faces. Detergent is not recommended for use on beach sand. (4) According to the degree of emergency, as determined by consul- tation with Division management, the Production Superintendent will arrange work schedules to provide relief for essential employee assignments. Production Superintendents of other areas will provide assistance as required. Genera 1 (1) A dispatcher will be assigned to assist the on-site supervisors where deemed necessary. (a) Determine status of all transportation equipment in Division service and have them in contact for possible reassignment. (b) Keep an accurate log of all dispatched transportation for immediate reference. (c) Contact weather reporting service and obtain current and ~forecast weather and water conditions. Keep such information plotted on an area map. -12- Accidental Discharge - Anchorage Task Force Acti on Procedure TECHNICAL ADVISOR (Division Engineer and Staff) The Technical Advisor shal 1 - 1. Provide advice and assistance to the on-site supervisor. Such assistance will include more or less constant communication between the on-site supervisor and the Division office. Verbal reports shall be communicated to the task force headquarters, at intervals established by the Director for each discharge where they will be distributed to members of the task force and support group. 2. Provide advice to other members of the task force and support group. 3. Prepare the final summary report on a major discharge with assistance from other task force members. Report to cover actions performed and resul ting effectiveness. HOUSING, OFFICE SPACE, AND ADMINISTRATIVE ASSISTANCE (.Division Adm. Manager) The Division Administrative Manager shall assist the Coordinator - Environmental Affairs in the following: 1. Provide assistance in initial notification of regulatory agencies and advise Division Manager of all details of reporting requirements. 2. Assure that all required written reports are. completed and distributed promptly. All reports and information on major discharges will be assembled and filed for immediate reference until the entire spill response is completed. 3. Keep a perman6nt record of all spills as required by regulatory agencies. COMMUNICATIONS (Drilling Superintendent) The Communications Supervisor shall - 1. Establish a network of communications to provide two-way communications -13- Accidental Discharge - Anchorage Task Force Action Procedure between discharge area and discharge operations control center at all times. Assign priority according to degree of emergency. Recommend best use of walkie-talkie radios. 2. Make available the usable radio channels of aircrafts, boats and automotive units that may be used continuously during discharge control operations. 3. Assist in arranging telePhone and other communications for support group members present in Division. LIAISON WITH LOCAL, STATE AND FEDERAL AUTHORITIES (.Coordinator - Environmental Affairs) 1. Handle all contacts with regulatory authorities after consultation with the Division Manager. 2. Be available during an emergency to assist Division management in consider- ing the possible extent of liability, legal entanglements, and public relations. May be asked to .handle contacts with certain support group members, such as Representative of General Counsel. 3. Advise Division management on regulatory considerations. ORGANIZATION An Oil Discharge Task Force has been developed and is listed below: Function Di rector/Coordinator Division Superviso~ Technical Supervisor Housing & Office Space Title Division Manager Producti on Foreman Engineer Division Admini stra- tive Manager Name and Home Phone Number H. D. Haley D. M. McCoy A. E. Hastings Accidental Discharge - Anchorage Task Force Action Procedure Function Communication Supervisor Liaison Coordinator Loca 1 -S tate- Fede ra 1 Technical Advisor Safety Coordinator Title Dri 11 ing Supt. Env i ronmen ta 1 Analyst Engineer Coordinator- Training and Safety (Area Code 907) Name and Home Phone Number T. S. Lucht J. T. Dosch G. A. Merriman J. T. Dosch -15- SECTION III ACCIDENTAL DISCHARGE CONTINGENCY PLAN CONOCO INC. - PRODUCTION DEPARTMENT SUPPORT GROUP RESPONSIBILITIES VICE PRESIDENT, PRODUCTION Responsibilities of the Vice President, Production - 1. The department and Division accidental discharge contingency plans are complete and understood by concerned operating personnel. 2. Personnel have been assigned to specific discharge response duties and that provision has been made for employee i~nstruction and training. 3. Regulations, local, state and federal are understood with provision for follow-up on the frequent changes. 4. When a major di~scharge occurs: a. Assume direction of the entire Conoco discharge response at his discretion. b. Call other members of the Support Group to the discharge headquarters, individually, as needed. REPRESENTATIVE OF PUBLIC RELATIONS AND COORDINATOR Responsibilities of this Support Group Member - 1. Meet with Division task force representatives during the development of Division accidental discharge contingency plans and agree on a method of handling all poblic contacts. Plans will include examples of how to handle requests for interviews or questions from various sources and examples of press releases and when to use. -16- Acci.'dental Di schar§e - Support Group Responsibi 1 it!es 2. Be prepared at all times to assist the Division task force with publi- city and public relations problems which might arise on even a very small discharge or a discharge from other than company sources. 3. Be prepared to be called to the scene to directly handle all public relations on any discharge ~when requested by the region or headquarters management. 4. When a major discharge occurs: a. Be prepared to go to the scene on short notice and stay until the emergency is over and the final public and press relations have been handled. REPRESENTATIVE OF GENERAL COUNSEL Responsibilities of these Support Group'members - 1. Provide advice and counsel during the development of accidental discharge contingency plans for all Production Department divisions. 2. Study the accidental discharge contingency plan and be informed on those matters on which their advice would possibly be requested in the event of a discharge of disaster proportions. 3. When a major discharge occurs: a. Be prepared to go to the scene on short notice and stay as long as advice and assistance in their special fields are required. b. Furnish advice and assistance by telephone as requested. DIRECTOR OF ENVIRONMENTAL AFFAIRS REPRESENTATIVE OF SURFACE TRANSPORTATION REPRESENTATIVE OF TELECOMMUNICATIONS -17- Accidental Dischar§e - Support Group Responsibilities REPRESENTATIVE OF PRODUCTION ENGINEERING SERVICES REPRESENTATIVE OF SAFETY DIRECTOR REPRESENTATIVE OF INSURANCE DIRECTOR REPRESENTATIVE OF MEDICAL DIVISION DIRECTOR REPRESENTATIVE OF ROW AND CLAIMS DIVISION MANAGER -18- Ir¸ CONOCO INC. Record of Accidental Discharge of Crude Oil or Hazardous Substances [I. Depar tm~:nt 3. Person Reporting Discharge 4. Discharge Discovered By Witnesses IDivision or Plant 2. Date and Time Initial Report Received Person RecEiving Report IDate and Time Discovered 5. How did Company Learn of Discharge '6. Date and Time Discharge Began IDate and Time Discharge Ended 7. Person in Charge of Site 8. Discharge Site 9. Type of Equipment or Operation Involved 10. Specific Source of Discharge 11. Name.and Volumes of Substances Involved 12. Nature and Extent of Area Affected by Discharge 13. Water Courses Reached 14. How Was Discharge Stopped 15. Possible Reason for DisCharge 12-65 BA, 2-74 16. Operating Conditions at Time of Discharge .. 17. General Weather Conditions at Time of Discharge 18. Third Parties Involved in Activities in Area Before or After Discharge .. Proximity and Type Activities 19. Federal State and Local Agencies Notified Aqencv Person Notified DatejTime Notified Method Used =Person Notifying ................. , ...... .... ,. . , , __ 20, Onsite Investigators (Non-Companyl 21. Remedial Action Taken · Date Started ," Time Completed 22. Assistanco ~.equired, Contractors Used, Costs ,§n~ture Title Location 2O NORTH AMERICAN PRODUCTION ACCIDENTAL DISCHARGE CONTINGENCY PLAN SUPPORT GROUP DIRECTORY CONOCO INC. Post Office Box 2197 Houston, Texas 77 001 Telephone: (713) 965-1000 Member Departmental Di rector Representative Representative Representative of: 1. EnVironmental Affairs 2. General Counsel ~ 3. Insurance 4. Medical Division 5. Production Engineering Services 6. Public Relations 7. Purchasing 8. Right-of-Way & Claims Division 9. Safety Director 10. Surface Transportation 11. Telecommunications Home Phone V. C. Eissler W. K. Dietrich J. E. Whitman (713) 723-1956 (713) 491-6616 (713) 965-1384 J. A. Queen (713) 96.5-2646 C. R. Hampton (303) 575-6008 Ted Rhodes (.713) 965-2756 J.R. Drumwright, M.D. (405) 762-3456 L. B. Curtis A. B. Amsden R. F. Wilkinson W. R. Casserly, Jr. C. H. Klunick Bob Walker W. L. Link (.713) 965-1310 [713) 965-1037 (713) 965-1492 (.713) 965-2169 (713) 965-2336 (713) 965- 2060 (405) 762-3456 Note: Representatives listed are responsible for providing the Support Group member. 21 U. S. Environmental Protection Agency Anchorage Office R. W. Morris, Chief, Oil Programs Nm 271-5083 344-9327 Mailing Address: Alaska Operations Office Region X U. S. Environmental Protection Agency 605 West Fourth Avenue Anchorage, AK 99501 U. S. Coast Guard Captain of the Port and Marine Safety Office 271-5137 Alaska State Department of Environmental Conservation Northern Regional Office, Fairbanks D. Lowery Northern Regional Environmental Supervisor J. Janssen Environmental Engineer 452-1714 H- 456-4861 H- 488-2834 Mailing Address: Alaska State Department of Environmentai' Conservati on Northern Region Post Office Box 1601 604 Barnette Street Fairbanks, AK 99707 22 MILN[ PT. uNIT 4'.. M[kNE PT. VICINITY MA~ ., f · · · · i .~,:-~<.: ..... . · i;~ .-. t ..r .~ .~. ,'.'.-?'. '. ......... ~ ....... ~.~,. £ t' ~.ROBABLE:. DTRE~T 02] SPI.LLAGE-FKO~-: 28 Conoco Inc. Milne Pt. Unit Proposed Drilling Supplement to SPCC 1981 23 [0¸ Number eao ea. ea. ea. ea. ea. ea. 15OO' 200' 700' 200' ea. ea. ea. ea. 2. ea. ea. ea. 800' 11 ea. ea. em. ea. ea. ea. em° ea. ea. ea. ea. 1 eao ARCTIC OILFIELD ENVIRONMENTAL SERVICES, INC. PHONE: 279-6117 TELEX: 26618 ARCTIC OILFIELD EQUIPMENT LEASING DAILY RATES, Recovery Systems 2" Centri Pu~ps 2" Diaphram Pumps 2" Waterous Float Pump (Fire Washdown) 1~" Pressure Pump 3" Trash Pump 3" Centri Pump 3" Diaphram Pumps Hoses 3" Suction Hard Hose 2" Suction Hard Hose 1¥' Fire Hose 3" Discharge. Hose Hose Floats S~par. ator & Skimmers 2000 Gallon Air Berm 3000 Gallon Air Berm 1000 Gallon Air Berm Olea Oil Skimmers 48" Manta Skimmers 48" + 36" Flexible Scavenger Oil..Skimmer Zl4E CSI Mop Skimmer CSI Mop 100' CSI Mop Idler Pulleys CSI PUZ638C Pumping Unit Storag.e.. 10,000 Gallon Goodyear Bladder 20,000 Gallon Goodyear Bladder 50,000 Gallon Uniroyal Bladder 3,000 Gallon Uniroyal Bladder Boats 16' Boston Whaler w/35 H.P. Johnson 15' Silver Liner Inboard Runabout Avon 16' w/25 H.P. Johnson 12' Avon w/15 H.P. Johnson 21' Aluminum Riverboat w/Twin 75 H.P. Johnson Jet Drives. 321 Aluminum Jet Barge w/Twin 460 Ford & Hamilton 1031 Jet Units ~ 24 ARCTIC OILFIELD EQUIPMENT LEASING DALLY RATES Page 2 Number Mbtors ,,, 1 em, I ea. 6 H.P. Johnson Outboard 15 H.P. Johnson Outboard ea. ea. ea. ea. ea. ea. ea. ea. ea. ea. Misc. ea. Support Equipment STIHL Abrasive Saw 8" STIHL Auger w/Extension 8.8 CFM Air Compressor SIOUX Steam Cleaner Chain Saws Space Heater Hot Air Heater (HOTSY) Ventilating Fan (24") Miller Welder - Gas Driven Victor Cutting Equipment w/Bottles Hand Tools Large Quantity Thunderbolts'Electric Welder 2 ea. 2 ea. 2 ea. Safer7 MSA Explosion Meters Scott Air Packs Emergency Oxygen Apparatus Ram 5 Air Packs Emergency Oxygen Apparatus Generators i ea. i ea. 2 ea. I ea. 3.5 KW ONAN Generator Set 3.0 KW ONAN Generator Set 6.0 KW Lite Plant w/25' Lite Tower 10. KW Lite Plant w/25' Lite Tower 2 ea, 2 ea. 5 ea.- 6 ea, Specialized Support Equipment Radios SSB Base Unit VHF Base Unit SSB Mobile Unit Hand-held SSB Unit 3000' 1000' 24 ea. 2000' 8 ea. 1 ea. 10 ea. 1500' 2 sets 200' Containment Ocean Dike Compactible Boom 10"x14" Ocean Dike Compactible Baby Boom 4"x6" Boom Lights Tow Line Tow plates Boom Repair Kit Anchors Harbor Dike Boom Ground Anchor Sets Kemper 6" x 8" Boom 25 ARCTIC OILFIELD EQUIPMENT LEASING DAILY RATES Page Sorbents 3M 156 Pads 3M 151 Pads 3M 157 Pads 3M 270 Boom 3M 126 Sweeps Large Quantity Large Quantity Large'Quantity Large Quantity Large Quantity Vehicles and Equipment 74 76 78 78 78 75 78 7O 75 71 72 75 67 77 66 77 Ford Flatbed Dump Truck 1/2 Ton GMC Pickup 4 W.D. 3/4 Ton Chev. Pickup 4 W.D. 1 Ton 3x3 Crew Cab 4 W.D. 1 Ton 3x3 Crew Cab 4 W.D. 1 Ton 3x3 Crew Cab Step Van ,. ~ 20' Cargo Van ~/lift Gate Gin Pole Truck~ Vac Truck 59 Barrel 3 Axle Flat bed Trailer lO'x20' 20'x 8' Gooseneck Trailer Series 25 Rubber Tire Crane (Pettib°ne 12.5 ton) Model Bob Cab Loader ~/TRA and Misc. Equip. 40' Miller Semi Trailer Fleet Lion Lift~ll Forklift * Ail vehicle mileage rates are subject to change due to the rise in gas prices. * Fuel prices are not.included in the equipment rental rate. * Rate per day is for 24 hour period. * All equipment on the hourly rate will be billed with a minimum of four (4) hours per call-out. * Rate will not appl~ if equipment is broken down. "2 each ']09 each 1 each 1 each 1 each 1 each 2 each 1 each 4 eaCh 1 each 2 each 1 each 1 each 1 each 1 each 1 each 1 each 1 each 1 each 1 each 1 each 1 each 1 each 1 each 3 each 2 each 2 each 3 each 1 each 2 each 2 each 6 each 6 each 65 each 6 each 2 each 10 each 18 each 19 each 2 each Imperial Survival suits w/high rider ring Gentex Comfort King II's, life vests 2 pc. Stearns float suit Sears battery charger S/N CH274365 e-ton floor jack S/N 30734 Sanyo Mi cr_owave Oven Ice augers Polaroid One Step Anchor and Buoy System Boxes Fittings box Radio cases w/comb, lock black .- Scale Craftsman tool chest 160 PSI shop air compressor Oxy/ace/ set- portable Portable, breathing oxy. rack w/bottles Drill bit sharpener Pallet jack Banding machine 3/8" drill motor ½" drill motor Skil 1 saw ' Belt sander Router Titan II elec. heaters Bench vi ces Rescue baskets Hand trucks Personnel kit - includes flashlights, protective clothi.ng, emergency rations, etc. Hyd. hose kit 100' sections l" pneumatic .hose Small orange RD cones Large orange RD cones Empty 55-gallon drums Empty 25-gal lon drums Tarps Buoys Rolls clear plastic bags Extension cords Stokes stretchers Miscellaenous line, shackles, lashing gear, first aid kits. 27 nvironmental ervices, Inc; DRAWER 4-2455 · ANCHORAGE, ALASKA 99509" BUS. (907) 279-6117 · TELEX 26618 September 18, 1980 ":';5:,?!""7%~.., Conco, I nc. '~' 7'?!~7290 Maple Court ' ¥:" :Venture, CA 93003 . ...., .: Attention: Mr. Dave Dooley - Dear Mr. The following 'letter and enclosure verify with our agreement that ArctiC. Oilfield Environmental Services has the following equipment. as: listed in the attached available ?.to Conco, Inc.""'and can and.~.~ill be dispatched in a matter 'of a few hours to 'anywhere in the state for Conco providing .......... .weather and-aircraft inable us to move. . . ...:-_'-_. - ~ '.'::'.. :Arctic ' Oilfield EnvirOnmental- Services 'j also...: has ..~] ... - .... '-pers$nnel available to be dispatched''t° '~nYwhe.re in..Ala '" ..... -'.with its 'eqUi'pment "°n" the '[ Same time period."_iNormai!y "~ ...- aircraft available.. "and:'Weather~ Permitting w'e::'a:~:'":'i'Ble to be on site anywhere in Alaska' within approximately six hours upon notification of a:""spill or an emergency. :?% .?,., ,, We appreciate the opportunity to serve Conco, Inc. -' the state .of_ Alaska. .. _. ' " -- ,'-~,,,., ,,-7 ::*,, ~ . ", ,.. '- .~.:...K,? ..... -. . Very truly yours, ,_ .; .. . .. ARCTIC OILFIELD ENVIRONMENTAL SERVICES ' ' . .... Glenn Newton .... ~ ' President GN/jm Enclosure 28 A:?.ia[e of Arc::c C.',f:eid Serwces 1. Miida ITEM ' MAKE MODEL SERIAL NUMBER · MISC. OFFICE EQUIPMENT Calculator (2) 2. Burrough Calculator 3. Ricoh Calculator 4. Hewlett-Packard Calculator 5. Casio Pocket Mini Calculator 6. Kodak Carsouel Auto Focus 7. IBM Correcting Selectric II 8. Panasonic Auto Stop Sharpner 9. DatagraphiX 1400 Microfiche Viewer 10. Casio Mini Printer 11. Lanier Microsette 60 Recorder (3 each) IOPD T-801 Ricomac 67 760H KP~-77A 401-P 09773551 08772788 137754 19158 1712502120 3372356 26-2968751 46664 3232419 92858 94769 95269 109116 1527105 3843585 1321304 (H038135 ) 12. Lanier Model MCT Transcriber 13. Minolta 35 MM SLR Camera 14. 50 Mid lens ('1) 15. 135 MM lens (1) ' ITEM MAKE MODEL SERIAL NUMBER MISC. SUPPORT EQUIPMENT (continued) 16. Ventilating fan 24" explosion-proof 17. 02/Explosion Meter 18. H2S Meter 19. Cut-off saw 20. Arc welder 21. Shop compressor 22. Table saw 23. Oxy/Acetylene set 24. Set shop mechanic's tools · 25. Bench grinder 26. Parts washer 27. Battery charger 28. Dynanometer 29. 3 Portable light stands- (2) 500-watt lights/stand 30. 4 Explosion proof light systems 31. 2 Chemical resistant suits 32. Supplied air breathing syStems- Gastech Homel i te XL-98 63431 O07 Lincoln TIG 300/300 AC339668 Melben 518594 Craftsman 113 299040 Victor ~ Craftsman Craftsman ~9719451 Kleer-Flo 70 10666 Solar CH2 74365 Chati 11 on WT-10 4606 MSA MSA 33. Double drum salvage beech winch, (2) 8000-lb anchors, Crown buoys, wire, complete two-man surface supply diving van. S~CES~ =-~-! ILF~D , INC. EQUIPMENT LIST MAY- 1980 I. CC~STRUCPION EQUIPMENT A. C}~qES UNIT SERIAL NL%mER NUMBER YEAR (2) 1070 (2) 1853 (2) 1854 (2) 5014 33951 1968 41474 Lorain Pmni~ Manitowoc DESCRIPTION 50-Ton Rubber ~'~eeled Crane ~DL 4100 Crane ~.~ #34 ~,DL 4100 Crane A~ # 37 MDL 4100 Crane AMF #36 B. DOZERS C. D. ~D[~G~IPI~/LOADERS . II. ROLLING STOCK A. TRUCKS 1. HIG~TLY TRACTORS (T) 8001 (T) 8002 (1) 1001 (1) 1004 (3) 1002 (3) 1003 (3) 1041 (3) 1043 (3) 1054 (3) 1060 (3) 1061 (3) .1.097 (3) 1098 (3) 1099 (3) 8801 (3) 8802 (3) 8803 (3) 8804 (3) 8805 (3) 8806 (4) 1657 (4) 1727 (4) 1728 (4) 1747 (5) 1601 (5) 1617 77V9249 1978 CAT 77V9250 1978 CAT 9642679 1978 CAT 9641479 197'9 CAT .50W2321 1978 50W2100 1978 64435846 1965 F620420 1967 571346 1964 85603074002242 1974 35603074002263 1974 35603074002492 1975 36603074002348 1976 35603074002413 '1976 76J13462 1978 76J13441 1978 76J13343 1978 76J13204 1978 1979 1979 110827 1969 66820P 1974 66816P 1975 1473738 1975. 106354 1966 K067S5220 1969 CAT CAT Holt Datsun Clark Hough Hough Hough Hough Hough CAT CAT CAT CAT CAT CAT Peterbilt Peterbilt Kenworth D8K Tractor D8K Tractor 14G Motor Grader 16G Motor Grader 988B ~eel Loader-Lease to N?~ -988BWheelLoader-~se to h~13 Forklift 4500 LB Warehouse Forklift 2500 LB.Forklift H90E 7-tonLoader/Forklift H90E 7-ton Loader/Forklift 90E 7-tonLoader/Forklift Hg0E 7-ton~Loader/Forklift H90E 7-ton Loader/Forklift 966C Wheel Loader 966C Wheel Loader 966C Wheel Loader 966C Wheel Loader 966C Wheel Loader 966C Wheel Loader 3-axleTractor 3-axle Tractor 3-axle Tractor 3-axle Tractor 3-axle Tractor W/Winch 3-axle Tractor W/Winch PACH~ 2 o~8 PAGES OILFIM~D , INC. EQTj IPI,~ LIST ~D~Y- 1980 II. t'~LLING SIY)C24 A. TRDC3%S 1. HIGt~'~Y TRACTORS 2. } .~AVY ~5~UL TP, ACIORS UNIT NU~ER (6) 1736 (6) 1737 (6) 1738 (6) 1742 (6) 1746 (6) 1748 (7) 1743 (7) 1744 (7) 1745 (7) 1750 (8) 1751 77189P 1975 77190P 1975 77191P 1975 77195P 1975 147372S 1975 147374S 1975 1473698 1975 147370S 1975 147371S 1975 1473768 1975 · 145897C 1975 Peterbilt Peterbilt Peterbilt Peterbilt Kenworth Kenworth KenWOrth Kenworth Kenworth K~nworth 4-axle 4-axle 4-axle 4-axle 4-axle 4-axle Tractor Tractor Tractor Tractor Tractor Tractor 4-axle 4-axle 4-axle 4-axle Tractor W/Winch Tractor W/Winch Tractor W/Winch Tractor W/winch 4-axle Tractor W/Winch 3. OILFIEID BFITI'ANDEMS (9) 1607 (9) · 1~615 (9) 1631 (9) 1633 (9) 1639 (9) 1640 (9) 1641 (9) 1642 (9) 1643 (9) .1644 (9) 1645 (9) 1647 (9) 1648 (9) 1664 (9) 1665 (9) 1666 (9) 1667 (9) 1668 (9) 1669 (9) 1670 (9) 1671 74950 1961 107759 1966 84314 1969 FD27063H 1963 84804 1969 84805 1969 84806 1969 84807 1969 84808 1969 84809 1969 84810 1969 84812 1969 84813 1969 84981 1976 84982 1976 84983 1970 84984 1970 84985' 1970 84986 1970 84987 1970 84988 1970 Kenworth Kenworth Internationa1 Kenworth Kenworth Kenworth Kenworth Kenworth Kenworth Kenworth Kenworth Kenworth 'Kenworth Kenworth Kenworth Kenworth Ker~orth Kenworth Kenworth Ken%~orth 3-axleOilfield Winch Truck 3-axle Oilfield Winch Truck 3-axle 3-axle 3-axle 3-axle 3-axle 3-axle 3-axle 3-axle 3-axle 3-axle 3-axle 3-axle 3-~[le 3-axle 3-axle 3-axle 3-axle 3-axle 3-axle Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck, Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck OilfieldWinchTruck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck PAC~ 3 II. ROLLING S'ICCK A. TRUC}CS 3. OIIYlE[D BEIYfT~NDt~S OILFI~,D S~ICESi-I~. EQUIPbK~T LIST ~ lvl~y- 1980 UNIT SEIAIAL NI~4BER NT~ER YEAR (9) 1672 (9) 1673 (9) 1694 (9) 1595 (9) 1753 (9) 1754 (9) 1755 (9) 1756 (9) 1757 84989 1974 84990 1970 5583406371795 1969 5583406371597 1969 Z019YHM085885 1978 900961C 1978 9009GOC 1978 900959C 1978 900958C 1978 Kenworth Kenworth International International White Kenworth Kenvx)rth Kenworth Kenworth DESCRIPTION 3-axle Oilfield Winch Truck 3-axle Oilfield Winch Truck 3-axle Oilfield Winch Truck 3-axle Oilfield WicnhTruck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck Oilfield Winch Truck (A) 1619 · 72536 1960 (A) 1637 114620 1969 (A) 1638 114621 1969 Kenworth Kenworth Kenworth 3-axle 6 WD Oilfield Winch Truck 3-axle 6 WD Oilfield Winch Truck 3-axle 6 WD Oilfield Winch Truck 4. ~'~TER TRUCKS (c) (c) (c) (c) (c) 1646 1758 1759' .1760 . 1761 84811 1969 159734S 1978 159733S 1978 159736S 1978 .. 159735S 1978 Kerm~prth Kenworth Kenworth Ken~0rth Kenworth 150 BBL Water Truck 110 BBL Water Truck 110 BBL Water Truck !10 BBL Water Truck 110 BBL Water Truck 5. FUEL RIRUCKS (D) 1741 77194P 1975 Peterbilt 4200GAL. Fuel Truck 6. V~.~T~ TRUCKS (E) 1626 (E) 1749 114457 147375S 1969 1975 Kenworth Kenworth 72 BBL Vacuum Truck 3-axle Vacuum Truck B. TRAILERS 1. FLATBEDS (K) (K) (L) (L) (L) (L) (L) (L) (L) (L) 1225 1349 1342 1343 1345 1347 1348 1361 1369 1382 GL81579006 7N47322007 1968 1974 AMC6143 1974 AMC6144 1974 AME6146 1974 AMC6148 1974 AMC5895 1974 AMC6432 1974 AMC6434 1974 AM26680 1974 Utility Utility Ashdown Ashdown Ashdown Ashdown Ashdown Ashdown Ashdown, 41 FT. Flatbed Trailer 40 FT. Flatbed Trailer 455T. Flatbed Trailer 45FT. Flatbed Trailer 45 FT. Flatbed Trailer 45 FT. Flath~ Trailer 45 FT. Flatbed Trailer 45FT. Flatbed Trailer 45 FT. Flatbed Trailer 45FT. Flatbed Trailer OILFIELD CE · . FI2UIPME~r LIST ~Y- 1980 II. ROLLIr,'G STOCK B. Ti~AILERS 1. FLRTBEDS UNIT SERIAL NL~3ER NUN~ER YEAR (L) (L) (L) (L) (L) (L) (L) (L) (L) (L) (L) (L) (L) (L) (L) (L) (L) (L) (0) (O) (O) (0) (0) (0) (O) (O) (0) · (o) (o) (o) (o) (o) (o) (o) (o) (o) (o) 1383 1384 1392 1400 1402 1403 1404 1411 1413 1414 1419 1431 1433 1437 1439 1440 1441 1443 · 1248 1249 1250 1251 1252 1253 1254 1255 1256 1257 1264 1265 1266 1267 1268 1269' 1292 1293 1294 A~E6681 1974 A~6682 1974 A~E6699 1974 A~6660 1974 ~6692 1974 A~E6693 1974 AMC6694 1974 AMC6685 1974 AMC6687 1974 AMC6702 1974 AME6733 1975 · AM£6813 1975 A~,~6811' 1975 ~6825 1975 A~4C6737 1975 AMC6739 1975 AMC6824 1975 AMC6826 1975 5759 1969 5760 1969 5761 1969 5762 1969 5763 1969 5754 1969 5765 1969 5766 1969 5767 1969 5768 1969 PFS167669 1969 PFS1676A 1969 PFS1676B69 1969 PFS1676C69 1969 PFS1676D69 1969 PFS1676E69 1969 6004 1970 6005 1970 6006 1970 Ashd0wn Ashdown Ashdovm Ashdown Ashdown Ashdown Ashdown Ashdown Ashdown Ashdown Columbia Columbia Columbia Columbia .Columbia Columbia Columbia Columbia Columbia Columbia Beall Beall Beall Beall Beall Beall Columbia Columbia Columbia DESCRIPTION 45 ~f. Flatbed Trailer 45 FT. Fla~ Trailer 45 FT. Flatbed Trailer 45 FT. Flatbed Trailer 45 FT. Flatbed Trailer 45 FT. Flatbed Trailer 45 FT. Flatbed Trailer 45 FT. Flatbed Trailer 45 45 45 45 45 45 45 45 45 45 FT. Flatbed Trailer FT. Flatbed Trailer FT. Flatbed Trailer Flatbed Trailer Flatbed Trailer Flatbed Trailer Flatbed Trailer Flatbed Trailer Flatbed Trailer Flatbed Trailer 4O 40 40 40 40 40 40 40 40 4O 40 40 4O 40 40 40 4O 40 40 FTe Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float Oilfield Float PAGE 5 PAGES II. ROLLING E[CCK B. T[{AILERS 1. I'LATB ~EDS , B. Tt%k~IIERS 2. L~'~OYS OILFIELD INC. EQUIPMENT LIST MAY- 1980 UNIT SERIAL 5rU~.KK~ NU~..~ 'ER YEAR (O) 1295 (0) 1296 (0) 1297 (O) 1298 (O) 1299 (O) 1300 (0) i30i (0) 1308 (0) 1309 (0) i3iO (0) 13il (0) 13i2 (0) i3i3 (0) i346 (0) 134i (0) i373 (0) 1374 (M) 1233 (M) 1258 (M) 1259 (M) 1260 (M) 1261 (M) 1262 (M), 1263 (M) 1270 (M) 1271 (M) 1272 (M) 1273 (M) 1274 (M) 1275 (M) 1276 (M) 1289 (M) 1337 (M) i358 (M) 1449 6007 6008 6009' 6010. 6011 6012 6013 711862 718863 ..711864 ,711865 711866 711867 115198 5123 5124 1970 1970 1970 1970 1970 1970 1970 1971 1971 1971 1971 1971 1971 1968 1969 1974 1974 PMT160769 PMT1607A69 PMT1607B69 PMT1607C69 PMT1607D69 PMT1607E69 701596 701597 701598 701599 701600 701601 2761 46561 TC75040 1968 1969 1969 1969 1969 1969 1969 1970 1970 1970 1970 1970 1970 1958 1944 1972 1974 1975 Columbia Columbia Columbia Columbia Columbia Columbia Columbia Loadking Loadking Loadking Loadking Loadking Loadking French Tool French Tool Loadking Loadking Shopmade Beall Beall Beall Beal Beall Loadking Loadking Loadking Loadking Loadking Loading Pierce Shopmade Shopmade Shopmade Transport DESCRIPTION 40 F~. Oilfield Float 40 FT. Oilfield Float 40 FT. Oilfield Float 40 FT. Oilfield Float 40 FT. Oilfield Float 40 FT. Oilfield Float 40FT. Oilfield Float 40 FT. Oilfield Float 40 FT. Oilfield Float 40 FT. Oilfield Float 40 PT. Oilfield Float 40FT. Oilfield Float 40 FT. Oilfield Float 38 FT. Oilfield Float 38 FT. Oilfield Float 40 FT. Oilfield Float 40 FT. Oilfield Float Single.DropL~y 40 FT. Single Drop Lowboy 40 FT. Single Drop Lowboy 40 FT. Single Drop Lowkoy 40 PT. Single Drop Lo, ix~y .40FT. Single Drop Lowboy 40 ~T. Single Drop L~vboy 53 PT. Single Drop L~vboy 53 FT. Single Drop L~0oy 53 Ff. Single Drop 53 FT. Single Drop Lowboy 53FT. Single Drop Lowhoy 53 PT. Single Drop Lowboy 40 FT. Single Drop L~boy Airplane Loading Lowboy Single Drop Lowboy 48 FT. Single Drop L~oy 35 FT. Single Drop Lowboy PAGE 6 o PAGES OILFIELD S S · EQ3IPMENT LIST ~AY- 1980 II. t~LLING S'ICCK B. TRAILERS 2. UNIT SF2LIAL NU~3ER N~,~ .ER YEAR (N) 1291 2063 1954 (N) 1428 82170 1975 Pierce Pointer/Willamette Double Drop L~.~oy 60-Ton Double Drop L~ 3. t IEAVY tlAUL LOWP33YS °, (M) 1399 (M) 1452 TC75624 1975 TC75025 1975 Transport Transport 69 FT. Single Drop L~.~boy 69 FT. Single Drop Lc~ . LIQUID/BULK q:'~'~'I'~_,RS :., (J) 1283 (J) 1290 (J) 1305 (J) 1307 (J) 1324 (J) 1327 (J) 1329 (J) 1372 (J) 1375 (J) 1376 (J) 1377 (J) 1378 (J) ~9901 (J) 9902 (J) 9903 (J) 9904 (J) 9905 TS128457 1957 TS953556 1957 PITS505A70 1970 PTS30A70 1970 C40105 1966 TITi6571 1971 165B71 1971 ~,~677106 1974 OMS677108 1974 OMS677109 1974 0MS677110 1974 ~4S677107 1974 T793601 1979 T793602 19~9 T793603 1979 T793604 1979 T793605 1979 Beall Beall Beall Beall Beall Transliner Transliner Fruehauf Fruehauf Fruehauf Fruehauf Fruehauf Peerless Peerless Peerless Peerless Peerless 8150GAL. Tanker 6000 GAL. Tanker 9000 GAL. Tanker 9200 GAL. Tanker 6500'GAL. Tanker 5500GAL. Tanker Tanker Tanker 10,000 GAL. Tanker 10,000 GAL. Tanker 10,000 GAL. Tanker 10,000 GAL. Tanker 10,500 GAL. Tanker 10,500 GAL. Tanker 10,500 GAL. Tanker 10,500 GAL. Tanker 10,500 GAL. Tanker 5. VACUUM TRAI!~RS (s) (s) (s) (s) 1142 1143 9003 9004 9039 1978 9040 1978 1979 1979 Columbia Columbia Thompson Thompson 200 BBL Vacuum Trailer 200 BBL Vacuum Trailer 200 BBL Vacuum Trailer 200 BBL Vacuum Trailer III. N~N-ROLLING STOCK A. SK ID ~)UI~/%ULTER TANKS (G) (G) (G) (G) (G) (G) (G) (G) 1130 1131 1132 1133 1134 1135 1136 1137 109 1976 106 1976 105 1976 110 1976 1976 107 '1976 111 1976 104 1976 Dimensional Dimensional Dimensional Dimensional Dimensional Dimensional Dimensional Dimensional 3000GAL. Skid 3000 GAL. Skid 3000 GAL. Skid 3000GAL. Skid 3000 CjYL. Skid 3000 GAL. Skid 3000 GAL. Skid 3000 GAL. Skid Mounted Water Tank Mounted Water Tank Mounted Water Tank Mounted Water Tank Mounted Water Tank Mounted Water Tank Mounted Water Tank Mounted Water Tank OILFIELD , INC. E~UIP~ LIST ~Y- 1980 III. N(X~;- FYDLLING STOCK B. SKID ~.'DUNTED/VACTAIM TA/qlCS UNIT SERIAL NUmaR NU~mER YEAR (H) 1120 (II) 1121 (H) 1123 (H) 1124 (H) 1125 1969 1969 1975 1975 1975 Shopmade Sho~made Shopmade Shopmade · Shopmade DESCRIPTION 75 BBL Skid. Mounted Vacuum Tank 75 BBL Skid Mounted Vacuum Tank Skid ~.~unted Vacuum Tank 100 BBL Skid ~.Dunted Vacuum Tank 100 BBL Skid Mounted Vacuum Tank (I) (I) (I) (I) (I) 1129 1138 1139 1140 1141 1210 150 · 1975 1975 1975 1977 1978 Dimensional Dimensional Dimensional Dimensional Dimensional 100 BBL Skid Mtd/Vac. Tank W/Agit. 100 BBL Skid Mtd/Vac.Tank W/Agit. Skid Mounted vacuum Tank W/Agit. Skid RDunted Vacuum Tank W/Agit. Skid Mounted Vacuum Tank W/Agit. IV. FLYING EQUIP~.~E~¢I' 2001 1980 8-~n Hovercraft SUPtY)iYI' 'EI3,J IP~'~ A. SIIOP TRUCKS B. PICKqJPS (B) (F) (Q) (Q) (Q) (Q) (Q) (Q) (Q) (Q) (Q) · (Q) (Q) (Q) (Q) (Q) (Q) (Q) (Q) (Q) (Q) (Q) 1649 1674 1675 1733 · 1752 1028 1072 1084 1095 · 1110 1500 1501 1505 1506 1507 1508 1509 1511 1512 1515 1516 1517 C~539P837444° 416060H954480 SNtS02Z127061 TYG34435008.99 D704VS36714 CCY245Zl1220 'CKY245B127671 CKY245B128327 16689 TCL266F522056 TCL246Z510662 TKL247Z508314 TKL247Z508381 TKL247Z511724 CKL268FL92583 CKL268F195587 CKL268F168594 CKL268F168801 CCZ149Z2118246 1969 1970 1970 1974 .. 1974 1975 1975 1975 1975 1964 1976 1976 1977 1977 1977 1977 1977 1978 1978 1978 1978 1979 Chevy International GMC Ford· Checy Chevy Chevy Chevy Hiway GMC GMS GMC GMC GMC GMS Chevy Chevy Chevy Chevy CheVy Delivery Van Tire Truck W/Tico Bocm 32 Passenger Bus Shop Service Van Shop Truck 4 ~D Suburban 2 T't) Pickup Crewcab Pc~er Auger 2 WD Suburban 2 WD Pickup 4 WD Pickup 4 ~D PJ.ckup 4 ~D Pickup 4 WD Pickup 2 WD Pickup 4 WD Suburban 4 WD Suburban 4 WD Suburban 4 WD Suburban Pickup · P}:GE 8 PAGES V. SUPiK)I~f EQU IP~fl~NT B. PICk-OPS VI. blI SCELI~.2'~tDOOS UNIT NUMBER (Q) 1518 (Q) 1520 (Q) 1521 (Q) 1522 (Q) 1523 (P) 1101 (P) 1103 (p) 1106 (P) 1108 (P) 1109 (P) 1359 (P) 1379 (P) 1396 (P) 1398 (P) 1451 OILFIELD , INC. EQUIPMENT LIST ~Uff- 1980 CCZ14Z127171 1979 CKL1495155078 1979 CKL149Z197986 1979 TKL149Z536262 1979 CCL269F177831 1979 1971 1971 1971 1970 5858 1974 · FWS670438 1974 TC75022 1975 TC75023 1975 Chevy Chevy Chevy Chevy Chevy ATCO ATCO ATCO Athey Athey Shopmade Loadk/ng Fruehauf Transport Transport DESCRIPTION Pickup Pickup Pickup Pickup Suburban 4-axle Modular Frame 4-axle b~Ddular Frame 4-axle Modular Frame Wagon Wagon 5th Wheel Steerable Dolly 2-axle Jeep Dolly 45/50 ~T. Stretch Trailer 4-axle Front Jeep Dolly 4-axle Front Jeep Dolly Number e~. ea. ea. ea. ea. ea. ea. ARCTIC OILFIELD ENVIRONMENTAL sERvIcES, INC. PHONE: 279-6117 TELEX: 26618 ARCTIC OILFIELD EQUIPMENT LEASING DAILY RATES Recovery Systems 2" Centri Pumps 2" Diaphram Pumps 2" Waterous Float Pump (Fir~ Washdown) 1~" Pressure Pump 3" Trash Pump 3" Centri Pump~ 3" Diaphram Pumps Rate/Day 35.OO 35.oo 39.50 25.oo 48.50 4s. 50 48.50 1500' 200' 700' 200' Hoses 3" Suction Hard Hose 2" Suction Hard Hose 1½" Fire Hose 3" Discharge Hose Hose Floats Separator & Skimmers .48 per ft. · 35 per ft. · 25 per ft. · 25 per ft. ! '! ea. ea. ea. ea. 2'ea. ea. ea. 800' 11 ea. ea. 2000 Gallon Air Berm 3000 Gallon Air Berm 1OO0 Gallon Air Berm Olea Oil Skimmers 48" Manta Skimmers 48" + 36" Flexible Scavenger Oil Skimmer Z14E CSI Mop Skimmer CSI Mop 100' , CSI Mop Idler Pulleys CSI PUZ638C Pumping Unit Storage $ 35.00 · $ 45.00 $ 27.50 $ 45.00 $ 45.00 $135.00 $185.00 $ 45.00 .$ 45'.00 ea. $185.00 1 ea. 1 ea. 1 ea. 1 ea. ea. ea. ea. es. ea. 10,OOO Gallon Goodyear Bladder 20,000 Gallon Goodyear Bladder 50,000 Gallon Uniroyal Bladder 3,000 Gallon Uniroyal Bladder Boats $ 95.OO $195.OO $295.OO $ 65.00 16' B.oston Whaler w/35 H.P. Johnson $145.OO 15' Silver Liner Inboard Runabout $190.00 Avon 16' w/25 H.P. Johnson $135.OO 12' Avon w/15 H.P. Johnson $1OO.OO 21' Aluminum Riverboat w/Twin 75 H.P. Johnson $250.00 Jet Drives. 32~ Aluminum Jet Barge w/Twin 460 Ford & Hamilton !031 Jet Units $2,750.O0 39 ARCTIC OILFIELD EQUIPMENT LEASING DAILY RATES Page 2 Number Motors ea. ea. 1 ea. 1 ea. 1 ea. ! ea. 4 ea. 2 ea. 1 ea. 1 ea. 1 ea. 2 ea. Misc. 1 ea. 2 ea. 2 ea. 2 ea. ea. ea. ea. ea. 2 ea. 2 ea. 5 ea. 6 ea. 3OOO' 1OO0' 24 ea. 20OO' 8 ca. 1 ea. 10 ca. !500' 2 sets 200' Rate/Day 6 H.P. Johnson Outboard 15 H.P. Johnson Outboard $ 25.00 $ 3o.oo Support Equipment STIHL Abrasive Saw 8" STIHL Auger w/Extension 8.8 CFM Air Compressor SIOUX Steam Cleaner Chain Saws Space Heater Hot Air Heater (HOTSY) Ventilating Fan (24") Miller Welder - Gas Driven Victor Cutting Equipment w/Bottles Hand Tools Large Quantity Thunderbolts Electric Welder 25.00 25.OO 20.00 3o.oo 15.OO 25.00 35.00 20.00 45.00 35.00 + ACET x OXY 7.00 40.00 Safety MSA Explosion Meters Scott Air Packs Emergency Oxygen Apparatus Ram 5 Air Packs Emergency Oxygen Apparatus $ 35.00 $125.OO $ 25,00 Generators 3.5 KW ONAN Generator Set 3.0 KW ONAN Generator Set 6.0 KW Lite Plant w/25' Lite Tower 10. KW Lite Plant w/25' Lite Tower 35.00 35.00 85.OO 95.00 .~pecialized Support Equipment Radios SSB Base Unit VHF Base Unit SSB Mobile Unit Hand-held SSB Unit Prices for this equipment can be given upon request. Containment Ocean/Dike Compactible Boom lO"x14" Ocean Dike Compactible Baby Boom 4"x6" Boom Lights Tow Line Tow plates Boom Repair Kit Anchors Harbor Dike Boom Ground Anchor Sets Kempcr 6" x 8" Boom 4O ARCTIC OILFIELD EQUIPMENT LEASING DAILY RATES Page 3 Sorbents 3M 156 Pads 3M 151 Pads 3M 157 Pads 3M 270 Boom 3M 126 Sweeps Large Quantity Large Quantity Large Quantity Large Quantity Large Quantity 74 76 78 78 78 75 78 7O 75 71 72 75 67 Vehicles and Equipment Ford Flatbed Dump Truck 1/2 Ton GMC Pickup 4 W.D.. 3/4 Ton Chev. Pickup 4 W.D. 1 Ton 3x3 Crew Cab 4 W.D. 1 Ton 3x3 Crew Cab 4 W.D. 1 Ton 3x3 Crew Cab Step Van 20' Cargo Van w/lift Gate Gin Pole Truck Vac Truck 59 Barrel 3 Axle Flat bed Trailer lO'x20' 20'x 8' Gooseneck Trailer Series 25 Rubber Tire Crane (Pettibone 12.5 ton) 77 Model Bob Cab Loader ~/TRA and Misc. Equip. " " " 66 40' Miller Semi Trailer " " " 77 Fleet Lion Liftall Forklift " " " $69.00 .50 per mile $30.00 .30 per mile $38.00 .35 " " $51.O0 .45 " " $51.O0 .45 " " $51.OO .45 " " $51.OO .45 " " $55.00 .50 " " $25.00 per hr. .50 mile $50,00 per hr. $25.00 $25.00 Cost upon request * Ail vehicle n~ileage rates are s6bject to change due to the rise in gas prices. * Fuel prices are not included in the equipment rental rate. * R~ate per day is for 24 hour period. * All' equipment on the hourly rate will be billed with a minimum of four (4) hours per call-out. * Rate will not apply if equipment is broken down. 41 Ocean Dike Boom Harbor Dike Boom Baby Boom BOOM LEASING RATES 1 Day 2 - 7 Days 8 - 14 Days 15 Days & Over 1.75/ft. 1.50/ft. 1.25/ft. 1.00/ft. 1.75/ft. 1.50/ft. 1.25/ft. 1.00/ft. .50/ft. .45/ft. .40/ft. .35/ft. ? Order Purchase Order ~-'---'1 Change No. '[ O 7~ttc OilfJeld Environmental Services 6611 Az'tic Boulevard ;.nchorage, ~K 99503 __ Recluisitioner's Copy IDate 9/24/80 ICorr. Code ITax Exempt Ship To Conoco, Inc. Attn: H. D. ~aley 290 Maple Court Ventura, CA 9~00~ '[his number must ar on all invoices, slips and correspondence. Purchase Order No. 00] As shovm on invoices ...... /Trace Key Ship Via ~lanket Order No. , . Acknow. , .... , .... ,, ,, ., , ........ ~eP°rt Required { Date Requir~ at DeStination Remarks Commodity Code I ~ . , Word Description Price- $ Per This Blanket Purchase Order is established to furnish necessary ~ebc~sc~yvices and materials for clean-up operations which might be required on G~wYdyr Bay No. 2 and Milue Pt. No. 2 drilling wells Prudoe Bay, Alahka. Services to be rendered only upon request of 6onoco personnel. At the time of placing a commitment against this order, the authorized Cenoco Inc. employee will present the ~endor with name, blanket order number, release number, and charge refer- ence. One copy of the priced delivery ticket will be left with the receiving individual after he signs for receipt of the material. I Invoices and delivery tickets are to reflect blanket order number, z release, number, and any charge r~ference given when material is ordered. Invoices and recap sheets (two copies and original) supported by signed copies of delivery tickets will be accumulated monthly by the smpplier and submitted to the above address. Upon receipt of this order, please inform your personnel of these pro- ce~ures. Conoco, Inc. reserves the right to cancel this order pri'or to the expiration date. ,, at once. Original Purchase Order Purchase Order Change No. Crowley Ehviromental Services }gl2 Spcnard Road Anchorage, ~d( 99503 Requisitioner's Copy 9/24/80 Date iCorr. Code Ship Conoco~ Inc. To Attn: H. D. Haley 290 Maple Court Ventura~ CA 9~00~ '[his numl)er must ar on all invoices, slips and correspondence. Exempt I Purchase Order No. 001-059225-3-70 ~" J Charge ...................... ] 'Requisition Nol .... ~us :.,. ~o be ~own o~ J=¥o~cea Acknow. ~ Flag [---']Prepaid J .[Origin [-~ Destination l See ~;port'Required ] Date Roquir~ at Destination Remarks ...... Commodity Code I Word Description ' Price- $ Per labo~ services a~d m~te~als £o~ clea~-u~ o~eta~to~s w3ic~ ~igh~ be tegut~ed o~5~L~.~E~. 2 a~8 [,~l~e ?~. No. 2 ~f1~tz~ we~s, ~oe 9a~ AlasAs. Se~vtees ~o be ~e~Se~e8 o~ ~e~es~ o~ Co=oco ~etso~el. A~ ~e ~ime'ot ~[ae~ s co~i~me~ ~ese~ ~he ve~do~ wit~ ~e, bl~e~ o~de~ ~be~ ~elease ~- be~, a~ chs~ge ~e~e~e~ce. 0~e eo~ o~ ~e ~ee~ ~e[~ve~ ~o~ ~eceJ~ o~ ~e mater,s[. ~vo[cea a~G ~e~ve~ ~cAe~s a~e to te~lect bla~e~ o~Se~ ~be~, ~elease ~be~, a~d a~ cha~ge ~ete~e~ce g~ve~ wAe~ m~e~a~ ~s o~Sete~. [~votces ~8 ~eca~ submitted ~o the above sdd~ess~ A~. ~acA 9~us. O~o~ teee~ o~ t~s otSe~ ~lease t~o~ ~ou~ ~e~so~e1 DE tAese ~ocedutes. Co~oco, ~c. ~ese~ves ~e ~JgA~ ~o ca~ce~ t~ts o~Set ~ot to ~Ae ez21t~to~ -, .................. materi~-r~D~~!~~~~urchasing Department at once. II II It It II It Ii It I1 II It il CROWLEY ENVIRONiVIENTAL SERVICES CORP. September 17, 1980 Mr. Dave Dooley Conoco, Inc. 290 Maple Court Ventura, CA 93001 Dear Mr. Dooley' o Pursuant to our conversation of September 17 this letter will confirm Crowley Environmental Services intent to provide personnel and equipment to Conoco on a contract basis as necessary for oil spill control/ recovery services on' the North Slope. In order to facilitate our response .in the event Conoco requires assistance we urge you to review the attached CES Work Authorization form and, if acceptable, return a signed copy to our Anchorage office. This will serve to pre-establish terms and conditions under which we would be contracted on an as-needed basis. We require a signed (executed) Work Authorization prior to commencing cleanup operations. It should be understood that Conoco will not assume any financial responsibility to CES by executing this contract in advance. Actual charges would commence only upon Conoco's authorizaton to proceed with services. Additional enclosures include a list of CES pollution-control equipment and an inventory of equipment available through Oilfield Services, a sister company with established operations at Prudhoe Bay. Be advised that Crowley also has a significant fleet of tugs, barges and other support equipment permanently stationed at Prudhoe Bay. If we can be of further assistance-or provide additional infor- mation, please contact us at anytime. Very truly yours, MBB/bb CROWLEY .ENVIRONMENTAL SFRVICES CORP. M. ~ru96 Bar~o/ GeneYaq Managt~r, Alaska Enclosures CROWLEY MARITIME CORPORATION--NORTHWEST AND ALASKA DIVISION 3400 East Marginal Way South Seattle. Washington 98134 t206) 682--'898 Post Office Box 171 78 Portland. Oregon -37217 ,503) 283-I 2:14 Te~e~ 3812 Spenard Road Anchoraqe. Alaska 99503 (907) 344-1511 Telex 25-403 45 CROWLEY ENVIRONMENTAL SERVICES CORP. OPERATING EQUIPMENT INVENTORY - SEPTEMBER 1980 ANCHORAGE, ALASKA ITEM MAKE MODEL SERIAL NUMBER 5. 6. 7. 8. 9. 10. ll. 12. 13. 14. ROLLING STOCK 65-bbl. vacuum truck 90-bbl. tank truck 5-ton flatbed truck with National crane Diesel boom truck 2½-Ton van truck 3/4-Ton 4x4 pickup Station wagon Front loader 2-Ton forklift 40-Foot lowboy Light duty pickup 3/4-Ton 4x4 pickup Sedan Station wagon Kenworth - 1963 GMC - 1971 International - 1977 -Autocar - 196~ GMC - 1973 Chevrolet - 1979 Chevrolet - 1979 Michigan - 1969 Clark Downs - 1964 Ford Courier - i98o Ford - 1980 BuiCk - 1980 Olds - 1980 Loadstar 1700 1AW35H 7DG2 C-40B F260 101202 DH92AA135255 EO22GCA21716 50720 TCE62TV559048 CKL2492120252 9K529173 422930 564002 SGTBWPT1449 WGN 3H35FAR469515 ITEM MAKE- MODEL SERIAL NUMBER ROLLING STOCK (continued) 15. 40-Foot van semi-trailer (response van) Utility - 1974 16. 40-Foot van semi-trailer Utility - 1974 17. 40-Foot van semi-trailer Utility - 1974 18. 20-Foot cargo van - 8 each (one in Kodiak) 19. 24-Foot cargo van - 3 each 20. 12-Foot cargo van - 5 each 21. 40-Foot cargo van Ottio 22. 25-Foot response trailer -1978 7047686001 7047686O02 744-7232-005 AK13192 (License) ITEM MAKE MODEL SERIAL NUMBER · e 3~ 4, e VESSELS Hawser vessel - 30'x8'x4' 17-Foot Boston Whaler 12-Foot Pioneer workboat (2) Zodiac MK III GR ' Zodiac MK IV GR Uniflite- 1968 Yarbrough Mfg. - 1976 Sinterplast Inc. Zodiac Zodiac Hawser 30HH675 USCG Reg. HID WBCA 6792M7~ AK-7225-D , 12-foot polyethylene Mark III GR 12191 Mark IV FR XDC795M80B L ITEl1 ' MAKE MODEL SERIAL NUMBER · · 2. 3. 4. 5. 6. 7. OUTBOARD MOTORS 55 [torsepower outboard 1976 Johnson 55EL 76 E4471295 9.9 Horsepower outboard 1977 Johnson lOR77A 4632091 35 tlorsepower outboard 1977 Johnson 35RL77H E4682169 70 Horsepower ~utboard 1979 Johnson 70EL79R' 55108211 9.9 Horsepower outboard 1980 Johnson IOR80A 5038980 9.9 Horsepower outboard 1979 Evinrude 0007387 25 Horsepower outboard 1979 Suzuki ITEM., ............ PUNPS 1. 2-Inch diaphragm 30 gpm- 2. 2~-Inch submersible 500 gpm 3. 2~-Inch submersible 500 gpm 4. l~-Inch centrif(igal 150 gpm 5. 2-!nch trash pump 195 gpm 6. 2-Inch trash pump 195 gpm 7. 2~-~-!nch high pressure 8. 4-Inch trash pump 610 gpm (electric start) 9. 3-Inch centrifugal pump 300 gpm lO. 3-Inch centrifugal pump 300 gpm ll. 3-Inch centrifugal pump - 300 gpm 12. 3-Inch trash pump 385 gpm 13. 3-Inch Lister diesel trash 320 gpm (electric start) 14. 3-Inch diaphragm- electric 15. 4-Inch Lister diesel trash 600 gpm (electric start) MAKE Home 1 i te Stanley Stanley Home 1 i te Homel i te Homel i te · Home 1 i te Homel i te Homel i te Homel i te Homel i te Homel i te Gorman Rupp Homel i te Gorman Rupp MODEL lllDP2-1 SM22 SM22 lllS1½-1 121TP2-1 121TP2-1 l15P2½-1A 160TP4-1 '120S3-1 120S3-1 120S3-1 120TP3-1A 13A2-LR1 DP-3 14A2-SR27 SERIAL NUMBER 41707167 1028 lO14 3260394 91300667 48404205 62320018 50300946 3369291 3369291 48237345 50200720 572332 607972 I ITEM MAKE MODEL SERIAL NUMBER · 16. 17. 18. 19. NOTE: PUMPS (continued) 2-Inch Edson hand diaphragm (2) 3-Inch double diaphragm air-driven pump 3-Inch diaphragm 3-Inch diaphragm A11 pumps Wi 1 den SM-3 Hom~l ite Homel i te explosion-proof and kamlocked. lllDP3 92045696 lllDP3 93167219 ITEM MAKE MODEL SERIAL NUMBER RECOVERY SYSTEMS/SEPARATORS 1. Oil/water separator, l0 gpm 2. Oleo III skimmer - 3 each 3. SLURP skimmer 4. Disc skimmer 5. Vac-U-Max- 2 each 6. Vac-U-Max 7. Oil Mop MK II-4E 8. Oil Mop MK II-4H 9. Oil Mop MK I-4E lO. Oil Mop Accs. - 300' OCW 4-6 rope mop, 100' OCW 3-4 rope mop, 3 TP-16 pullies, 3 TP-12 pullies 11. 36-inch Manta rigid 12. 48-inch Manta flexible 13. Portable air compressor 14. Scavenger 15. Skim Pak Oi 1 Mop CES Mfg. CES Mfg. Lockheed Vac-U-Max Vac-U-Max. Oil Mop Oil Mop Oi 1 Mop Gardner-Denver Oil Recovery Systems Douglas R-10 Type 1 O1 F 55-2N TK-1N MK I I-4E MK I I-4H MK I-4E 36" 48" 125 cfm 2023-10 10253 Part- 5518210505 66861/76 72079/77 1298-A 610006-05 610036-03 , 603776 2043 ITEM MAKE MODEL SERIAL NUMBER CONTAINMENT BOOM/ACCESSORIES 1. Compactible boom- 500 feet 2. · Standard boom - 2,100 feet 3. e 5~ 6, Compactible boom- 900 feet Fast-water compaOtible - 7000 feet Whittaker EXpandi Boom - 1,000 feet (includes boom pallet, accessories) Whittaker Expandi ,Boom - 1.65 feet Kepner 14"x16" Kepner 8"xl 2" Kepner 8"xl 2" Kepner 8"xl 2" Miscellaneous tow adapters, repair kits, etc. NOTE' All boom palletized'or boxed fOr shipping. CSCBPHD1416DF BHD812FF CSCBPHD812DF CSCBPHDN848DF Model 4300 Model 3000 ITEM MAKE MODEL SERIAL NUMBER 2, 3~ · e 6 7~ COMMUNICATION EQUIPMENT 7 each UHF Portables MotOrola Complete withchargers, carrying cases, antennas, remote mikes. One boom mike headset. All portables TX ON 459MHz, RX ON 454 MHz. 10 each batteries Motorola 1MAXAR 25-watt UFH Base Station 1MILCOR UHF Repeater (Mt. Susitna) 4 each Converta-Con UHF consoles with accessories 3 each MOCOM-70 UHF vehicle units 1 each portable communications shack MX 360 278 ACC0640 278 ACC0641 278 ACC0642 278 ACC0643 278 ACC0644 278 AEE4453 278 AEE4455 DFIG 36039 FCHG 02836 DFIG 35945 FBHG 01164 EEHG 92713 EFHG 95833 DFIG 36044 DFIG 36028 BAAU 28717 AJA 00328 ITEM MAKE MODEL SERIAL NUMBER 8, COMMUNICATION EQUIPMENT (continued) 4 each VHF portables - channels 6, 16, 10, 81 Modar Modar Modar Modar Modar 4 each VHF portables - channels 6, 16, 10, ll, 22, 81 Standard Standard Standard 'Standard All VHF portables include batteries, chargers, carrying case, remote mikes. 10. 1 Each VHF portable base ll. 1 Each VHF base 12. 1 Each VHF Base (OIL TIGER) 13. 1 Each VHF Base 14. 1 Each 120/12-volt convertex Modar Triton 55/75 Modar -10-Channel Modar 55/75 Modar lO-Channel Newmar 15. 1 Each VHF scanner 16. 1 Each SS3 Base Regency DECCA Triton H231TM1140AT Tri ton H2~l TM1140AT Triton H231TM1140AT Triton H231TM1140AT Tri ton H231Tml 140AT 831 831 831 831 D33ADA1025AK D23ABA1820BK D23AB1820AK 115-12-12 ACT-C4-A SSB' 150 S23AOB R31A53 , S23A1B OllA4T QllA2T 97U090027 97U090024 97U090029 93U040190 233CEA0176 SMO28K 014841 156 174-17128 E1200025 ITEM MAKE MODEL SERIAL NUMBER · e STORAGE TANKS 300-Gallon pillow tank 600-Gallon towable - 2 each 3, 4, 5~ , · e · 6,000-Gallon bladder tank 1,O00-Gallon bladder tank 500-Gal lon sealed drum tank - 3 each 20,O00-Gallon bladder tank 20,O00-Gallon bladder tank 1 O, O00-Ga I 1 on steel tank 300-Gallon steel tank (skid mounted) lO. lO,O00-Gallon~ bladder tank Kepner Kepner Goodyear Goodyear Uni royal Goodyear Uni royal Geer Un i roya 1 NOTE' All tanks complete with fittings, dry discoUnt/shutoff valves. Sea bags wi th fittings 315600FD ITEM MAKE MODEL SERIAL NUMBER · · . HOSE 2"x20 suction (12) 2"x50 discharge (6) 3"x20 suction (22) 3"x50 discharge (20) 5. 4"x20 suction (17) · · 4"x50 discharge (7) l~'~"x50' fire hose (4) each 50'x½" hydraulic hose each 50'x3/4" hydraulic hose ITEM MAKE MODEL SERIAL NUMBER MISC. SUPPORT EQUIPMENT (continued) 16. Ventilating fan 24" explosion-proof 17. 02/Explosion Meter 18. H2S Meter 19. Cut-off saw ?,,, 20. Arc welder 21. Shop compressor 22. Table saw 23. Oxy/Acetylene set 24. Set shop mechanic's tools 25. Bench grinder 26. Parts washer 27. Battery charger 28. Dynanometer 29. 3 Portable light stands- (2) 500-watt lights/stand 30. 4 Explosion proof light systems 31. 2 Chemical resistant sui'ts MSA 32. Supplied air breathing systems MSA Gastech Home 1 i te Lincoln Melben Craftsman Victor Craftsman Craftsman Kleer-Flo Solar Chatillon XL-98 TIG 300/300 63431007 AC339668 518594 ll3 299040 39719451 70 WT-IO 10666 CH2 74365 4606 33. Double drum salvage beech winch, (2) 8000-lb anchors, Crown buoys, wire, complete two-man surface supply diving van. Alaskan Beaufort Sea Oilspill Response Body 6700 ARCTIC SPUR ROAD · ANCHORAGE, ALASKA 99502 TELEPHONE (907) 349-6491 August 3, 1981 TO: ABSORB Member-Company Representatives Technical Subcommittee Members Chairman - Legal Subcommittee Chairman - Accounting Subcommittee Chairman - Communications Subcommittee FROM: SUBJECT: A1 Allen, ABSORB Manager ~~~~ Update on ABSORB State of Readiness The following information is provided to assist you in developing site-specific spill contingency plans for the Beaufort Sea and in dealing with questions and/or concerns from government agencies regarding ABSORB's operational readiness. CONT'ING ENCY PLAN ABSORB's Oil Spill Contingency Plan has undergone an extensive review since its release in July, 1980. This review has resulted in a set of three revision packages. The first package, covering a few changes in wording and phone numbers, etc., was mailed to all plan holders on July 10, 1981. The second revision package, covering equipment specifications, site restoration, Commun- ications network, government agencies, personnel job descriptions and mihor wording changes will be mailed within a few days of the completion of our annual meeting '(August 18/19, 1981). This second mailing will include the names and phone numbers of the officers of ABSORB's Executive Committee for the remainder of 1981 and for the new fiscal year, 1982. A third package of revisions is being planned for a November/ December, 1981 mailout providing substantially new information on our training programs, sensitivity atlas and equipment/services 'resource inventory' and retrieval system. FI'ELD'MANUAL' '(or HANDBOOK) ABSORB is currently developing an Oil Spill Contingency Field Manual (or Handbook) with assistance from Crowley Environmental 59 August 3, 1981 Page 2 - Services, Anchorage. The field manual will be a condensed ver- sion of several chapters out of the larger ABSORB Oil Spill Con- tingency Plan. It will be a loose-leaf notebook approximately (6 1/2" by 9") prepared for use by operational personnel in the field. This field manual will be prepared in a style and format to facilitate a simple conversion of the manual to a ~i2e:~spe'ci'fi~ document for use by any of ABSORB's member companies. While serving as a useful field-oriented, mini-contingency plan for the ABSORB Response Team (ART), the manual will be easily converted, as necessary, for site-specific offshore drilling operations. The planning and preparation of the manual has been coordinated with Federal and State agencies to insure its adequacy in meeting all regulatory concerns. . FACILITIES AnCh°ragp - The ABSORB headquarters will relocate on or about September 1, 1981 from 6700 Arctic Spur Road to 201Danner Avenue, Suite 170. The Cook Inlet Response Organization (CIR0) and Gulf of Alaska Cleanup Organization (GOACO) headquarters will also move to the same location. All existing telephone numbers should remain in effect. The ABSORB warehouse in Anchorage (4,600 sq.ft.) is located at 525 Potter, Bay #1, and is currently used in receiving and pre- ~aring equipment for shipment to the North Slope warehouse, and for storing certain backup resources such as sorbents, contain- ment boom and a complete bird rehabilitation center.. These ma- terials can be moved quickly to the slope or any other area of need upon demand. North -SlOpe--The ABSORB warehouse at Prudhoe Bay (10,800 sq.ft.) was completed in April 1981. The warehouse is located on Spine Road, next to the VECO camp and construction facilities, mid-way between the Deadhorse Airport and the ARCO airstrip. The ware- house contains woqd and metal workshops, storage bins and racks, dispatch office, and a large room for training or for onshore support functions during an actual spill. The building together with approximately two acres of gravel pad, is capable of holding the entire inventory of ABSORB's oil spill response equipment, materials and support vehicles/vessels. 6O August 3, 1981 Page 3 ABSORB's 20-man Herc-able camp, capable of supporting 20 to 40 personnel at a remote location if desired, is presently being set up next to the North Slope warehouse. The camp will be used for lodging warehouse personnel and instructors, and for a potential R & D program out on the ice this winter. The camp is connected by detachable walkways to our warehouse and to two equally mobile modules comprising our Command and Communications Center and a Government Liaison/Debriefing Room. !EQUIPMENT As of August 1, 1981, approximately 95% of ABSORB's oil spill equipment inventory was in place at the North Slope warehouse, or enroute to arrive at Prudhoe Bay within a few days. The remain- ing portion of ABSORB's planned fiscal year 1981 equipment ac- quisitions will be in place by November, 1981. Additional equip- ment and materials have since been identified, and pending approval of the new budget for the rest of 1981 (September - December) and all of 1982, these items will be acquired and on board by June 1, 1982. A list of our response equipment and materials, along with dates to be in place, has been attached for your review and use as desired. TRAINING "SCHEDULE On July 27, 1981, I sent a complete breakdown of our planned training schedule to each of the recipients of this memo. As indicated, approximately ten separate training activities are planned between now and mid-November. 61 QUANTITY FACILITIES ~BSORB SPILL: CLEiNUP EQUIPMENT (in place or enroute to Slope) DESCRIPTION I981 NOV' Major warehouse equipment 20-man camp Anchorage warehouse (leased) Prudhoe Bay warehouse (leased) X X X X VESSELS 1 ea 32' workboat X 1 ea 16' ion boat w/25hp motor and trailer VEHICLES 1 ea : 2 ea DETECT I ON 18' 6-ton van truck (4 wheel drive) X Snow'machines & sleds X 1 ea 1 ea 7 ea 3 ea Current meter (handheld) Current meter (self-recording) Ice augers Vapor analyzers CONTA'I NMENT ' EQU IPM ENT 2035' Goodyear Sea Sentry boom 1000' Kepner Reel Pak boom (on two separate 500' reels) X x (2) X x (5) X ABSORB EQUIPMENT Page 2 QUANT ITY DESCRIPT I ON CONTAINMENT' EQUIPMENT.".'(c0nY 2700' Ocean Dike containment boom 900' Mini boom 1000' American Marine Simplex oil boom An additional 10,000 to 15,000 feet of boom--will be. purchased following open water test and evaluation activities this summer. The additional booTM should be on board by June, 1982. OIL' RECOVERY "EQUIPMENT 10 ea SLURP port able wi er skimmers (Under- Review) 10,000' Rope Mop skimmers (small) 3M type 280 ~orbent boom 457 rolls 197 bales 3M type 100 sorbent rolls 3M type 157 sorbent 100 bales 3M type 151 sorbent Rop Mop and disc-type skimmers of various types, and configura- tions are q~rrently under review, and planned for purchase this summer. These additional recovery capabilities will be ready for use prior to breakup, 1982. RUG '1 X X X X X X X X I981 NOV' 1 X 63 ABSORB EQUIPMENT Page 3 QUANT ITY DESCRIPT I ON STORAGE "E~UIPMENT 1 ea 1000 gallon air berm storage containers 2 ea 2000 gallon air berm storage containers 2 ea 3000 gallon air berm storage containers ....... 20 ea Firestone Fabritank 2250 gallon bladders ea Firestone Fabritank 4400 gallon bladders Dracone barges (500 bbl class) are currently under review and will likely be purchased within the nexi 6 months. TRANSFER 'EQUIPMENT 1620 ' 2" B. F. Goodrich suction hose w/fittings 4020 ' 3" B.F. Goodrich suction hose w/fittings 10 ea 10 ea 2 ea 2" Multiquip QP20T self-priming trash pumps 3" Multiqu{~ QPD302 diaphragm pump Slickbar Trans-Vac, skid-mounted vacuum units w/skimmer heads AUG '"1 X X 1981 NOV ' '1 X X 64 ABSORB EQUIPMENT Page 4 QUANTITY DESCRIPTION LOG IS'TI CAL' 'SUPPORT ~UG~ 1 I981 NOV ~"1 1 ea Iea 20 ea 5 ea 1 ea 1 ea i ea 1 ea 1 ea i ea Iea Communication system with value of $255,000, including: G. E. Porta Mobil II UHF ~ VHF X G. E. Master II Mobil UHF ~ VHF X Motorola MX 360 UHF X(5) Motorola MX 360 VHF X G. E. Deskon II base X controller G. E. Mastr II UH & VHF X repeaters Comco 731 air to ground X Motorola Micom-Consolette X single sideband H. F. tranceiver Motorola VHF marine X G. E. Mastr II VHF X 40 kw diesel generator and X housing Bird rehabilitation center x(15) X (part ial ) X (complete ) 16 ea 1 ea 5 ea 5 ea 2 ea 2 ea Bird scare-away cannons & floats 1.5 kw Homelite generator/(gas) Pincor 3.0 kw generators/(gas) Pincor 5.0 kw generators/(gas) Pincor 8.5 kw generators/(gas) Pincor 13.0?kw generator/(diesel) X X 9 ea 1 ea TPA500-4 tripod lights w/4 Tungston halogen flood lights 100,000 btu direct-fired space /heater 65 ABSORB EQUIPMENT Page 5 QUANTITY DESCRIPTION LOGISTICAL' ~UPPORT :(Cbnl~ ' ~i') 9 ea 2 ea 150,000 btu direct-fired space heaters 320,000 btu direct-fired space heaters 3 ea. Chain saws, 2. w/36'_', bars; 1 w/7, bar 10 ea Response boxes Small hand tools Personnel protection gear Miscellaneous supplies-beach cleanup 3 ea Weatherport shelters I2'x20' insulated 60 ea Life vests (Gentex Comfort King) 60 ea Mustang.U-VIC jackets 4 set s Arctic clothing and survival equipment OIL DISPOSALi "EQUIPMENT 10 drums Dispersant (Corexit 9527) 10 drums (Under- Review) Dispersant ~(ARCO-chem) Ignitors (for in-situ burning of oil) i981 AUG' 1 X X X X (part ial ) X X X NOV~ '1 X(complete ) X 66 ABSORB EQUIPMENT Page 6 A majority of the above resources are now owned or will soon be purchased by ABSORB. A small portion of ABSORB's equipment resources, however, has been, and will continue to be, leased. The following resources will likely remain in a lease-as-needed mode' -Additional crew cabs and pickup trucks -Special airborne oil detection sensors -Aircraft, all-terrain vehicles, tribikes, etc. -Additional workboats, tugs, barges, etc. -Special ice harvesters & melters -Aerial dispersant equipment/aircraft Additional items may be placed into ABSORB's inventory under long-terTM lease agreements or other immediate-access arrangements. Such items include: -Large storage barges -Onshore emergency pipeline systems for waste oil transport -Onshore storage tanks -Flaring systems and waste oil incinerators CHECK LIST FOR NEW WELL PER>fITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc thru 8) (3) Admin (9/'thru 11) thru 20) (5) oPE,4 - ~ru 24) (6) Add:.~]~ ~'-Z,/.~2// Geology: Eng i_~ing WVA KT~RAD JAL ~" J rev: 03/10/81 ¸e 10. 11. YES NO 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ................. ...........~ 3. Is well located proper distance from property line ..... ''''.''''''' ~f~ 4. Is well located proper distance from other wells ....... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ............. ./- 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day wait ............. ~1~[i[~[ ..... / Does operator have a bond in force .................................. Is a conservation order needed ..................................... Is administrative approval needed ee®eeeeeeel~eleeeee®e~eeeeeee~ee~e 12. Is cOnductor string provided ............... , .................. ~ 13. Is enough cement used to circulate on conductor and surface i[iii iii~ 14. Will cement tie in surface and intermediate or production st ' 15. Will cement cover all known productive horizons .................... " 16. Will surface casing protect fresh water zones ...................... _ 17. Will all casing give adequate safety in collapse, tension and burst..~~ 18. Is this well to be kicked off from an existing wellbore ........ ' '"' ~'--- ~2 19. Is old wellbore abandonment procedure included on 10-403 ........ .... z 20. Is adequate well bore separation proposed .......................... . ~~ 21. 22. 23. 24. 25. Is a diverter system required .................... ...... Are necessary diagrams of diverter and BOP eqUipment 2~t~ch;~"g~.'''''"'' Does BOPE have sufficient pressure rating - Test to i'~ pg.. Does the choke manifold comply w/API RP-53 (Feb.78) ............. ,. . REMARKS Additional requirements ' Additional Remarks: A, 4.. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi ,. No Special'effort has been made to chronologically organize this category of information. LIS ~.~5 YER~FICAq~ION LI$IING {~VP 009.H03 VERIFICATION Li'~TING PAGE 1 ~. REEL HEAOE~ ~ SERVICE NAME :~kRVIC DATE :82/01/23 ORIGIN : REEL NAME :REEL ID CONTiNU.~TION # :0i COMMENTS :REEL COMMENT6 #* TAP~ HEAUE~ ** SERVICE NAME :SERVIC DATE :82/01/23 OR1GIN :10;0 TAPE NAME :62503 CDN~I qUATION # :01 P~qEVIOUS TAPE : CUMNENT6 :TiPE, CURRENTS ~# FILE HEADER *~ FILE NAME :5ERVIG.0(1 SERVi:E NAN{} : VERSiUN # : DAT~ : MAXIMUM LENGTH : 1024 FiLE TYPE : PRE¥IOU$ FILE : RECORDS MNEM ~(ONTENT$ CN : CUNOCO INC. WN : MIbNE POINT FN : WILDCAT RANG: ~U~N: 13N SEC ~: 19 COIN: N. SLOPE S~A~): ALASKA CTRY: U.S.A. MNEM CDN~E~T5 PRES: NEDI~4F ** PECORD TYPE 047 ** ~ECORD F~PE 047 UNIT TYPE CATE SIZE OCO 000 000 000 000 000 000 000 000 0(0 012 065 000 016 065 000 008 065 000 003 065 000 003 065 000 002 065 000 OOU 065 000 000 065 000 006 065 UNIT TYPE CATE SIZ~i CODE 000 00~ 007 065 CONflDEi IAL LVP '(09.M03 YERi. flCATION Li. bTING PAGE 2 RECORD TYPE 047 ** ~ COMMENT5 COMPANY FIELD COUNTY STATE DATE LOGGED CASING D~lbbE~ : CONOCO INC. : MiINE ;ID/NJ B-2 : ~IbDCA7 : 1~. 66OPE : 29-DEC. 8] , : 22]4 RUN NO. : TWO BIT SiZE : 12.5 , 8.75 f'bOlO TYPE : KCL DM~S. : 9.9 ¥18C. : 38 ~ : 11.4 FLUID b086 : 11.0 Mb RM @ MEAS. TEMP. ~: 0.154 '~ 65 F RMF ~ MEAS. TEMP. : 0.124 ~ 65 F RMC ~ ME~.S. TEMP. ': 0.342 '~ ~2 F RM @ BaT : 0.123 ~ 83 F MATRIX : ~ANI$~.ONE ~ DATA FORMA~' RECORD ~. ENTRY BLOCK6 TYPE SIZE REPR ~DDE ENTRY 4 1 66 -1 8 4 73 60 9 4 65 .lIN 0 I 66 0 DATUM SP~C1M]CA~].~N .~LOCgS MNEM $~RVIC~ SERNiCE. UNIT AP1 A~ ~PI AP1 ~ILE SiZEi PROCESS SAMPLCi REPR iD O~OE~ # LOG ~EPE CLAS~ MOD NO. LEVEL CODE DkPr ~[ 0 0 0 0 0 4 0 I 68 009.1403 YERII;'iCA'i'I[~I~ LISTING PAGE 3 DT BHC~ GR PROX Mbb MNOR MLD M1NV MbL CALi Mbb NPHI ~DN'~-- ~HOB FDN-~ CALl FDN~ GR FDN DRHO NRAT FDN NCNb FDN FCNL ~DN THOR N-bT URAN NGT PUTA NGT SGR NGT CGR NGT LLD DWU bLS DWO SFLU ~D1L GR iLD ~D1L - ILM ~Dlb ~ SP ~DiL-' G~ ~DIL DATA D~PT MNUR R140B NRAT URAN LLD DEPT MNOR RHOB NRAT URAN LLD DEPT MNOR RHOB NRAT URAN 66D i6U US/f ~ 52 32 O 6API 60 31 32 0 OHSM 20 0 0 0 OHM~ 20 26 2 0 014~ 20 25 2 0 IN 20 28 3 0 Pg 42 68 2 0 G/C3 42 35 1 0 I~ 42 28 3 0 GAP1 42 31 32 0 6/C3 42 44 0 0 42 42 I 0 42 34 92 0 42 34 93 0 PPM 0 0 0 0 PP~ 0 0 0 0 PU 0 0 0 0 GAP1 0 0 0 0 G~PI 0 0 0 0 014N~ 0 0 0 0 OHMN 0 0 0 0 014MM 7 0 0 0 GAPi 0 31 32 0 0~ 7 12 46 0 OH~N 7 0 0 0 NV 7 1 0 0 6API 7 31 32 0 4707.500 -999.25'0 -~99.250 -999.250 -999.250 -999.250 -999.250 47(0.000 0.466 2.389 3.295 1.634 8~5.579 -999.250 4600.00~ 1,.6( 2.373 3.250 0.140 2.6~1 --)99.250 DT MINV CALl NCNL POTA IbM DT MINV CALl NCNL POTA Lb6 ibm MiNV CALk NCNL PO'IA -999. 250 GR -999.250 CALl -999.253 GR -999.250 f'CNL -999.250 SGR -999.250 SFLU -999.250 SP -999.250 GR 0.277 CALl 7.414 GR 763.500 fCNL 0.007 SGR 1344.375 SFbU -999,2t0 SP 109.563 GR 2.017 CALl .. 8.703 GR 1606.000 fCNb 0.042 SGB 2.740 6f'LU -999,.25~ SP 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 ~ 0 ~ 4 0 0 4 0 0 4 0 0 4 0 -999.250 PROZ -999.250 NPBI -999.250 DRHC -999.250 T140R 42.625 CGR · -9~9.250 fir -99).250 ' GR -999.250 PROX 5-84~ NP14I -9§9.250 DRt~O 236.125 THOR 42.625 KGR -~9~.250 GR -9§9.250 GR 110.375 PROX 8.914 NP14i -999.250 DR140 509.500 THOR 107.188 CG~ -999.250 G~ -999.~25~ GR 1 68 1 68 1 68 1 68 I 68 1 68 1 68 1 68 I 68 1 68 I 68 1 68 1 68 I 68 1 68 1 68 I 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 I 68 -999.250 -999.250 -999.250 -9c~9.250 30.016 '[5.500 -)9~.250 0.679 41.260 0.108 4.973 30.016 85.500 -9~9.250 3.055 38.672 0.013 10.516 106.500' 106.063 -999.250 LVP O09.HQ~ VkRI~ IcA'rICh DEPT 4~00.000 OT MNOH 1.282 MiNV RHD8 2.197 CALl NR~T 3.453 NCNL URAN 0.697 LLD 4.456 bLS ILD -999.250 IbM DEPT 44£0.0(0 DT MNOR 3.082 MINV RHO~ g.5;7 CALl NMAT 2.445 NCNL URAN 1.230 POTA bbD 9.892 bLS ILD -999.250 OEPT 4300.~00 OT MNOR 0.§(3 MINV RHOB 2.146 CALl NRAT 3.299 NCNL URAN 1.380 POmA LbO ~.3~8 bLS ILD -~99.250 ibm O~PT 42C0.0(0 DT MNOR 0.933 MINV RHOB ~.334 CALl NRAT 3.063 NCNL UR~N 0.200 POTA LLD 2.693 LbS ILD -999.250 IbM DEPT 4100.300 MNOR 0.822 MINV RHO8 2.258 CALl NRAT 3.289 NCNL URAN -0.043 POmA LLD ~.6(7 LbS ILD -~99.250 IbM DEPT 4000.0{0 OT MNOR 0.91.5 MIN¥ RHOB ~.311 CALl NRAT 3.b33 NCNL ORaN 0.819 POTA L~O 3.082 LbS ILO '-999.250 DEPT 3900.000 DT MNOR 0.374 MINV R~05 2.088 C~Li NR~T 4.098 NCNL URAN 0.595 [LD 2.603 iLD -999.250 IbM LITT1NG 112.000 ~.6~3 8.502 1297.000 0.035 4.047 -999.250 88.188 5.927 8.578 0.021 -999.~50 114.188 0.797 8.383 1722.000 0.030 1.202 -~99.253 1{5.000 1. O89 8.391 1729.90) 0.025 2.566 -999.2," 0 118.188 1.039 8.977 1481.000 0.034 2.559 -~99.25~ 115.188 1.158 8.391 1497.303 0.034 3.021 -999.250 133.500 0.441 10.336 1041.000 0.032 2.540 -999.250 GR CALl SfbO SP CALl GR FCNL SFLU SP GR CALl GR fCNL SGR SF GR CALl GR FCNL SFLU SP GR CALl FCNL SGR SFLU $P GR CALl GR SFLU GR AL1 GR ;fCNL $P 91.~63 PM[JR 8.82 6 NPHI -99 ~. 250 DRHO 3c, 5.750 THCR 89.813 C~R -9§9.250 GR -99R.250 GR 59.344 PROX 8.367 NPHI -999.250 DRHO 828.500 THOR 61.719 KGB -99~.250 GR -999.250 GR 76.813 PROX 8.063 NPHI -999.250 DRHO. 552.000 THOR 75.125 CGR -999.250 GR -999.250 GR 62.719 PBOX 8.258 NPHI -999.250 DRHO 599. ~00 THOR 62.781 ~(GR -~9).250 GR -999.250 ~ GR 101'.750 PROX 8.703 NPHI -999.250 DRHO 442.750 THOR 93.938 CGR -999.250 GR -999.250 GR 92.438 PROX 8.172 NPHI -999.250 DRHO 453.250 THOR 87.563 t(GR -999.250 -999.250 GR 82.250 PRO~ 9.602 NM~I -999.250 DRHO 273.000 THOR 86.750 C~R -999.250 GR -999.250 GR PAGE 2.]45 ;~.2,4~0 0.056 9.039 85.500 '~6.500 -~99.250 9.586 25.488 0.003 5~, 305, 52.2i9 60.969 -9~,9.250 0.896 40.039 -O.0O6 3.428 64.688 77.000 -999.250 2.408 35.791 0.007 6.207 62.750 61.312 -9~9.250 1.913 38.965 0.015 10.531 94.312 90.375 -999.~50 2.107 46.045 0.000 8.07~ 81.250 82.625 -999.250 0.835 51.563 0.059 7.480 76.813 '79.375 -999,250 LVP O09.HO~ VERIf'ICAT1GN LILTING DEPfl 3800.000 MNOR 1.260 RHOB 2 · 11.7 NRAT 3.453 URAN -0.285 LbO %. 394 ILD -999.250 OEPT 3700.0f0 MNOR 2.088 RhOB }.452 NRAT 5.379 URAN 0.396 bLO 17.479 ILO -999.250 DEPT 3000.300 MNOR 1.291 RHOb 2.152 NRAT 4.180 URAN 1.117 LLD 9.9]5 ILD -999.250 DEPT ~5C0.0(0 MNOR 0.u49 RHOB 2.193 NRAT 3.563 ORAN -0.113 bbD 5.962 ILO -999.250 DEPT ~qO0.O00 MNOR 1.521 R~OB 2.209 NRAT 4.070 URAN 1.15.7 bbD ,1~.~]2 ILD -~9~.250 DEPT J300.OCO MNOR 0.671 RHOB ~.1~6 NRAT 4.445 UR~N 1.132 bbD 6.549 ILO -999.250 OEPT 3200.300 MNOR 0.680 RHOS 2.197 NRAT 4.0C0 URAN -0.342 LLD 4.4~9 or MiNV CALl NCNL POTA OT MIN¥ CALl NCNL PO'fA bLS ibm DT MINV CALl NCNL POIA LbS OT MINV "CALl NCNL POTA bbs DT MINV CALI NCNL POIA OT MINV CA~I NCNL POTA DT MINV CALl. NCNL PO'IA 126.375 1.213 8.602 i5(;9.000 0.035 3.694 -999.25] 143.750 3.265 ~]1.156 906.503 0.020 18.~62 -999.2.~ 0 138.500 1.393 12.242 955.000 0.029 5.049 -~99.25~ 1~2.563 0.545 ~11.734 1283.D0) 0.033 4.511 -999.250 131.500 1.788 11.898 1099.000 0.037 8.422 134.125 0.619 ~12.008 1085.303 0.039 5.483 -999.2.~ 0 133.750 0.631 12.914 1060.000 0.038 3.742 CALl GR [CNL SFLU GR CALl G~ FCNL SGR SFLU SP G~ CALl GR SGH SFLU SF CAbI FCNL S~'LU ~£AL1 GR FCNL SGR 8FLU CALl GR ~'CNL · SFLD SP GR CALl GR ~CNL SFLU 73.438 8.656 -999.250 457.750 71.188 -999.250 -999.250 51.000 12.352 -999.250 17~.]75 ;47.469 -99~.250 -9§9.250 64.063 12.102 -999.250 217.125 78.500 -999.250 -999.250 83.938 1i.578 -999.250 331.250 73.188 -999.250 -999.250 62.813 12.023 -999.250 268.500 66.813 -999.250 -999.250 108.625 11.836 -999.250 245.875 104.750 '99~.250 -999.250 93.500 12.086 -999.250 267.000 100.188 -999.250 PROX NPHI DHHO THOR CGR GR GR NPHI DRHO THOR ,CGR GR GR PRO% NPHI DRHO THOR CGR GR GR NPHI DHHO THOR K GR GR N~5I DRHO THOR CGR GR GR PROX NPHI DRHO THOR KGB GR GR PROX NPHI DRHO THOR CGR GR PAGE 2.755 42.480 -0.006 4.930 73.312 65.125 -999.250 9.980 73.877 -0.020 ].227 44.969 49.625 -9S9.250 1.825 51.758 0.041 5.813 69.875 66.500 -999.250 1.555 40.869 -0.018 3.590 70.813 65.188 -999.250 7.891 49.951 -0.000 7.461 03.188 59..406 -999.~50 1.856 56.689 0.006 9.141 96.938 94.125 -9~9.250 1.764 48.242 0.004 10.820 99.125 97.625 CONFIDENTLAL bYP 009.H03 VP3Rtblch'rl~N LISTINg. PhGE 6 -999.250 DEPT 3100. )00 DT MNOR 0.6( 3 M1NV RHOB 2.201 CALl NRAT 3.834 NCNL URAN 1.934 POqA LLD b. Q55 LLS ILD -999.250 ILM DEPT 30C O. O( 0 DT MN(OR 0.674 M/NV RIiUB 2. :2:~ 1 CALl NRAT 3.768 NCNL ORAN 0.68b POTfl bbD b.470 hO~ iLD -999.250 ibm DEP%~ 2900.000 MNUR 0.535 MINV RLOB 2.035 CALl NRAT 4.395 NCNL URAN 1.924 LLD 0.0(5 LL6 ILD -999.250 DEPT 28C0.0(0 MNOR 0.577 RHOB 9.074 NRAT 3.768 URAN -0.310 bLD 6.366 ILD -999.250 UT MINV CALl NCNL POIA LbS DT MiNV C&Li NCNL PO'LA bLS DT MINV CALl NCN£ POTA MINV C.~Ll NCNL POmA DEPT 2700.000 MNOR 0.726 RHOB 2.201 NRAT 3.764 URAN 0.281 bbD 6.428 iLD -999.250 DEPT MNOR 0.~45 RHUb NRAT 3.984 UR~N 0.425 LbD 9.0~2 lbo -999.250 DEPT 2500.000 MNOR 0.873 RHO~, 2.158 NR~T 3.855 URAN 0.204 -999.3~0 142.750 0.471 12.180 1408.000 0.029 4.722 -999.25~ ~33.750 0.659 ,11.914 1278.00) 0.036 4.895 -999.250 164.500 0.499 11.148 1012.500 0.041 '5.198 -999.25) 140.500 0.803 ,11.609 1158.000 O.O30 4.323 -999.250 141.125 0.704 11.727 1200.000 0.039 5.945 -999.250 I38. 000 0.599 ~12.125 1254.30) 0.036 6.679 -999.250 137.000 ~.115 11.844 1369.000 O.029 SP CALl GR fCNb SG~ 8FLU G~ CALl ~CNL ,5FLU i(ALI GR SFLU SP CALl GR FCNL SGR SFLU SP i£ALI G~ ~fCNL SFLU CALl G~ fCNL SGR S~LU G~ ~CALi -999.250 86.188 12.680 -999.250 387.750 91.063 -999.250 -999.250 82.500 11.742 -999.250 367.750 86.875 -999.250 -999.250 101.375 9.938 -999.250 229.750 97.000 -999.250 -999.250 66.063 1!.352 .999.250 323.500 65.938 -999.250 -999.250 11.516 -999.250 339.250 84.438 -9~9.250 -99~.250 85.938 11.828 -999.250 32).300 88.563 -999.250 -999.250 74.250 11.570 -999.250 372.500 83.813 PRGX NPHI DRHO THOR CGR G~ PROX NPHI DRHG THOR GR PROX DRHO THOR CG~ GR PRGX NPH1 DRHO THO~ C. GR GR G~ PRGX NgF I DRHO T~GB C ~ GR G~ P~CX NPHI DRHO {( GR GR PRO~ THC~ C3~ -9~9.250 1.477 45.557 -0.006 6.379 72.250 86.750 -999.~50 1.840 44.482 -0.002 7.902 84.375 76.938 -999.250 0.618 56.104 0.023 5.953 85,750 85.063 -999.250 0.853 44.629 -0.019 4.645 68.813 60.094 -999.250 1.554 44.482 -0.006 6.2.38 80.500 ,58.563 -)99.250 1.729 48.291 -0.010 7.840 86.438 75.750 -999.250 1.118 40.094 -0.008 ~.691 76.000 LYP 009.H03 VERi~-ICA'rlGN Li6TiNG PAGE 7 DLD /.667 bls 5 [LD -999.250 IbM -999 DEPT NRAT ORAN LLD ILD DLPT MNOR NRAT UR~N LLD DEPI MNOR RHUS NRAT U~AN 6LD DEPT RHOB NRAT UR~N LLD DEPT MNOR N~AT U~AN LLD DEPT MNOR NRAT URAN 1LD DEPT MNOR RHOB NBAT 2400.900 DY' 137 0.5f6 MINV 0 2.139 CALl 16 3.557 NCNL 1207 -0. 144 POIA O $. 9( 4 LbS 3 -999.250 iLM -399 2300.0(0 DJ' 138 0.504 MIrY 0 2.1,74 CALl !13 3.877 NCNb 1503 0.220 POTA 0 7.b44 bls 3 -999.250 IbM -999 2200.300 OT 8.682 MINV 2.098 CALl 3.8¢3 NCNL 0.16b -999.250 9.219 139 7 7 1581 0 -999 9 149 8 8 1743 0 -999 7 158 5 10 152 l 0 -999 8 148 5 9 15lb 0 -999 2 171 ,11 17 125'1 2100.000 8.185 M1NV 2.118 CALl 3.607 NCNb 0.251 POTA -999.250 bbs 7.68~ IbM 2000.~00 OT 8.053 MINV 1.998 CALl 3.738 NCNL -0.125 POIA -999.2~0 8.352 1900.000 4.202 MINV 2.146 CALl 3.973 NCNb -0.126 POTA -999.250 LbS 2.178 1800.900 OT 10.859 MiNV 1.972 CALl 4.641 NCNL .376 .250 .750 .580 .5~3 .000 .033 .788 .253 .375 .529 .852 .303 .030 .405 .250 .208 .b77 .715 .000 .026 .250 .281 .292 .40B .7~6 .000 .021 .250 .824 .292 .359 .065 .000 .021 .250 .555 .833 .~64 .0c. 9 .000 .029 .250 .375 .344 .823 · 000 SFLU SP G~ CALl FCNL SFLU GR CALl GR f CNL SGR SFLU SP Gl~ CALl Gi~ f'CNb S~'LU SP CALl GR fCNL SFLU GR CALl GR FCNL SFLU CALl FCNL SGR 5FLU G~ CALl GR -999.250 -9§9.250 66.125 16.312 -999.250 342.250 62.531 -99g.250 -999.250 67.188 13.711 -999.250 399.750 69.563 -99).250 -999.250 72.750 .9.484 68.656 377.000 51.875 11.453 -8.667 79.391 ,78.0Z8 461.250 42.844 ~.352 -1.766 49.852 10.078 48.953 414.250 41.594 10.961 -24.349 81.859 ~.117 85.859 385.000 58.031 1.843 -0.~9 48~'~055 1'6.891 45.65e 258.250 GB GR PROX NPHI DRHO THOR CGR GR GR .NPH1 DRHO THOR GR GR' NPHI DRHO THOR CGR OB PROX NPHI ~HOR K GR GR GR PROX ,DRHO THOR CG~ GR GR PROX NPHI THOR K GR GR G~ NPBI DRHO THOR 69.938 -9~9.250 1.161 38.525 -0.011 3.465 64.000 55.938 -999.250 1.329 45.557 -0.019 5.905 70.375 63.500 -919.250 14.172 42.578 0.143 3.234 50.594 -999.250 72.750 11.203 39.600 0.016 2.697 40.906 -)99 50 14.'766 38.306 0.063 2.383 42.563 -999.250 49.852 4.924 42.896 0.021 3.689 59.000 -)99.250 '~1.859. 21.495 48.572 0.013 2.428 bVP 0)9.H03 V~RI~ICATiON LIbT1NG PAGE UR~N 0.098 PO'IA LbO -999.250 bbs ILD 18.328 ibm DEPT 1700.)00 DT MNOR -999.250 MINV RHOB 2.116 CALl NRAT 4.219 NCNb URAN -0.017 POIh LLD -999.250 bbs 1LO 2.197 DkPT lbCO.0(0 OT MNOR -999.250 RHOB 2.~41 CALl NRAT 4.242 NCNL URAN -999.~0 PO~A LbO -~99.250 LbS ILD 12.648 ibm DEPT 1500.D00 DT MNOR -999.~0 MINV RHOB 2.121 CALl NRAT 4.332 NCNL ORAN -999.250 POmA LLO -999.250 LbS 1LO 18.765 Ib~ DEPT 14(0.0(0 DT MNOR -~99.250 MINV RHOB 1.853 CALl NRAT 4.b72 NCNL URAN -999.250 POTA LLD -999.250 LbS 1LD 127.b25 ibm DkPT 1300.)00 DT MNOR -999,~50 MINV RHO~ 2.105 CALl NRAT 4.31~ NCNb ORAN -999.250 LbO -999.250 ILD 27.953 ibm D~PT 12(0.0(0 OT MNOR -~99.250 M1NV RHOB 2.100 CALl NRAT 4.065 NCNb UR~N -999.250 LbO -999.250 bbs ILO 3b.281 IbM D~PT 1100.)00 DT MNOR -999.~50 MINV RHOB 1.261 CALl 0.021 SGR -999.250 SFLU 17.938 SP lb2.042 GB -999.250 CALl 18.156 GR 143~.0(0 FCNL 0.026 SG~ -999.~50 SFLU 2.070 8P 17~.750 GR -999.250 CALl ,17.807 GR 1453.000 FCNL -999.250 -999.25~ SFLU 11.227 -999.250 GR -999.250 CALl 17.536 138~.0(0 FCNL -999.250 8GR -999.~50 SFLU 15.375 SP · 999.250 GR -999.25) CALl 22.2~6 GR 1287.000 FCNL -999.250 -999.250 SFLU 50.5~3 SP -999.250 GR -999.250 CALl 17.281 GR 140~.0(0 FCNL -999.250 SGR -999.2~0 St'LO 20.541 -999.~50 GR -999.25~ CALl 18.2~! GR 1375.000 ~CNL -999.250 SGR -999.250 $FLU 27.109 SP -999.250 GR -999.250 CALl 22.188 GR 40.125 15.375 e22.000 75.031 -999.250 72.578 310.000 51.781 4.238 -15.182 71.516 -999.250 71,625 321.250 -999.250 11.563 -13.432 59.547 -999.250 b4.844 3C 8. ~ 0 -~9~.250 17.922 -21.682 -999.250 -999.~50 29.930 252.250 -9~9.250 150.125 ~4.448 -999.250 -999.250 63.641 333.500 -~9).250 23.219 -35.365 -999.250 -999.250 ~54.336 327~000 -9~9.250 2~.484 ~50.531 -999.250 -999.250 23.063 ~( GR GR GR PROX NPHI D~HO THOR CGR GR PROX NPHI DRHO THOR CGR GR GR PROX NPHI THOR CGR GR GR NPH I ERHO THOR ~( GR GR PROX NPHI DRH6 THOR CGR GR GR PRGR NPHI THOR ~C GR GR GR PROX NPMI DRHC 39.344 '-~99.250 4@.055 -999.250 43.530 ~.~0~ 2.9.~ 5 51.938 -9c. 9.250 75.031 -999.250 43.127 0.049 -999.250 -999.250 -999.250 ,Z1.5ib -999.250 44.751 9.923 -999.250 -)99.250 -9~9.250 59.664 -999.250 48.108 '0.084 -~99.250 -999.250 -~99.250 27.312 -999.250 43.896 9.932 -9~9.250 -~99.250 -9~9.250 57.305 -999.250 41.563 0.006 -)99.250 -999.250 -)99.250 49.859 -999.250 52.039 I~¥P 009.;~03 ~EBI~i, ChTION illSTIthG Pg'(.E 9 N{A~ 4.938 NCNL L~AN -999.250 POZA LLD -999.250 ILL 47.250 1194.000 -999.250 -999.250 15.227 DEPT 1000.000 DT MNOR -999.250 MINV RHOB, 1.664 C~LI NRAT 4.148 NCNL URA~ '999.250 POmA LbD -999.250 bbs ILL 14.109 -999.250 -999.250 18.714 1174.000 -999.250 -999.250 9.828 DEPT 900.000 bT M~OR '999.250 MINV RHOB 1.259 CALl N~AT 4.926 NCNL URAN -999.~50 PO~A LLD -399.250 [JL6 ILD 34.312 -999.250 -999.250 22.125 1195.000 -999.250 -999.25} 12.305 DEPT 800.)00 DT MNOR -999.250 MINV RHOb 1.507 CALl N~AT 4.914 NCNL URAN -999.250 POmA LLD -999.250 bLS ILL 50.655 IbM -999.250 ,999,250 21.844 1188.0(0 -999.250 -999.250 18.406 DEPT 7(0.0(0 D'~ MNOR -)99.250 MINV RHOB 2.027 CALl NRAT 4.551 NCNb UR~N -~99.250 POTA LLD -999.250 LbS ILL 10.34~ IbM -999.250 -999.25D 17.90.6 1297.000 -999.250 -999.250 7.4~4 DEPT bO9.)O0 DT MNOR -999.250 MINV RHUB i.524 CALl NRAT 4.90~ NCNL URAN -999.250 POIA LLD -999.250 bbs ILL ~9.68~ Ib~ -999.250 .999.250 22.021 1214.0(0 -999.250 -999.250 26.422 DEPT 5(0.000 DT MNOR -~99.250 MINV RHOB i.792 CA61 NBAT 4.230 NCNL U~N -999.250 PO~'A LLD -999.250 b~6 lbD 20.141 IbM -999.250 -999.253 22.~:~8 1303.000 -999.250 -999.250 12.211 DEPT &OD. )00 DT MNOR -999.~50 MINV -999.250 -999.250 fCNL SGR SfLU GR ,(AL1 GR :PCNL SGR Sf'LU SP CALl (JR FCNL 8GB SFLU SP GR CALl GR FCNL SGR Sf'LU SP CALl FCNL SGR SFLU SP OR CALl GR FCNL SGR SFLU SP CALl f'CNL SGR- SFLO SP CALl 225.375 THOR -999.250 CG~ b9.750 GR -69.396 GR -~9~.250 PROX -9~9.250 NRFI 37.797 DRHO 2~3.500 THOB -999.250 CGR 22.781 GR -57.531 .GR -999.250 PRCX -999.250 NPHI 22.785 DRHO 244.125 THG~ -999.250 CG~ 35.250 GR -~3.115 G~ -999.250 PROX -999.250 NPHI ' 24.970 DRHC -232.500 THOR -)9~.250 COB ,~0.750 GR -74.063 G~ -999.250 PROX -999.250 NPHI 285.250 THOR -9~9.250 ?;051 GR -f0.417 GR -999.250 PROX -999.250 NPHI 32.762 DRHO 237.]~0 THOR -~9~.250 COB -74.750 GR -999.250 PRO~ -999.250 NPHi ~7.109 5RBO 293.250 THOR -9~9.250 ~CGB 14.383 G~ -f2.427 -GR -999.250 PRO~ -999.250 NP~I -999.250 -999.250 -999.250 25.637 -~99.250 43.640 0.022 -999.250 -999.250 -999.250 34.039 -999.250 52.893 -0.025 -999.250 -999.250 -999.250 23.316 -999,250 51.172 9.912 -9§9.250 -999.250 -9~9.250 24.203 -999.250 47.534= 0.039 -)99.250 -999.250 -~99.250 45.2~9 -999.250 51.294 9.D08 -9~9.250 -999.250 -9~9.250 34.773 -999.250 42.163 0.101 -~99.250 -999.250 -399.250 35.734 -999.250 39.355 bYP 009.H03 YER[f~iC~TIUN blSTINS P,~GE 10 RMOB 2.043 CALk NRAT 4.105 NCNb URAN -999,250 POTA DLD -999.250 LbS ILD 6.512 ibm 20,922 GR 1390.000 -999.250 -999.250 SfLU 4.426 SP DEPT 300.)00 DT MNOR -999.25U MiNV RHOB 1.836 CALl NRAT 4.223 NCNL URAN -999.250 LLD -999.250 LbS iLL 99.625 ibm -999.250 GE -999.250 CALl 21.271 1292.000 FCNL -999.250 -999.250 SFLU 37.781 SP DEPT 200.000 MNUR -999.250 M[NV fHOB 2.212 CALl NRAT 4.070 NCNL URAN ' -999.250 PO'lA bbD -~99.250 ILL 102.125 ibm -999.250 '(R -999.250 CALl 17.896 GR 1372.000 f'CNL' · 999.250 SGR -999.253 SfLU 61.8~5 SP DEPT 100.)00 DT MNUR -999.250 MiNV RHUB -999.250 CALI NRAT 4.656 NCNb URAN -999.250 POmA bbD -999.250 bLS ILL 2000.000 lb~ -999.250 GR - 999. 250 CALl -~99.259 6R 1214.0( 0 FCNL -999.250 SGE -999.2~ 0 SFLU 0.507 SP DEPT 9?.0(0 DT MNOR -)99.250 MiNV RHOB -999.250 CALl NRAT -999.250 NCNL ORaN -999.250 POTA LLD -999.250 bbs 1LD 20~0.000 ibm · 999.250 GR -999.25) CALl -999.250 GR -999.250 f'CNL -999.250 SGR -999.250 SFLU 0.815 SP #* F~b~ TRAILER #* FiLE NAME :SEE~IC.O01 SERVI2E NAMf] : VER$10N # : DATE : MAXIMUM L~NG~H : 1024 FILE TYPE : NEXT f'Ib~ NAM~ : *~ TAPE TRAILEE ~ SEEVi2E NAM£i :SE~ViC, DATE :82/01/23 ORIGIN :107o .f4.539 334.750 THOE -9~9.250 4.348 GE ~?.945 GE -999.250 PROX -999.250 NPHi 27.664 DEHO 280.500 THOR -999.250 CGR 107.938 GR -85.083 GR -999.250 PRCX -999.250 NPHI 42.969 DRHO 353.750 THOR -999.250 CGR 309.750 GR -~8.063 GH -999.250' PROX -999.250 NPHI 17,832 DRHC 2~5.500 THOR -99~.250 CGR 1.~2~ GR -99~.250 .GR -999.250 PROX -999.250 NPBI -99~.250 THOR -9~9.250 ~(G~ 1.072 GR -999.250 GR 0.000 -)99.250 -999.250 -)99.250 57.672 -999.250 4i~.370 0.083 -999.250 -999.250 -999.250 26.402 -999.250 40.906 0,017 '999.250 -999.250 -999.250 4~.758 -999.250 49.841 -999.250 -9~9.250 -999.250 -9~9.250 17.055 -999.250 50.879 -9!9.250 -~99.250 -999.250 -)99.250 ~8.406 bVp O09.t't[~: VERII~ICATI[~N LI6'I~I,N(J PAGE TAP~ NAME :62503 CONTiNUATiUN # :01 NEXT TAPE NAME : COMMENTS :TAFE O£MMENT6 ~* REEL TRAILER ** SERV iC'k NAME ::2ERV1C D.~TE :82/01/23 OR1G1N : REEL NAt4~ :~EEL ID CONTINUATIUN # :(1 N~XT RE~L NAME : CONFIDENTIAL