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190-089
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPH-04 (PTD# 190-089) Missed AOGCC Witness MIT-IA Date:Wednesday, May 31, 2023 2:57:24 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, May 31, 2023 2:20 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: MPH-04 (PTD# 190-089) Missed AOGCC Witness MIT-IA Mr. Wallace – PWI well MPH-04 (PTD# 190-089) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA. 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 comments or concerns. Thanks, Ryan Thompson Milne / Islands 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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 responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim I DATE: Friday, May 31, 2019 �/)Z.I � P.I. SReggupervisor I SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC H-04 FROM: Jeff Jones MILNE PT UNIT H-04 Petroleum Inspector Sre: Inspector Reviewed BILL P.I. Supry J Cjl� NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT H-04 IInsp Num: mitJJ190531104129 Rel Insp Num: API Well Number 50-029-22064-00-00 Inspector Name: Jeff Jones Permit Number: 190-089-0 Inspection Date: 5/13/2019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well T H-04 TypeInj w ITVD T 3713 Tubing' 1036 1037 - 1036 1035 PTD 1900890 "Type Test[ SPT Test psi soo IA o r3 _ 1644 1635 - BBL Pumped. 07 ' BBLReturned: 07 OA =13 249 350 'so Interval 4YRTST ;P/F P Notes: I well inspected, no exceptions noted. - Friday, May 31, 2019 Page I of I STATE OF ALASKA ALIIIL OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LI Plug Perforations Li Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Well Repair 2.Operator p ElRe-enterSusp Well El Other:CT FCO-Nitrogen ❑✓ Name: Hilcorp Alaska LLC 4.Well Class Before Work: 5.Permit to Drill Number. Development ❑ Exploratory ❑ 190-089 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic Service El6.API Number: AK 99503 50-029-22064-00-00 7.Property Designation(Lease Number): 8.Well Name and Number ADL0025906 MILNE PT UNIT H-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 4,496 feet Plugs measured N/A RECEIVED true vertical 4,362 feet Junk measured 4390(Fill) feet 3,762,3,811 & JUN 16 2017 Effective Depth measured 4,390 feet Packer measured 4,168 feet 3,666,3,713& Ac true vertical 4,263 feet 4,054 true vertical feet Casing Length Size MD TVD Burst Collapse Conductor 105' 13-3/8" 105' 105' N/A N/A Surface 2,562' 9-5/8" 2,562' 2,524' 3,520psi 2,020psi Production 4,472' 7" 4,472' 4,339' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet SCANNED ,ILi , 2 L') .7, True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 4,183' 4,069' D&L,Baker SC-1L Packers and SSSV(type,measured and true vertical depth) &Baker D N/A See Above N/a 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 240 2,050 Subsequent to operation: 0 0 0 240 2,225 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory El Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-047 Authorized Name: Bo York Contact Name: Stan PorholaS" " Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.corn Authorized Signature: * J Date: 1 4 _.) �Y.` ! Contact Phone: 777-8412 Form 10-404 Revised 4/2017 RBDMS I v ,)Uig L 6 2017 Submit Original Only • • . Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-04 Coil 50-029-22064-00-00 190-089 2/11/17 7/7/17 Daily Operations: 6/7/2017 -Wednesday MIRU SLB CT#8. PJSM. Perform BOP test. MU BHA- 1.5" CRC, DBPV, 2 x 5.5' stingers, 1.5" DJN. OAL= 12.95'. Stab on well. NU BOPE. Fluid pack to tank. PT low and high - 300 psi/3,600psi. CTMD corrected to RKB-add 20'. Open Well -T/I/O = 410/200/200. RIH and Well pressured up with choke closed. Open choke and maintain 300-400psi WHP. Initial TAG at 4,165' ctmd (4,185' MD) (WLEG at 4,182' on schematic). PU and start cleaning out from 4,149' ctmd. Clean out to PBTD at 4,370' ctmd (4390' MD). During first part of cleanout had to open choke full open to maintain returns. Clean out with slick 1% KCL water and Gel sweeps. Ave pump rate of 1.4 bpm/3,500psi. CTP/30psi WHP. POOH pumping at max rate/3,900psi CTP, chasing returns. Returns are thick schmoo and solids. FP coil with 60/40 while POOH.At surface. Pump 13 bbls 60/40 down backside to FP well. Final injection rate was 1.6 bpm at 897psi WHP. Close swab. Remove fusible cap. Blow down surface lines. RDMO. Notify Pad Op status of well. 6/8/2017-Thursday, No activity to report. 6/9/2017- Friday No activity to report. 6/10/2017-Saturday No activity to report. 6/11/2017-Sunday No activity to report. 6/12/2017- Monday No activity to report. 6/13/2017-Tuesday No activity to report. . 11 • Milne Point Unit Well: MPU H-04 SCHEMATIC Last Completed: 5/13/2015 Hileorp Alaska.LLC PTD: 190-089 Orig.KB Elev.:72.0'/Orig.GL Elev.:37.0 CASING DETAIL RKB-Haw r:35.0'(Nordic#3) Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/K-55/Weld 12.615 Surface 105' 13-3/8"!'I 3 3/8"t4 9-5/8" Surface 36/K-55/BTC 8.921 Surface 2,562' 7" Production 26/L-80/BTC 6.276 Surface 4,472' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 2.441 Surface 4,183' JEWELRY DETAIL 9-5/8" No Depth Item Est.TOC @3,200' 1 3,763' XO 2-7/8"X 4-1/2" i!= 2 3,764' Packer 7"D&L Hydraulic Set Perm 4.5"LTC RA Tag in collar 3 3,769' X0 4-1/2"x 2-7/8" @3,326' _ 4 3,802' 2-7/8"XN Nipple w/2.225"no-go ID x 5 3,810' 80-40 S-22 Snap Latch(seals removed) 1 `''° 6 3,811' Packer:7"Baker SC-IL(4.000"ID) 1.11 :' 7 3,820' Sliding Sleeve 1 2 8 3,845' 2-7/8"Blank Pipe 7:4 9 4,076' 2-7/8"Screen:Bakerweld 12 ga. 3 ;r 10 4,155' Polished Bore Receptacle:ID= 2.062" I ,. 11 4,156' 2-7/8"Screen:Bakerweld 12 ga. 4t 12 4,167 Snap Latch 13 4,168' Packer:Baker'D'Sump ` 5 14 4,170' Seal Assembly et 4, 15 4,181' XN Nipple:Otis-ID=1.791"No Go 16 4,182' WLEG-Bottom @ 4,183' 6 ' PERFORATION DETAIL , Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status 1r l fx 7 "NB"Sands 4,086' 4,099' 3,976' 3,989' 13 1/10/1991 Open A "NC"Sands 4,111' 4,118' 4,000 4,007 7 1/10/1991 Open 1 9 "NE"Sands 4,134' 4,154' 4,022' 4,041' 20 1/10/1991 Open M NB "OA"Sands 4,208' 4,238' 4,092' 4,120' 30 1/5/1991 Open ANC "OB"Sands 4,274' 4,288' 4,154' 4,186' 14 1/5/1991 Open SNE N'Sands Perfeed w/24gm.BH 43C;'0'Sands perfed w/37gm.Hyperjet II;(EHD=0,49",TTP=30,25")w/72 Deg.Phasing _-10 WELL INCLINATION DETAIL 1.4::•••:' , KOP @ 1,400' STIMULATION SUMMARY ( .'.. 11 Max Hole Angle=18 to 21 deg.f/2,250'to TD 'N'Sands Frac Packed w/8,100Ibbs of 20/40 Sand Hole angle thru perfs=19 deg. `''' •' 12 DLS=4 deg./100'f/1,650 to 1,850 13 OPEN HOLE/CEMENT DETAIL 13-3/8" 500 sx Permafrost in a 30"Hole CL 1-2 ; . 9-5/8" 1,014 sx Arctic Set&250sx Class'G'in a 12-1/4"Hole 14' 7" 211 sx Class'G'in a 8-1/2"Hole 1 15 TREE&WELLHEAD Fill @ i 16 4370Tree 2-9/16"-5M WKM 6107117 -QA Wellhead 11"5M WKM w/11"x 2-7/8"tbg.Hanger,2.5"'H' BPV profile and 8rd EUE threads top and bottom OB GENERAL WELL INFO API:50-029-22712-00-00 Drilled and Cased by Nabors 27E-10/18/1990 Completed w/Gravel Pack and ESP-1/26/1991 RWO ESP Replacement by Nabors 4ES-9/14/1994 RWO ESP Replacement by Nabors 4ES-1/20/1997 Ik'' RWO ESP Replacement by Nabors 4ES-2/1/1998 RWO ESP Replacement by Nabors 4ES-3/9/2001 Remove and Replace Tubing Patch-2/26/2006&4/8/2006 TD=4,496'(MD)/TD=4,362'(TVD) Pull Tubing Patches-9/9/2006 PBTD=4,393'(MD)/PBTD=4,266'(TVD) RWO ESP Replacement by Nabors 4ES-9/17/2006 RWO ESP Replacement by Nabors 35-9/13/2008 WINJ Conversion w/Nordic 3-5/12/2015 Revised By:STP 6/12/2017 • • • SOF 7.4 � THE STATE Alaska Oil and Gas ti�,-s - of e T Conservation Commission ALAS 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS • +^^ -_� .�., Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC SCANNED MAS 0 92017, 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU H-04 Permit to Drill Number: 190-089 Sundry Number: 317-047 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a4 /al)e )S4 Cathy P. oerster Chair DATED this 2 day of February, 2017. RBDMS ly FEB - 3 2017 • • RECEIVED STATE OF ALASKA JAN 2 5 2 17 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS %3GW7 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ CT FCO❑., Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Coil-Nitrogen❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 190-089 ' 3.Address: Stratigraphic ElService L. 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-22064-00-00 1 7.If perforating: 8.Well Name and Number: �A What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 / (�' Will planned perforations require a spacing exception? Yes CI No O/ MILNE PT UNIT$r6 H-04 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906. MILNE POINT/SCHRADER BLUFF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 4,496' ' 4,362' • 4,393' 4,266' 1,491 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 105' 13-3/8" 105' 105' N/A N/A Surface 2,562' 9-5/8" 2,562' 2,524' 3,520psi 2,020psi Production 4,472' 7" 4,472' 4,339' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic/ See Attached Schematic 2-7/8" 6.5#/L-80/EUE 4,183 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): , D&L;Baker SC-1L;Baker D and N/A 3,762'(MD)&3,666'(TVD);3,811'(MD)&3,713'(TVD); 4,168'(MD)&4,054'(TVD)and N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory 0 Stratigraphic❑ Development❑ Service ❑✓ 14.Estimated Date for 15.Well Status after proposed work: 2/7/2017 Commencing Operations: OIL ❑ WINJ ❑✓ • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola S--P Email sporhola@.hilcorp.com Printed Name Bo York Title Operations Manager V' 2S Signature / Phone 777-8345 Date 1/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ l..irjf- -? I'-Iia Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ [- Spacing Exception Required? Yes ❑ No VSubsequent Form Required: f 0 — ‘-1634-1 RBDMS U FF3 - 3 2017 / / APPROVED BY Approved by: `41y / g- ip i � h5 COMMISSIONER THE COMMISSION Date:Z-Z —1 K7 1/'Z" iT ^ 1. -I_/7 Submit Form and Form 10-403 Revised 11/2015 ®Rivolpk4ioAi$/alid for 12 months from the date of ap oval. Attachments in Duplicate D/7, '�K(`` V �H.� �L • • Well Prognosis Well: MPU H-04 Hileorp Alaska,LD Date:1/24/2017 Well Name: MPU H-04 API Number: 50-029-22064-00 Current Status: Water Injector Pad: Milne Point H-Pad Estimated Start Date: February 7th, 2017 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-089 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) 40406 ber: w ig filar C,' = 19110, Gott Rai •Cern• Current Bottom Hole Pressure: 1,891 psi @ 4,000' TVD (Last BHP measured 8/20/2013) Maximum Expected BHP: 1,891 psi @ 4,000' TVD (No new perfs being added, EMW= 9.1 ppg) MPSP: 1,491 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU H-04 was drilled in 1990 using Nabors 27E and in 1990 ran a gravel pack using EWS #4 in the Schrader Bluff OA, OB, NE, NC, and NB sands with an ESP.Several ESP pulls and replacements with Nabors#4ES occurred in 1994, 1997, 1998, 2001, 2006 and Nabors#35 in 2008.The completion was pulled and changed out in 2015 using Nordic#3 and the well converted to a water injector. Notes Regarding Wellbore Condition • Max deviation at the base of the permafrost (max angle 20.7° @ 4,496'). • Casing last tested to 2,000 psi for 30 min down to 3,762' on 5/28/2015. • Deviation at perfs is 20.0°. • Tubing below gravel pack is 2-3/8". Min ID is 1.791"thru XN profile. • Last Fill Depth:4,188' MD tagged on 9/20/2015. Objective: The purpose of this work/sundry is to cleanout fill across the OB perfs using a nitrogen foam cleanout. l C>.4 Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 5 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. t. <4..:.:.> N /Le ti`r` c. Submit 10-424 form within 5 days. 3. RIH w/1.50" coil w/1.5"to 1.75" max OD wash nozzle and cleanout BHA and cleanout to PBTD at+/- 4,393' MD (in 7" casing). POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the 7" casing. • • Well Prognosis Well: MPU H-04 Hilcorp Alaska,LL) Date: 1/24/2017 b. Contingency: If unable to wash down with nozzle, RIH w/1.5" to 1.75" reverse circ BHA and reverse circulate (see Reverse Circulating diagram) to PBTD at+/-4,393' MD (in 7" casing). POOH. c. Contingency: If unable to reverse circulate, RIH w/ 1.5"to 1.75" mill and motor BHA and cleanout to PBTD at+/-4,393' MD (in 7" casing). POOH. 4. RIH w/ 1.50" coil w/1.5"to 1.75" max OD wash nozzle and cleanout BHA and cleanout to PBTD at+/- 4,393' MD (in 7" casing). POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/1.5"to 1.75" mill and cleanout BHA and cleanout to PBTD at+/-4,393' MD (in 7" casing) using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 5. RIH w/1.50" coil w/1.5" to 1.75" max OD wash nozzle and cleanout BHA and cleanout to PBTD at+/- 4,393' MD (in 7" casing). Circ 30 bbl of heated diesel with Barascrub (to remove schmoo) and displace w/ 1% KCI to surface. POOH. 6. PU to 2,200' and freeze protect well. POOH w/coil. • 7. RD Coiled Tubing and ancillary equipment. 8. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen &Foam Flow Diagram 5. Reverse Circulating Flow Diagram Milne Point Unit • iii • . Well: MPU H-04 SCHEMATIC Last Completed: 5/13/2015 Iiikrorp Alaska,LLC PTD: 190-0$9 Orig.KBElev.:72.0'7Orig.GLElev.:37.0 CASING DETAIL RKB-Hanger:35.0'(Nordic#3) Size Type Wt/Grade/Conn ID Top Btm 0, 13-3/8" Conductor 54.5/K-55/Weld 12.615 Surface 105' 13 3/84s 9 5/8" Surface 36/K-55/BTC 8.921 Surface 2,562' f 7" Production 26/L-80/BTC 6.276 Surface 4,472' TUBING DETAIL 44 2-7/8" Tubing 6.5/L-80/EUE 2.441 Surface 4,183' VI 'qt JEWELRY DETAIL 9-5/8" `s No Depth Item Est.TOC @3,2017 1 3,763' X0 2-7/8"X 4-1/2" 2 3,764' Packer:7"D&L Hydraulic Set Perm 4.5"LTC RATagincollar 3 3,769' XO 4-1/2"x 2-7/8" ®3,326' € 4 3,802' 2-7/8"XN Nipple w/2.225"no-go ID 5 3,810' 80-40 S-22 Snap Latch(seals removed) 1 '' 6 3,811' Packer:7"Baker SC-IL(4.000"ID) V A 7 3,820' Sliding Sleeve 2 1 / 8 3,845' 2-7/8"Blank Pipe > ' 9 4,076' 2-7/8"Screen:Bakerweld 12 ga. 10 4,155' _ Polished Bore Receptacle:ID= 2.062" 44 11 4,156' 2-7/8"Screen:Bakerweld 12 ga. VA 4. 12 4,167' Snap Latch two 13 4,168' Packer:Baker`D'Sump 14 4,170' Seal Assembly 15 4,181' XN Nipple:Otis-ID=1.791"No Go 16 4,182' WLEG-Bottom @ 4,183' ` 6 * PERFORATION DETAIL '?31" Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status {4 Z Jg 7 "NB"Sands 4,086' 4,099' 3,976' 3,989' 13 1/10/1991 Open .., `� 8 "NC"Sands 4,111' 4,118' 4,000' 4,007' 7 1/10/1991 Open ,r.it "NE"Sands 4,134' 4,154' 4,022' 4,041' 20 1/10/1991 Open yNB "OA"Sands 4,208' 4,238' 4,092' 4,120' 30 1/5/1991 Open 3 NC "OB"Sands 4,274'. 4,288' 4,154' 4,186' 14 1/5/1991 Open ,3i i NE `N'Sands Perfeed w/24gm.BH 43C;'0'Sands perfed w/37gm.Hyperjet II;(EH D=0.49",TTP=30,25")w/72 Deg.Phasing i ,s ,10 WELL INCLINATION DETAIL -.S.- - ' KOP @ 1,400' STIMULATION SUMMARY 11 Max Hole Angle=18 to 21 deg.f/2,250'to TD 'N'Sands Frac Packed w/8,100lbbs of 20/40 Sand a �k,.� Hole angle thru perfs=19 deg. _ 12 DLS=4 deg./100'f/1,650 to 1,850'' „ 13 OPEN HOLE/CEMENT DETAIL 13-3/8" 500 sx Permafrost in a 30"Hole 9-5/8" 1,014 sx Arctic Set&250sx Class'G'in a 12-1/4"Hole ( 114 7" 211 sx Class`G'in a 8-1/2"Hole (i 1 15 TREE&WELLHEAD Fill@ 4.s 16 Tree 2-9/16" SM WKM 4,188' 9I20/15 OA Wellhead 11"SM WKM w/11"x 2-7/8"tbg.Hanger,2.5"`H' BPV profile and 8rd EUE threads top and bottom 06 GENERAL WELL INFO C,r API:50-029-22712-00-00 r;.0 r� Lry Drilled and Cased by Nabors 27E-10/18/1990 ▪ ;:;:;t`a::i;: ; (_` Completed w/Gravel Pack and ESP-1/26/1991 ..;a..a.: ` RWO ESP Replacement by Nabors 4ES-9/14/1994 RWO ESP Replacement by Nabors 4ES-1/20/1997 ' RWO ESP Replacement by Nabors 4ES-2/1/1998 7 • , r n', RWO ESP Replacement by Nabors 4ES-3/9/2001 Remove and Replace Tubing Patch-2/26/2006&4/8/2006 TD=4,496'(MD)/TD=4,362'(TVD) Pull Tubing Patches-9/9/2006 PBTD=4,393'(MD)/PBTD=4,266'(TVD) RWO ESP Replacement by Nabors 4ES-9/17/2006 RWO ESP Replacement by Nabors 3S-9/13/2008 WINJ Conversion w/Nordic 3-5/12/2015 Revised By:STP 1/24/2017 H . Mi Point Unit COIL BOPE MPU H-04 lIwu„ a,. p at ,L.IA; 1/24/2017 MPU H-04 13% x9%x 7x2'/8 Coil Tubing BOP To injection head 1 11 1.50"Single Stripper r Lubricator 1 0 1 I •',I,I Blind -4 1/16 15 .- Blind uIaI.t �� s lllV\V\V\ 01111 Shear ;®IM * 1IIuI. O 1.I,I, �_ ■� Slip .I.I• 1111.111111 41 J Slip JIiIi Pipe �ffil � Pipe ■I■I� J �s !tot Crossover spool 4 1/16 15M X 4 1/16 10M a'r a Crossover spool 144 IlItt 4 1/16 10M X 4 1/16 5M 3r a U Pump-In Sub 4 4 1/16 5M ■ 1.(o j4}I a `, . I n 1502 Union froManual Gate Manual Gate Crossover spool 2 1/8 5M 2 1/8 5M 4 1/16 5M X 2 9/16 5M Valve,Upper Master,WKM-M, Or � , 29/165MFE -a: Valve,Lower Master,WKM-M, firs , 2 9/16 5M FE _-: _ Tubing Adapter,2 9/16 5M 1 • • STANDARD WELL PROCEDURE Itikcorp ;1(aka.IAA NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • • y ooa °I° Y CO3 .4', E v> x s F v w ZO w V w ZZ w ttl S Y H V ~ •• • .. • 4sr Q� a o3ao12 83a000 til ; y 3 ° LL w 3 ° LL w Sco 0 o a ca to W 7 A ftl J7 e+ a o a }..•• .a w 9 O W U Ct .-1 ...r : 'v':'..v 9 ~ u.,., G Z ° i Y 0 • 7i, "7'®1-1 -co*Taooa— A COI 0iv V v E aooa— V L.2 LL n o � .. �T n o _ 1I F �� !fill" A IIS 0 � � - _ N Z w a 9 w Fa v ` = LL V 0 0 0 O m W VI a D K w w a Q 33o Z N o a H Y 2 m m K o a D m m 0 0 a 0. loilliziorc 411: z:1 I D0:1 ›. • -8 § 4 = w 0 L., LLJ 0 LU r.J.4 > MI 4 = ...s.2 = Pu --"---2 w F- u - , •• ..........* = 83 < ouE 03 .-tou2 ° E...--: .r7...,.., ..,..._.„ . .''..S. e 0 0 5 "'",%,... 0 = :.•. . o. E a u " : : E .... ... .1.. --, Fj ititil=Mi e L.., II: -6 0 >' b ,• -0-. ..i (?4 5 •r'z "A A 1.6 o° o a u., >• (.7r:COu-, ...: :"...,-...1,,.... x oldi _ .,, ..,_ ' - 1:3 1- o z o m _, a 1 . u 8 . . . .•.1 7 V 2 -Dont*DOci— J V sit ° 0 o § ni I 11 II.if'i'lli OS ii la 7 C o 0 om 2 In a V z 4 1- ...i" 2 8 Ln ••"; 0..?.- £ RECEIVED STATE OF ALASKA ALOKA OIL AND GAS CONSERVATION COM SION SEP 2 9 2015 REPORT OF SUNDRY WELL OPERATIONS , . : ,,. 1.Operations Abandon Plug Perforations H Fracture Stimulate _I Pull TubingU J Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Convert to Injector 0 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 190-089 3.Address: Stratigraphic❑ Service ❑., 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22064-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT SB H-04 - 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 4,496 feet Plugs measured 4,266 feet true vertical 4,362 feet Junk measured N/A feet 3,762,3,811 & Effective Depth measured 4,393 feet Packer measured 4,168 feet _ 3,667,3,713& true vertical 4,266 feet true vertical 4,054 feet Casing Length Size MD TVD Burst Collapse Conductor 105' 13-3/8" 105' 105' 2,730psi 1,130psi Surface 2,562' 9-5/8" 2,562' 1,562' 3,520psi 2,020psi Production 4,472' 7" 4,472' 4,340' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic feet JAN 2 0 2016 4.001) True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 4,183' 4,069' 7"Hyd Set Perm. 3,762/3,667 7"SC-IL 3,811 /3,713 Packers and SSSV(type,measured and true vertical depth) D Sump N/A 4,186/4,054 N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 500 470 Subsequent to operation: 0 0 445 960 1,161 14.Attachments(required per 20 FAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory H Development❑ Service ❑., Stratigraphic H Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑✓ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-242 Contact Stan Porhola Email sporhola(@.hilcorp.com Printed Name Stan Porhola Title Operations Engineer y Signature4144;:,101/4 Phone 777-8412 Date 9/29/2015 Form 10-404 Revised 5/2015 /G' d Z /5 RBDMS IJL 0 1 LOIS i� o r I Submit Original Only • • Milne Point Unit Well: MPU H-04 SCHEMATIC Last Completed: 5/13/2015 Hilcorp Alaska,LLC PTD: 190-089 CASING DETAIL Orig.RKB AGL:35'/Orig.GL Elev.:37' Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/K-55/Weld 36/K 55/Btrc. 12.615 Surface 105' 133/8 ' 9 5/8" Surface 8.921 Surface 2,562' ,, ,r 7" Production 26/L-80/Btrc 6.276 Surface 4,472' I TUBING DETAIL `'^I i a" 2-7/8" Tubing 6.5/L-80/EU 8rd 2.441 Surface 4,183' JEWELRY DETAIL '41 Vi W. No Depth Item 1 1 3,762' 7"Hydraulic Set Perm.Isolation Packer 4.5"LTC D&L t:4 tt :1 2 3,803' 2-7/8"XN Nipple w/2.225"no-go ID 3' 3 3,811' Packer:7"Baker SC-IL/Snap Latch Seal Assy. •y 4 3,845' 2-7/8"Blank Pipe It 'i' 5 4,076' 2-7/8"Screen:Bakerweld 12 ga. Com' 6 4,155' Polished Bore Receptacle:ID= 2.062" si A,uq 7 4,156' 2-7/8"Screen:Bakerweld 12 ga. A lr' 8 4,168' Packer:Baker'D'Sump 9-5/8" 9 4,181' XN Nipple:Otis-I0=1.791"No Go j 10 4,182' WLEG-Bottom @ 4,183' PERFORATION DETAIL RATag incollar @ Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status 3,326' Est.TOC @ 3,200' e "NB"Sands 4,086' 4,099' 3,976' 3,989' 13 1/10/1991 Open "NC"Sands 4,111' 4,118' 4,000' 4,007' 7 1/10/1991 Open "NE"Sands 4,134' 4,154' 4,022' 4,041' 20 1/10/1991 Open " "OA"Sands 4,208' 4,238' 4,092' 4,120' 30 1/5/1991 Open "013"Sands 4,274' 4,288' 4,154' 4,186' 14 1/5/1991 Open 'N'Sands Perfeed w/24gm.BH 43C;'0'Sands perfed w/37gm.Hyperjet II;(EHD=0,49",TTP=30,25")w/72 Deg.Phasing i WELL INCLINATION DETAIL µ` KOP @ 1,400' Max Hole Angle=18 to 21 deg.f/2,250'to TD Hole angle thru perfs=19 deg. il DLS=4 deg./100'f/1,650 to 1,850' STIMULATION SUMMARY 'N'Sands Frac Packed w/8,1001bbs of 20/40 Sand 4 { OPEN HOLE/CEMENT DETAIL 4 13-3/8" 500 sx Permafrost in a 30"Hole 9-5/8" 1,014 sx Arctic Set&250sx Class'G'in a 12-1/4"Hole 7" 211 sx Class'G'in a 8-1/2"Hole TREE&WELLHEAD Tree 2-9/16"-5M WKM Wellhead 11"5M WKM w/11"x 2-7/8"tbg.Hanger,2.5"'H' 0 BPV profile and 8rd EUE threads top and bottom a GENERAL WELL INFO 4 1 API:50-029-22712-00-00 .40_© 3 Drilled and Cased by Nabors 27 -10/18/1990 Completed w/Gravel Pack and ESP-1/26/1991 I1 RWO ESP Replacement by Nabors 4ES-9/14/1994 fm� RWO ESP Replacement by Nabors 4ES-1/20/1997 7 ° RWO ESP Replacement by Nabors 4ES-2/1/1998 '8 9 ll RWO ESP Replacement by Nabors 4E5-3/9/2001 10 Remove and Replace Tubing Patch-2/26/2006&4/8/2006 V Pull Tubing Patches-9/9/2006 7 r.4.r,Ca RWO ESP Replacement by Nabors 4ES-9/17/2006 TD=4,496'(MD)/1D=4,362'(TVD) RWO ESP Replacement by Nabors 3S-9/13/2008 PBTD=4,393'(MD)/PBTD=4,266'(TVD) WINJ Conversion w/Nordic 3-5/12/2015 Revised By:TDF 5/28/2015 • • Hilcorp Alaska, LLC 11i14orpAlaska.LLc Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPH-04 50-026-22064-00-00 190-089 5/10/2015 5/13/2015 Daily Operations: 5/6/15-Wednesday No operations to report. 5/7/15-Thursday No operations to report. 5/8/15-Friday No operations to report. 5/9/15-Saturday No operations to report. 5/10/15-Sunday Accept rig. MIRU spot tanks and containment,spot spooler, berm cellar, run hardline to kill tank,offload SW, Pull BPV. OA 350psi/IA 500psi/TBG 410psi. Pressure test all lines 250psi low/2,500psi high. BOP test waived by Matthew Herrara AOGCC 5/9/15 19:46 hrs. Blow down annulus and tbg to 65psi. No fluid in returns. Pump 140°8.5 ppg SW catch full circ after 20 bbls, heavy thick crude returns 1,150psi,3 BPM pump total 120 bbls. Increase pump rate to 4 bpm pressure @ 600psi. Circulate to clean tubing and cable,after 200 bbls circ. returns still dirty, increase rate to 6 BPM 1,015psi pump 50 bbls. 250 bbls pumped.Shut down check flow. Light flow. 218 bbls returned. Monitor well, light flow SIP>20 psi.Weight up to 8.7 ppg w/NaCI. Displace well with 8.7 ppg brine @ 3bpm 270 psi. Monitor well.Well gassing,still trying to flow. Weight up to 8.8 ppg, monitor well,still trying to slighlty flow. Install BPV. ND tree NU BOPE, monitor annulus. 5/11/15-Monday NU BOPE. BOP test and chart 250psi low/3,000psi high.Annular test 250psi low/2,500psi high.Accumulator draw down test. Remove TWC, rig up chrome handling tools, install landing JT, pull hanger w/85k initial 73 k travel. Pull hanger.Well info is incorrect Hanger is x-overed via EUE and TC II to VAM TOP. Decomplete hanger and penetrators,disconnect ESP and heat trace cables. BO LD hanger and pups. Pull pipe in singles LD and slip cables over sheaves to spooler. POOH LD Chrome. 2-7/8"VAM with ESP and heat trace string utilizing hand slips and safety clamp and x-over elevator stop on every joint. 74 jts out,slug tubing with seawater oil u-tbg., at 76 jts end of heat trace. Resume POOH withtb&and ESP to 400'. �----� --- 5/12/15-Tuesday Continue POOH,total 113 jts, and LD ESP chrome handling equipment. Clean rig floor and tools. PU MU casing scraper and mule shoe. PU MU new 2-7/8" L-80 EUE tbg. RIH to top of GP packer @ 3,805' reverse circ.and check tag again. POOH with same LD scraper. PJSM MU snap latch assy.with seals removed, ported x-over, pup joint,XN-nipple w/RHC plug in place, 1 jt 2-7/8" EUE tbg, hydraulic set permanent 7"26#packer, pup jt,and RIH with 117 jts tbg.Scraper snap in snap out 10k and repeat same 10k.Space out,space out measurement puts latch in profile but possibly a little short. Pup availability from 2-4 feet plus elect to go with 2'. RIH and land, 63K see BHA enter GP just prior to landing. No Latch. Depths are WLEG inside GP 3,817'.Top of snap latch seal assy 3,815', ported XO w/0.75" hole, Pi,XN-profile 3,808',XO, hydraulic set packer 3,770',XO, 6' pup, 117 jts 2-7/8 EUE L-80 tbg, 2' pup, 5.5' pup and hanger. Original KB 35'.Set BPV. ND BOP. Install tree won't align (tree without alignment flange)cross threaded DE wellhead bolt galled. Bolt removed. NU tree. Rig up to pump freeze protect, install lubticator for bar drop. Pumping freeze protect. • • Hilcorp Alaska, LLC IIileuip Alaska.LL( Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPH-04 50-029-22064-00-00 190-089 5/10/2015 5/13/2015 Daily Operations: 5/13/15-Wednesday Pump 15 bbls diesel freeze protect down tbg and 75 bbls down annulus. Drop Bar. Pressure up on tubing packer,shear @ 3,000 psi, pressure to 4,000 psi and hold 10 minutes. Bleed off annulus and chart test casing to 1,500 psi for 30 minutes. ISC RDMO. fit 5/14/15-Thursday Y No operations to report. 5/15/15-Friday No operations to report. 5/16/15-Saturday No operations to report. 5/17/15-Sunday No operations to report. 5/18/15-Monday No operations to report. 5/19/15-Tuesday No operations to report. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 16,2015 Jim Regg P.I.Supervisor Ne �'ll a Il`� SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC H-04 FROM: Matt Herrera MILNE PT UNIT SB H-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J13(2-- NON-CONFIDENTIAL t2NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB H-04 API Well Number 50-029-22064-00-00 Inspector Name: Matt Herrera Permit Number: 190-089-0 Inspection Date: 5/28/2015 Insp Num: mitMFH150531151829 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well H-04 ' 1Type Inj W-'TVD 3713 Tubing 1029 1031 , 1036 - 1031 1031- 1031- PTD 1900890 Type Test SPT Test psi 1500 - IA 1004 2022 - 1966 1973 1963 - 1960 . IntervallIINITA1 P/F P OA 362 363 364 365 364 364 Notes: l > (A)e(( C,�IU[r J k� 7„ ec �� L, S -A1 4r-X,e� �i�-242— ( 21 �� SCANNE© JUL 1 3 ?U Tuesday,June 16,2015 Page I of 1 Brooks, Phoebe L (DOA) pTD k Iq 00$9 0 From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, June 01, 2015 4:16 PM To: Brooks, Phoebe L(DOA) Subject: RE: MIT NS-28 (PTD#2050160) Attachments: image001 jpg; image002 jpg; MP H-04 SCHEMATIC 5-26-2015.doc; NS-28 SCHEMATIC 4-7-2015.doc Hello Phoebe, Please see the attached schematics for MPH-04 and NS-28. I have updated the NS-28 MIT form with the Matt Herrera's name. Thank You, Wyatt Rivard Well Integrity Engineer 0: (907) 777-8547 1 C: (509)670-8001 I wrivard@hilcorp.com 3800 Cenlerpnint Drive,Suite 14001 Anchorage,AK 99503 flilror!) \la.k:ti.Ltd. From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Monday, June 01, 2015 3:57 PM To: Wyatt Rivard Subject: RE: MIT NS-28 (PTD # 2050160) Wyatt, Can I also add MPH-04 to the list? Thanks, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax:907-276-7542 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. 1 Milne Point Unit Well: MPU H-04 II SCHEMATIC Last Completed: 5/12/2015 tia<,i��,�:at t.ka.IAA, PTD: 190-089 CASING DETAIL Orig.RKB AGL:35'/Orig.GL Elev.:37' Size Type Wt/Grade/Conn ID Top Btm { ., 13-3/8" Conductor 54.5/K-55/Weld 12.615 Surface 105' 13-3/8"Z '. ' 9-5/8" . Surface 36/K-55/Btrc. 8.921 Surface 2,562' i,,i 7" Production 26/L-80/Btrc 6.276 Surface 4,472' TUBING DETAIL 2-7/8" Tubing 6.4/L-80/EU 8rd 2.441 Surface 3,811' JEWELRY DETAIL No Depth Item 1 3,762' 7"Hydraulic Set Perm.Isolation Packer 4.5"LTC D&L 2 3,803' 2-7/8"XN Nipple w/2.225"no-go ID a 3 3,811' Packer:7"Baker SC-IL/Snap Latch Seal Assy. i,`. 4 3,845' 2-7/8"Blank Pipe 5 4,076' 2-7/8"Screen:Bakerweld 12 ga. i 6 4,155' Polished Bore Receptacle:ID= 2.062" 7 4,156' 2-7/8"Screen:Bakerweld 12 ga. 8 4,168' Packer:Baker'0'Sump 9-5/8' 9 4,181' XN Nipple:Otis-ID=1.791"No Go 10 4,182' WLEG-Bottom @ 4,183' PERFORATION DETAIL RA rag incolIar@ Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 3,326' Est.TOC @ 3,200' "N"Sands 4,086' 4,099' 3,976' 3,989' 13 1/10/1991 Open "N"Sands 4,111' 4,118' 4,000' 4,007' 7 1/10/1991 Open "N"Sands 4,134' 4,154' 4,022' 4,041' 20 1/10/1991 Open "0"Sands 4,208' 4,238' 4,092' 4,120' 30 1/5/1991 Open "0"Sands 4,274' 4,288' 4,154' 4,186' 14 1/5/1991 Open 'N'Sands Perfeed w/24gm.BH 43C;'0'Sands perfed w/37gm.Hyperjet II;(EHD=0,49",TTP=30,25")w/72 Deg.Phasing V WELL INCLINATION DETAIL L KOP @ 1,400' , Max Hole Angle=18 to 21 deg.f/2,250'to TD Hole angle thru perfs=19 deg. 0 , '.* DLS=4 deg./100'f/1,650 to 1,850' STIMULATION SUMMARY a 'N'Sands Frac Packed w/8,1001bbs of 20/40 Sand OPEN HOLE/CEMENT DETAIL " 13-3/8" 500 sx Permafrost in a 30"Hole ;, 9-5/8" 1,014 sx Arctic Set&250sx Class'G'in a 12-1/4"Hole 7" 211 sx Class'G'in a 84/2"Hole TREE&WELLHEAD Tree 2-9/16"-5M WKM 11"5M WKM w/11"x 2-7/8"tbg.Hanger,2.5"'H' Wellhead BPV profile and 8rd EUE threads top and bottom GENERAL WELL INFO , ._. "1 API:50-029-22712-00-00 1 a 2 -; Drilled and Cased by Nabors 27 -10/18/1990 t 11 ',4 Completed w/Gravel Pack and ESP-1/26/1991 RWO ESP Replacement by Nabors 4ES-9/14/1994 5T RWO ESP Replacement by Nabors 4ES-1/20/1997 RWO ESP Replacement by Nabors 4ES-2/1/1998 am 9 8 RWO ESP Replacement by Nabors 4ES-3/9/2001 10 Remove and Replace Tubing Patch-2/26/2006&4/8/2006 Pull Tubing Patches-9/9/2006 7"A,..,,t . 1. RWO ESP Replacement by Nabors 4ES-9/17/2006 RWO ESP Replacement by Nabors 35-9/13/2008 TD=4,496'(MD)/TD=4,362'(TVD) WINJ Conversion w/Nordic 3-5/12/2015 PBTD=4,393'(MD)/PBTD=4,26C(TVD) Revised By:TDF 5/28/2015 1°,0-o6°1 \ of T� Alaska Oil and Gas yw I�jjs THE STATE '���,;,-s����, ofALASKA Conservation Commission r#z 333 West Seventh Avenue Anchorage, Alaska 99501-3572 of � � GOVERNOR BILL WALKER g Main. 907.279 1433 ALAS Fax: 907.276 7542 www.aogcc alaska gov M414 6) APP. 2 9 2015 Chris Kanyer Operations Engineer Hilcorp Alaska, LLC iv - o 9 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB H-04 Sundry Number: 315-242 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this 44 11of April, 2015 Encl. RECEIVED STATE OF ALASKA APR 2 1 2015 . ALASKA OIL AND GAS CONSERVATION COMMISSION 07-5 1/-/z �S• APPLICATION FOR SUNDRY APPROVALS AOG''C 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other: Convert to Injector L] 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC , Exploratory ❑ Development E. 190-089 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22064-00-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477 Will planned perforations require a spacing exception? Yes ❑ No 0 i MILNE PT UNIT SB H-04 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 4,496 4,362 4,393 4,266 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 105' 13-3/8" 105' 105' 2,730psi 1,130psi Surface 2,562' 9-5/8" 2,562' 1,562' 3,520psi 2,020psi Intermediate Production 4,472' 7" 4,472' 4,340' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EU 8rd 3,689 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"SC-IL&'D'Sump and N/A 3,811'(MD)/3,713'(TVD)&4,168'(MD)/4,054'(TVD)and N/A 12.Attachments: Description Summary of Proposal E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development❑ Service ❑I 14. Estimated Date for15.Well Status after proposed work: Commencing Operations: � S/3/0/5 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A WINJ E GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer(a�hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature < Phone 777-8377 Date 4/21/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3IS-2L-f2 Plug Integrity ❑ BOP Test Vi Mechanical Integrity Test CV Location Clearance ❑ Other: .4- 300° los, a c.f) *--TT:_,(— (IH4Ast°w I bf}1 -{-) 2S- (az- , -, ) Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /0—`IO`i APPROVED BY Approved by: alfrti p 2.64....,,,,„,(4.._ COMMISSIONER THE COMMISSION Date: C�_ L7-/S' cJ •)2/) n� t\I 4Lor 2 / / Submit Form and Form 10 403(Reed 10/2012) 4 li 12 months from the datd'Of aqbM 1hrleRs tpfgfolicate KKK��tSSS S�`� L J CUiJ Well Prognosis Well: MPH-04 llilcora Alaska,LL Date:4/21/2015 Well Name: MPH-04 API Number: 50-029-22064-00-00 Current Status: SI Producer Pad: H Pad Estimated Start Date: May 3, 2015 Rig: Nordic 3 Reg.Approval Req'd? May 1, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 190-089 First Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374 (M) Second Call Engineer: Bo York (907)777-8345 (0) (907)727-9247 (M) AFE Number: Current Bottom Hole Pressure: - 1,802 psi @ 4,000' TVD (Last BHP measured 8/20/2013) Maximum Expected BHP: - 1,802 psi @ 4,000' TVD (No new perfs being added) Max.Allowable Surface Pressure: 185 psi (Based on actual reservoir conditions and water cut of 90% (0.429psi/ft)with an added safety factor of 1000' TVD of oil cap) Brief Well Summary: The Milne Point H-04 well was drilled as a Schrader Bluff development well that TD'd at 4,496' and ran and cemented 7" casing in November 1991. The well was completed initially as an ESP producer. This completion and subsequent ESPs failed and were replaced in 1994, 1997, 1998, 2001, 2006, and 2008. The recent pump failed in May 2009. The most recent casing pressure test performed to 1,500psi on 9/11/2.08. A casing pressure test will be completed during this workover with the newly installed packer. {�v",,, p No subsidence issues are expected in this well. Cyn �r••‘42r fp 749 /y'f/4-1/- / 7 Gtr: Notes Regarding Wellbore Condition {cr root C?‹ Au/ C''c.reeseP re (e5s T q 4 601069 i ti e 1/... " heti 1 -"/e Current well status is shut in oil producer. No subsidence issues suspected. ,.,c on, re/hy,a%y tr4`vc cif y Variance from 20AAC25.412(b) Packer will be set greater than 200ft measured depth from perfs is requested. Lek 15 Ct (ra' vCtr• Cvndoe/r,4f /'j,f 'v'e/" to AOR(status of wells within 1/4 mile radius of injection zone): 4„ .nd«ro/ 5406,4 4/10 w leaf' i/hprover( fr c c "j 6.0A, j-j,,1 fb rt.'6, API Well No Permit Well Current Status Zonal isolation(method) op fir Estimated TOC (calculated) at 3,200'MD pool. 50-029-22064-00-00 190-089 MPH-04 S/I >850' above Schrader NB sand r 50-029-23106-00-00 202-152 MPI-15 Producing Estimated TOC (calculated) at 2,433'MD >2,000' above Schrader NB sand RWO Objective: Pull ESP, run casing scraper, & run 2-7/8" water injection completion with packer set+200ft from perfs. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Circulate well with 8.5ppg seawater and monitor well. 3. If necessary,circulate well with 8.7ppg brine (or appropriate kill weight fluid). Monitor well. 4. ND tree, NU 11" BOPE and test to 250psi low/3,000psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. Well Prognosis Well: MPH-04 llilrorp Alaska,LL: Date:4/21/2015 5. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 6. Unseat hanger and pull 2-7/8" chrome tubing, heat trace, and ESP completion from 3,689'to surface and lay down same. 7. RIH with cleanout BHA to+/-3,800'. POOH with same. 8. MU and RIH with locator/latch, hydraulic permanent packer on 2-7/8" 8RD EUE L-80 tubing [new]. Locate/space out/latch (not.sealing) into SC-1L packer at 3,811', land tubing hanger, and injection packer at +/-3,784',with XN nipple (w/plug installed) at 1-3,799'. 9. Pressure up on tubing to set injection packer at+/-3,784'. 10. Perform a charted casing pressure test to 1,500psi for 30min. Bleed off pressure. 11. ND BOP, NU and tree. 12. RDMO workover rig and equipment. 13. Turn well over to production. 14. Slickline to pull plug in XN nipple at/-3,799' post rig. _ Attachments: LA): �e ssc.x MIT- f' 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPU H-04 • .14 SCHEMATIC Last Completed: 9/13/2008 ltilrorp Alaska,LLC C PTD: 190-089 CASING DETAIL Orig.RKB AGL:35'/Orig.GL Elev.:37' Size Type Wt/Grade/Conn ID Top Btm 13-3/8", Conductor 54.5/K-55/Weld 12.615 Surface 105' 13-3/8"y ,* ql 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,562' ,i; 7" Production 26/L-80/Btrc 6.276 Surface 4,472' ' 1 lit! TUBING DETAIL 2-7/8" Tubing 12.6/13-CR/yam Top 3.958 Surface 3,689' "i JEWELRY DETAIL No Depth Item Heat Trace to y1 144' 2-7/8"Camco KBMM GLM w/1"Sidepocket 41 2,435' A A 2 3,471' 2-7/8"Camco KBMM GLM w/1"Sidepocket 4 4 3 3,624' 2-7/8"XN Nipple: ID=2.250" r 4 3,644' Discharge Head ' j 5 3,645' Pump:SXD 90-538-P11 9 .J(.� 6 3,658' Gas Separator:GRSFTX AR H6 a.. 7 3,663' Tandem Seal Section:GSB3DB SB/SB PFSA/FSA CL-5 ii V? 8 3,677' Motor:Centrilift KMH 76hp/1,360 V,34 A 9-5/8 9 3,685 Phoenix XTO x/6 fin Centralizer:Bottom @ 3,689' 10 3,811' Packer:7"Baker SC-IL 11 3,845' 2-7/8"Blank Pipe 12 4,076' 2-7/8"Screen:Bakerweld 12 ga. RATagincollar@ 13 4,155' Polished Bore Receptacle:ID= 2.062" 3,326 ,Esl.TOC @ 2W 14 4,156' 2-7/8"Screen:Bakerweld 12 ga. +, 15 4,168' Packer:Baker'D'Sump 16 4,181' XN Nipple:Otis-ID=1.791"No Go 17 4,182' WLEG a A PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status ll e 2 R "N"Sands 4,086' 4,099' 3,976' 3,989' 13 1/10/1991 Open ` "N"Sands 4,111' 4,118' 4,000' 4,007' 7 1/10/1991 Open `t if "N"Sands 4,134' 4,154' 4,022' 4,041' 20 1/10/1991 Open A ,0 "0"Sands 4,208' 4,238' 4,092' 4,120' 30 1/5/1991 Open "0"Sands 4,274' 4,288' 4,154' 4,186' 14 1/5/1991 Open Yw 'N'Sands Perfeed w/24gm.BH 43C;'0'Sands perfed w/37gm.Hyperjet II;(EHD=0,49",TTP=30,25")w/72 Deg.Phasing li 3 4 STIMULATION SUMMARY WELL INCLINATION DETAIL .,. h 'N'Sands Frac Packed w/8,1001bbs of 20/40 Sand KOP @ 1,400' a. t 4 Max Hole Angle=18 to 21 deg.f/2,250'to TD OPEN HOLE/CEMENT DETAIL �i x Hole angle thru perfs=19 deg. h5 13-3/8" 500 sx Permafrost in a 30"Hole DLS=4 deg./100'f/1,650 to 1,850' 9-5/8" 1,014 sx Arctic Set&250sx Class'G'in a 12-1/4"Hole it It .6 7" 211 sx Class'G'in a 8-1/2"Hole W P .7 TREE&WELLHEAD Si Tree 2-9/16"-SM WKM Wellhead 11"5M WKM w/11"x 2-7/8"tbg.Hanger,2.5"'H' "% "�6 BPV profile and 8rd EUE threads top and bottom t 9' GENERAL WELL INFO ++ API:50-029-22712-00-00 .l tB • Drilled and Cased by Nabors 27 -10/18/1990 17 Completed w/Gravel Pack and ESP-1/26/1991 .12 RWO ESP Replacement by Nabors 4ES-9/14/1994 P 1,0'13 RWO ESP Replacement by Nabors 4ES-1/20/1997 15 RWO ESP Replacement by Nabors 4ES-2/1/1998 -...-i � 16 A17 R RWO ESP Replacement by Nabors 4ES-3/9/2001 Remove and Replace Tubing Patfh-2/26/2006&4/8/2006 u Pull Tubin Patches-9/9/2006 7"tL'1►$�` 4 8 RWO ESP Replacement by Nabors 4ES-9/17/2006 TD=4,496(MD)/TD=4,362'(1VD) RWO ESP Replacementby Nabors 3S-9/13/2008 PBTD=4,393'(MD)/PBTD=4,266'(TVD) Revised By:TDF 4/17/2015 Milne Point Unit .11 Well: MPU H-04 PROPOSED Last Completed: 9/13/2008 • Hilcorp Alaska,LLC PTD: 190-089 CASING DETAIL Orig.RKB AGL:35'/Orig.GL Elev.:37 Size Type Wt/Grade/Conn ID Top Btm 13-3/8" Conductor 54.5/K-55/Weld 12.615 Surface 105' 133/8 9-5/8" Surface 36/K-55/Btrc. 8.921 Surface 2,562' 7" Production 26/L-80/Btrc 6.276 Surface 4,472' TUBING DETAIL 2-7/8" Tubing 6.4/1-80/EU 8rd 2.441 Surface ±3,811' JEWELRY DETAIL No Depth Item • 1 ±3,784' Packer 2 ±3,799' XN Nipple b,. 3 3,811' Packer:7"Baker SC-IL • 4 3,845' 2-7/8"Blank Pipe t 5 4,076' 2-7/8"Screen:Bakerweld 12 ga. i 6 4,155' Polished Bore Receptacle:ID= 2.062" ,: 7 4,156' 2-7/8"Screen:Bakerweld 12 ga. A V 8 4,168' Packer:Baker'D'Sump 9-5/8” 9 4,181' XN Nipple:Otis-ID=1.791"No Go 10 4,182' WLEG-Bottom @ 4,183' PERFORATION DETAIL RATag incollar @ Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 3,326' Est.TOC @ 3,200' "N"Sands 4,086' 4,099' 3,976' 3,989' 13 1/10/1991 Open .14 3. "N"Sands 4,111' 4,118' 4,000' 4,007' 7 1/10/1991 Open "N"Sands 4,134' 4,154' 4,022' 4,041' 20 1/10/1991 Open ' ,.. "0"Sands 4,208' 4,238' 4,092' 4,120' 30 1/5/1991 Open "0"Sands 4,274' 4,288' 4,154' 4,186' 14 1/5/1991 Open 'N'Sands Perfeed w/24gm.BH 43C;'0'Sands perfed w/37gm.Hyperjet II;(EHD=0,49",TTP=30,25")w/72 Deg.Phasing ,, WELL INCLINATION DETAIL 4 KOP @ 1,400' I Max Hole Angle=18 to 21 deg.f/2,250'to TD Hole angle thru perfs=19 deg. '6l; DLS=4 deg./100'f/1,650 to 1,850' i,, STIMULATION SUMMARY 'N'Sands Frac Packed w/8,100lbbs of 20/40 Sand • OPEN HOLE/CEMENT DETAIL 13-3/8" 500 sx Permafrost in a 30"Hole • 9-5/8" 1,014 sx Arctic Set&250sx Class'G'in a 12-1/4"Hole • 7" 211 sx Class'G'in a 8-1/2"Hole TREE &WELLHEAD 4. Tree 2-9/16"-5M WKM Wellhead 11"5M WKM w/11"x 2-7/8"tbg.Hanger,2.5"'H' BPV profile and 8rd EUE threads top and bottom a. 1 GENERAL WELL INFO ® X11 3� API:50-029-22712-00-00 3 X NI 3 Drilled and Cased by Nabors 27 -10/18/1990 Completed w/Gravel Pack and ESP-1/26/1991 6 W o i71.• RWO ESP Replacement by Nabors 4ES-9/14/1994 6 i RWO ESP Replacement by Nabors 4ES-1/20/1997 RWO ESP Replacement by Nabors 4ES-2/1/1998 $ RWO ESP Replacement by Nabors 4ES-3/9/2001 ' knI1 9 . 10 Remove and Replace Tubing Patch 2/26/2006&4/8/2006 Pull Tubing Patches-9/9/2006 r''� RWO ESP Replacement by Nabors 4ES-9/17/2006 TD=4,496'(MD)/TD=4,362'(ND) RWO ESP Replacement by Nabors 3S-9/13/2008 PBTD=4,393'(MD)/PBTD=4,266'(TVD) Revised By:TDF 4/17/2015 11" BOP Stack � 0 0r iiia 11111, Hydril 11" 5M , ,iiiaii � ! , \ , Shaffer — MO01 ji .01:11 2 3/8" Rams - 11" 5M 2 7/8-5.5 _ _ _ variables / Hydril C120--( 11" 5M1....._jBlinds i Optional valve port [11111FINFWV; -;-- ----.) Orr - ! 0...flici � � (ii G-14 ' - G' fL1 9-1�-0 -- - -' -16� 1 G-18L1 -:- -- LI - J-07 - :ii- E-28 0104 G-05 1 G-01 G-02 • i-04 11. I-04A ' . IIIN N 11 çALI l •�� 1-02 , , air , \ /- — l I -/4/ , 1,\ . 1 111-03 , I y �� I \ 1_15 A\-- /1-.,: ---1, _ _ _ _I:_-_-_-,---H-4.1_4), 14,1; 4 Ae::- - - - ),, _ - --f - 4-ii,- ,--N--— — ,E =15L -- ' -t- _ _ -....„11..... ' ,.t I, - -I- 14,5111) —t- _ , _11 H , i H-15re* • `-- - 'y--� LH ' � , I 14 HILCORP ALASKA LLC \01 \.,., 1-- H-19 �... 1-01 I MILNE POINT FIELD N \\ , 1 T, AOR MAP �.__`.-� t-._._. ._\_.._._..__'io. ....\_.._....... �+ • MPH 04 I 1 \` I J \�I \;�i. \` 0 1 052 I \ N ` N E��T I l , , S - � POSTED WELL DATA i' 0 11 `\ S-34L' * Well Number ( 11 , i v I II1 S-3 ••-• vai I1611 WELL SYMBOLS I I • Active Oil -O- H-08BLI D&A I I iki INJ Well(Water Flood) I -_.`,. A P&A Oil I 108 ' \----. Abandoned Injector I I \ I S-34 f ,--, RED DOT=Top SEchhrraader<S Blluff OA Sand H-09. -09 Well Symbol at BHL0 Black Long Dash Circle=1320'radius from midpef Perfs along wellpath in green H-07AL1 I • y April 16,2015 it �.Lu I PETRA 4/162015 3'.13.10 PM Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~0- O~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by:~Bren Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: ~si NOTScanned.wpd STATE OF ALASKA A~ OIL AND GAS CONSERVATION CO~SION REPORT OF SUNDRY WELL OPERATIONS /0--9.0 ~ 1. Operations Performed: ^ Abandon ®Repair Well . ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing , ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP - ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development, ^ Exploratory 190-089 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22064-00-00 - 7. KB Elevation (ft): 72 00 9. Well Name and Number: MPH-04 8. Property Designation: 10. Field /Pool(s): ADL 025906 Milne Point Unit / pare "ver Sa s 11. Present well condition summary ~ ~~~ ~~~ i Total depth: measured 4496 ~ feet `~~ true vertical 4362 ~ feet Plugs (measured) N/A t~ Effective depth: measured 4393 feet Junk (measured) N/A true vertical 4266 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 13-3/8" 105' 105' 2730 1130 Surface 2527' 9-5/8" 2562' 2525' 3520 2020 Intermediate Production 4437' 7" 4472' 4340' 7240 5410 Liner c/yj~ Perforation Depth MD (tt): 4086' - 4288' Perforation Depth TVD (tt): 3976' - 4168' 2-7/8", 6.5# L-80 3689' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Screen Assembly: 7" Baker SC-IL packer and a 7" Baker 3811' 'D' sump packer 4168' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 280 0 Subsequent to operation: 30 58 72 120 286 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram -® Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 NIA Printed Name Sondra Stewman Title Drilling Technologist ~'`~~ Prepared By Name/Number ~ ®~-~ Sig ature _ Phone 564-4750 Date 6 Sondra Stewman 564-x750 Form 10-404-'F~vised 04/2006 ~~{ ~(l~ ~,~ 4 C~~ ~' Submit Original Only Tree: 2-9/16" - 5M WK Wellhead:11" 5M WKM w~ 1" x 2 7/8" tbg. hng, 2.5" 'H' BPV profile and 8 rd. threads top and btm. KOP @ 1400' Max. hole angle: 18 to 21 deg. f/ 2250' to TD Hole angle through pees = 19 deg. DLS = 4 deg./100' f/ 1650' to 1850' 9 5/8", 36#/ft, K-55 Btrc. 2562' 2-7/8", 6.5#/ft,13Cr-80 tbg. (cap. = 0.0058 bpf, ID = 2.441") 7", 26 ppf, L-80, Btrc. production casing (cap. = 0.0383 bpf, ID = 6.276') Orig. 72' (Nabors 27E) GL=3 2 7/8" Camco KBMM 144' GLM w/ 1" sidepocket Heat-Trace to 2435' MD Radioactive marker in collar at 3326' and ~ it I 2 7/8" Camco KBMM 3471' GLM w/ 1" sidepocket Stimulation Summary: N Sands Frac Packed w/ 8100 # 20/40 Sand Perforation Summary: Ref. Log: CNL / LDT 10/16/90 Size SPF Interval (TVD) 'N' Sands 4.5" 24 4086' - 4099' (3976' - 3989') 4.5" 24 4111' - 4118' (4000 - 4007') 4.5" 24 4134' - 4154' (4022' - 4041') 'O'sands 4.5" 5 4208' - 4238' (4092' - 4120') 4.5" 5 4274' - 4288' 4154' - 4168' 'N' Sands perfed w/ 24 gm. BH 43C 'O' Sands perfed w/ 37 gm. HyperJet II (EHD = 0.49",TTP = 30.25") w/ 72 deg. phasing DATE REV. BY COMMENTS 10/20/90 01/17/91 JBF JBF D & C by Nabors 27E Gravel Pack and initial ESP Compl. 09/14/94 02/02/98 JBF M. Linder ESP Replacement by Nabors 4ES ESP Re lacement b Nabors 4ES 03/10/01 B. Hasebe ESP Replacement by Nabors 4ES 07/12/05 Lee Hulme Set tubing Patch 09/18/06 R. Handy 4ES ESP RWO/Tbg C/o 9/13/08 REH ESP RWO & Tb c/o b Nabor; 2-718" XN Nipple ID 2.25" 3624' Centrilift SXD 90-538-P11 3644' GRSFTX AR H6 Gas Sep. 3658' Tandem Seal Section ' GS63DB SB/SB PFSA/FSA 3663 CL5 Centrilift 76hp KMN 1360 367T volt/34 amp motor Phoenix XTO 3685' 6 Fin Centralizer 7' Baker SC-IL Pkr. @ 3811' and 2 7/8" blank pipe @ 3845' and 2 7/8" Bakerweld 12 ga. screen @ 4076' PBR (2.062" ID) @ 4155' and 2 7/8" Bakerweld 12 ga.screen @ 4156' 7" Baker 'D' sump pkr. @ 4168' and Otis 'XN' Npl. (1.791" no-go) @ 4181' and WLEG @ 4182' and 7" Float collar 4393' 7" Csg. shoe 4472 MILNE POINT UNIT WELL H-04 API NO: 50-029-22064 BP EXPLORATION (AK) Page 1 ~of 1 Well: MPH-04 Well History Well Date Summary MPH-04 8/16/2008 T/I/0=250/250/280. (Freeze protect for RWO). Freeze protect tbg w/ 15 bbls diesel. Freeze protect production line w/ 2 bbls 60/40 meth, 3 bbls diesel, & 2 bbls 60/40 meth. Freeze protect test line w/ 2 bbls 60/40 meth, 3 bbls diesel, & 2 bbls 60/40 meth. FWHP=0/250/280. MPH-04 8/30/2008 WELL S/I UPON ARRIVAL (pre rwo) DRIFTED TO 1968' SLM W/ 2.31 GAUGE RING P 2" AD-2 HIGH FLOW PACKOFF ASSEMBLY FROM 1968'- 1983' SLM. RIH TO PULL DGLV FROM 3525' MD AT REPORT TI "'CONTINUE ON 8/31/08"* MPH-04 8/31/2008 '"'CONTINUE FROM 8/30/08 "' (pre rwo) PULLED 1" BK-DGLV FROM 3525' MD, LEFT OPEN PULLED 1" BEK-DPSOV FROM 140' MD, SET 1" BK-DGLV PERFORMED SBHPS TURN WELL OVER TO DSO "' JOB COMPLETE "' MPH-04 9/4/2008 The Well Support Techs rigged up and set a back pressure valve, removed the wellhouse, flowlines and the foundation. Blinds were installed as needed. NOTE: Well is ready for RWO. MPH-04 9/7/2008 T/I/0=0/280/300, Temp=Sl. PPPOT-IC (PASS), eval IAxOA com. PPPOT-IC: Stung into test port (0 psi). Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 20 psi in second 15 min (PASS). Bled to 0 psi. Did not function LDS. MPH-04 9/7/2008 3ressure on t~,e IA/OA are equal and appear to be tracking. A packoff test was performed and it passed. QAwas bled from 300 osi to 100 osi in about 15 minutes with all gas returns ~ 15:00 hrs. Pressure rose to 180 psi by 14:30 hrs and then to 200 psi @ 17:30 hrs (2 1/2 hrs total). Pressure was again bled to 100 psi C~3 2100 hrs and increased to 180 psi by 00:30 hrs on 9/8/08. Pressure at 08:00 was 230 psi (11 hrs after bleed). ~,~, MPU Engineers and the 3S WSL are aware of the anomaly and the potential need to conduct a casing pressure test during the RWO about to commence. MPH-04 9/13/2008 (Freeze Protect TBG and IA) T/1= 0/0 Pump 15 bbls dead crude down TBG followed by 65 bbls dead crude down IA to freeze protect well. Awgers continued on 09-14-08. MPH-04 9/14/2008 (Freeze protect TG and IA) T/I/0= 0/0/0 Pump 15 bbls dead crude down TBG followed by 65 bbls dead crude down IA to freeze protect well. FWHP= 0/0/0 (swab-shut /wing-shut /ssv-shut /master-open / IA open to gauge.) (Note : IA has no gauge. Contacted Scott Byars to call Well Tech's ) MPH-04 9/19/2008 MPU W pport Techs Dulled BPV and PT flow-lines prod.and test to 1150 psi for 10.mins Note tree cap was wkm changed out to Camron. MPH-04 9/23/2008 (IA Flush) Load fluids for job. Continue on 09-24-OS WSR. MPH-04 9/24/2008 T/I/0=300/0/260 (IA Flush) Continued from 09-23-08 WSR. Pumped 90 bbls Dead Crude down IA. with well online. FWHP= 300/0/680 IA, and OA open to gauges. MPH-04 9/29/2008 T/I/0=300/200/250 IA Flush -Pumped IA w/90 bbls crude with well on line. IA/OA, wing, master &ssv open. Swab closed. Notify operator. Final WHP's=300/120/700 MPH-04 10/1/2008 T/I/0=300/100/160 IA flush. Pumped 90 bbls dead crude down IA. while well was online. FWHP=300/0/580 Master, Wing, SSV, IA, and OA open. Swab closed. MPH-04 10/2/2008 IA Flush Load Fluids for job. Continued on 10-03-08 WSR. MPH-04 10/3/2008 T/l/0=300/0/180 IA Flush Continued from 10-02-08 WSR. Pumped 90 bbls Dead Crude down IA while well was online. FWHP=300/0/600 Master, Wing, SSV, IA and OA open. Swab closed. Print Date: 10/8/2008 Page 1 of 1 BP EXPLORATION Operations Summary Report Legal Well Name: MPH-04 Common Well Name: MPH-04 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date From - To Hours Task Code: NPT 9/8/2008 01:00 - 03:00 2.00 RIGD P 03:00 - 07:00 4.00 RIGD P 07:00 - 12:00 5.00 RIGD P 12:00 - 13:30 1.50 RIGU P 13:30 - 14:30 1.00 RIGU P 14:30 - 15:30 1.00 RIGU P 15:30 - 16:30 1.00 RIGU P 16:30 - 18:00 1.50 RIGU P 18:00 - 20:30 20:30 - 21:30 21:30 - 23:30 23:30 - 00:00 9/9/2008 00:00 - 06:00 06:00 - 07:00 07:00 - 08:30 08:30 - 09:30 09:30 - 11:30 11:30 - 16:00 16:00 - 17:00 2.501 KILL I P Start: 9/5/2008 Rig Release: 9/13/2008 Rig Number: Page 1 of 3 Spud Date: 10/11 /1990 End: Phase Description of Operations PRE R/D equipment, scope down mast an lower onto carrier. Unhook water, steam, air and electrical lines. PRE Move pipeshed away from carrier. Jack carrier down. Hold PJSM with Peak drivers and move pits and pipeshed. PRE Rig depart MPF pad. PRE MIRU on MPF-04, Spot carrier over well. Jack carrier. PRE Spot and level pipeshed and pits. PRE Berm cellar, cuttings and boiler blowdown tanks. Set walkways, stairs and handrails. PRE Raise mast off of carrier and scope up into position. PRE Hook up water, steam and air lines between modules. Plug in electrical lines. DECOMP Install secondary valve on IA. R/U circulating lines for well kill, R/U hard line to tiger tank. Pressure test circulating lines to 3,500 psi, test hardline to tiger tank to 500 psi. 'Riq accepted at 18:00 hours. 1.00 KILL P DECOMP R/U lubricator and test to 500 psi with diesel. Pull BPV, 200 psi on tubing, 200 psi on IA and 250 psi on OA. Bleed OA pressure to 100 psi. 2.00 KILL P DECOMP Line up and pump 25 bbls of 120 degree 8.7 ppg brine down tubing taking returns out the IA through the choke manifold to the tiger tank at 3 bpm with 360 psi, heave crude returns; Line up and bullhead 20 bbls of 120 degree 8.7 ppg brine down tubing at 1.5 bpm with 860 psi. Pressure bled down to 220 psi in 10 minutes. Line up and pump 170 bbls of 120 degree 8.7 ppg brine down the tubing taking returns out the IA through the choke manifold to the tiger tank at 3 bpm with initial circulating pressure of 350 psi building to 900 psi with thick crude returns and a final circulating pressure of 290 psi. Clean 8.7 ppg brine back to surface. Highest pressure reading on the OA was 320 psi. 0.50 KILL P DECOMP Shut in and monitor well. 40 psi on tubing and 50 psi on IA. Calculate kill wei ht fluid lus 75 si over balance = 9.3 6.00 KILL P DECOMP Monitor well while waiting on kill weight brine and trucks. 1.00 KILL P DECOMP Load pits with 9.3 #/gal brine. Strap all tanks, check rig up, PJSM with crews for well kill. 1.50 KILL P DECOMP Open well to Tbg and IA on vacuum. Circulate 9.3 #/gal brine 4 BPM, 370 psi. Fluid returns after 5 Bbls. Circulate 20 Bbls, close choke and bullhead 20 Bbls into formation C~ 2 BPM / 1000 psi. Shut down. Tbg and IA bleeding down slowly. Open choke and circulate 150 Bbls of 9.3 #/gal brine ~ 4 BPM, 380 psi Tbg, 60 psi IA. Good clean 9.3 # brine in and out. Flowcheck well - Tbg/IA on vacuum. Circulated 164 Bbls total w/ 134 Bbls returned. (19 % losses) 1.00 WHSUR P DECOMP Dry rod TWC. Test to 3500 psi from above. Chart for 5 minutes. Blow down choke and all lines to Tiger Tank. Load pits with 90 Bbls of 9.3 #/gal brine. 2.00 WHSUR P DECOMP Bob Noble with AOGCC, waived State's right to witness BOPE testing. ND Tree. Bleed hanger void, check LDS. Check hanger threads with 8-1/2 turns, 2-7/8" EUE 8 rd. 4.50 WHSUR P DECOMP NU BOPE. 1.00 WHSUR P DECOMP Function test BOPE a ui ment. Test gas sensors and monitors. Grease choke manifold and all valves. Prep floor. Printed: 9/30/2008 11:55:29 AM BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPH-04 Common Well Name: MPH-04 Spud Date: 10/11/1990 Event Name: WORKOVER Start: 9/5/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2008 Rig Name: NABOBS 3S Rig Number: I Code ~i NPT Phase ~, Description of Operations Date From - To ~ Hours Task -- - 9/9/2008 17:00 - 22:00 5.00 WHSUR P DECOMP Pressure test BOPE to 250 / 3500 psi against the TWC with 2-7/8" and 3-1/2" test joints, 2-7/8" X 5" VBR, per BP/AOGCC Regulations. Test witnessed by NAD toolpusher and BP/ WSL. 22:00 - 00:00 2.00 WHSUR P DECOMP PU/MU new Opso Lopso with 2' and 4' pups. PU/MU lubricator and test to 500 psi, Well Support techs pulled TWC. Fill IA every our p . 9/10/2008 00:00 - 01:00 1.00 PULL P DECOMP UD lubricator and New Opso Lopso. 01:00 - 02:30 1.50 PULL P DECOMP Hang double sheave and cable trunk in Derrick. 02:30 - 03:30 1.00 PULL P DECOMP MU landing joint, BOLDS with Cameron wellhead rep, Pull tubing hanger free, POW = 45k. 03:30 - 04:00 0.50 PULL P DECOMP Circulate 30 bbls 9.3 ppg Brine at 3 bpm / 210 psi. Observe well, - 5 bph loss with pumps off. 04:00 - 06:00 2.00 PULL P DECOMP BO / L to ing anger, pull Heat trace and ESP cable over Derrick sheave. 06:00 - 15:00 9.00 PULL P DECOMP POH laying down 2-7/8" tubing and all jewelry. Continuous hole fill w/ charge pump ~ -5 bph losses. Heat trace for 2250'. 15:00 - 18:00 3.00 PULL P DECOMP BO / LD ESP assembly. Recovered 357 = 6 ft Flatguards, 11= 4 ft, 16 = 3 ft, 1 = 1 ft, 28 =LaSalle clamps, 2 = Armguards, 1,178 steel bands. 18:00 - 20:30 2.50 CLEAN P DECOMP Clean and clear rig floor of ESP handling equipment. 20:30 - 00:00 3.50 CLEAN P DECOMP P - "bit 7" cs scra er and PU 3-1/2" DP from pipe shed and RIH to 1,860' MD with continuous hole fill and 5-8 bph loss. 9/11/2008 00:00 - 01:30 1.50 CLEAN P DECOMP Continue PU 3-1/2" DP from pipe shed and RIH w/ 7" csg scraper and tag with 5K WOB at 3,800' MD, PUW = 62K, SOW = 55K. 01:30 - 02:30 1.00 CLEAN P DECOMP Circulate surface to surface with 9.3 ppg brine, 3 bpm / 200 psi, with -5 bph loss, pumps off, observer well on slight Vac. 02:30 - 05:00 2.50 CLEAN P DECOMP Blow down lines, POH from 3,800' MD and stand 3-1/2" DP in Derrick. 05:00 - 06:30 1.50 DHB P DECOMP BO / LD Bit and Csg scraper. PUMU HES 7" RBP._ 06:30 - 10:00 3.50 DHB P DECOMP RIH w/HES 7" RBP on 3-1/2 DP from Derrick. 10:00 - 11:30 1.50 DHB P DECOMP MU TIW valve, set RBP ~ 3785'. PU repeat procedure, confirm set of RBP. Close TIW valve, close annular. Pressure casing to 1500 psi ~ 1-1/2 BPM. Took 7 Bbls to pressure up. OA pressure from 130 psi to 250 psi. Chart for 50 minutes. IA from 1550 psi to 1480 psi, OA from 250 psi to 200 psi. 11:30 - 12:30 1.00 DHB P DECOMP Bleed Csg to 0 psi. RIH and unseat RBP from 3785'. Flowcheck well. 12:30 - 17:00 4.50 DHB P DECOMP POH with 7" RBP, la ing down 3-1/2" DP. Continuous hole fill, losses ~ -5 bph. Maintain trip sheet and pit watcher. Lay down RBP 17:00 - 00:00 7.00 BUNCO RUNCMP Clean and clear rig floor. Prep for running completion. Hang tubing stabbing board in Derrick. RU Chrome tubing handling tools. 9/12/2008 00:00 - 01:30 1.50 BUNCO RUNCMP Continue to RU to run 2-7/8" chrome completion. PU Centrilift equipment to rig floor. 01:30 - 03:30 2.00 BUNCO RUNCMP PU/MU ESP pump and motor with Centrilift rep. 03:30 - 04:30 1.00 BUNCO RUNCMP Run ESP cable over sheave in Derrick. 04:30 - 09:00 4.50 BUNCO RUNCMP Run 2-7/8" 13cr-80, 6.5# Vam To , ESP com letion. Utilize weight compensator and torque turn services. Run with XN nipple, one GLM ("E" DGLV-BK latch) and 36 joints of tubing. Continuous hole fill, losses ~ -5 bph. Maintain trip sheet and Printed: 9130/2008 11:55:29 AM c: BP EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPH-04 Gommon Well Name: MPH-04 Spud Date: 10/11/1990 Event Name: WORKOVER Start: 9/5/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2008 Rig Name: NABOBS 3S Rig Number: Date 'From - To Hours Task Code NPT Phase Description of Operations __ 9/12/2008 04:30 - 09:00 4.50 BUNCO RUNCMP pit watcher. 09:00 - 12:00 3.00 BUNCO RUNCMP Start heat trace mid joint # 37 (as RIH). Continue run 2-78" 13Cr-80, 6.5# Vam Top completion. Losses @ -5 bph. 12:00 - 12:30 0.50 BUNCO RUNCMP 44 joints in hole. Crew change. Shut down operations to review recent incidents on other Rigs, focus on well conditions and current operations. Discuss "busy derrick", overhead hazards, pinch points, and well control. 12:30 - 00:00 11.50 BUNCO RUNCMP Continue RIH w/ 2-7/8" chrome tubing with heat trace, ESP. Centrilift rep make ESP /Heat trace conductivity test at -2,000 ' and flush pump with 10 bbls seawater at 1/2 bpm / 1,000 psi. Losses ~ -5 bph. 9/13/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Ran GLM (DPSOV-BEK latch) Centrilift rep make ESP /Heat trace conductivity test. 01:00 - 01:30 0.50 BUNCO RUNCMP Flush pump with 10 bbls seawater at 1/2 bpm / 900 psi. 01:30 - 02:30 1.00 BUNCO RUNCMP PU / MU tubing hanger and landing joint. 02:30 - 03:00 0.50 BUNCO RUNCMP Cut ESP /Heat trace cables and snake over Derrick sheaves. 03:00 - 05:00 2.00 BUNCO RUNCMP Centrilift rep make ESP /Heat trace Hanger splices and install shipping caps. Take final conductivity checks. 05:00 - 06:00 1.00 BUNCO RUNCMP Land tubing hanger and RILDS, LD landing joint. PUW = 44K, SOW = 42 an - ro ec o izer, 3- Armister guards, 24- Cannon clamps, 48- Nails, 372 (6ft) and 10 (oft) and 23 (aft) Flat guards, 1,222 Bands. 06:00 - 06:30 0.50 WHSUR P RUNCMP D rod TWC. Test to 3500 si from above and chart. 06:30 - 08:30 2.00 WHSUR P RUNCMP Clear floor of torque turn and other equipment for running completion. Remove stabbing board from Derrick. 08:30 - 12:30 4.00 WHSUR P RUNCMP ND BOPE 12:30 - 16:00 3.50 WHSUR P RUNCMP NU 13-5/8" x 2-7/8" tubing head adaptor. WKM 5K tree. Test hanger void to 2,000 psi for 20 minutes. Centrilift do final checks on ESP-Heat Trace cable. Final checks: ESP -intake psi - 1652 psi /motor temp - 85 deg F / 2.0 ohms phase to phase / 3 gig phase to ground. Heat Trace- 2.8 ohms phase to phase / 50 gig phase to ground. 16:00 - 17:00 1.00 WHSUR P RUNCMP Test tree to 5,000 psi with diesel._ PU/MU lubricator, pull TWC. Run BPV, Normal up tree and cellar. Release Rlg C~ 17:00 hours 9/13/2008 Printed: 9/30/2008 11:55:29 AM STATE t)F ALASKA 11114!07 pIL AND GAS CONSERVATIC)N COMMISSION BOFE Test Report Submit ~: Contractor: Nabors Rig No.: 3S DATE: 9/9/2008 Rig Rep.: J. Greco ! R. Bjofius ~ Phone: 659-4487 ~ Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: J. Menke ! D. Rues Field/Unit & Well No.: MP H-04 PTL3 # '~ Operation: Drtg: Wosko~ver: x Test: InitiaL• x Weekly: Test Pressure: Rams: 25013500 Annear: 25013504 .TEST DATA MISC. INSPECTK}NS: Test Result Test Result Location Gen.: P WeN Sign P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5J8 5000 P Pipe Rams 1 2 7J8 X 5 P Lower Pipe Rams 0 NA Blind Rams t B~rtd P Choke Ln. Valves 1 31/8" 5000 P HCR Valves 2 3 1B" 5tMt0 P Kill Line Valves 1 21116" 5{Yt?0 P Check Valve 0 NA MUD SYSTEM: V~ual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 0 NA Lower Keay 0 NA Ball Type 1 P lrrsuie BOP 1 P Bi-Weekly Valves: 250/3500 CHOKE MANIFOLD: Quantity Test Result No. Valves 13 FP Matwat Chokes 1 P Hydraukc Chokes 1 P ACCtJMtJLATOR SYSTEM: TimeJPressure Test Result System Pressure 3100 P Prue A#er Ck~tre 1850 P 200 psi Attained 30see P Fug Pressure Attained 150sec P Blind Switc#t Covers: All stations P Nitgn. Bottles (avg}: 1875 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 1 Test Time:.. ~ Hours Components tested ALL Repair or replacemerrt of ege~ment w~ be made within days. Notify the North Slope Inspector 659-3607, foAow wrii#r written conf~matic~n th S~erviser at: Remarks: Tested with 2 7J8" and 3112" tes# ioint test against Two Way Check valve (TWC ). Choke valve #12 leaked, greased and retest good.. 24 HOUR NOTICE GIVEN YES X MO BOP Test (for rigs) BFL 11/14/07 Date 09!08/08 Time Test start 17:00 F w SEP ~. 0 2'DO$ 8:00 By Bob Noble Witness R.Bjorhus/D.Rhodes Nabors 3s BOP Test MP H-04 9-9-2008 Revised.xls .. STATE OF ALASKA . RECEIVED R~~ORTo~~N~~~sDc~~s:~~T~O~~~~;;~NN¡ .OCT 1 2 Z(JUb aska a,l & Gas Cons, C nc orage o Re-Enter Suspended Well 181 Other Change Out ESP 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 025906 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 99519-6612 o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: 181 Development 0 Exploratory 190-089 o Stratigraphic 0 Service 6. API Number: 50-029-22064-00-00 181 Repair Well 181 Pull Tubing o Operation Shutdown 12. Stimulation or cement squeeze summary: Intervals treated (measured): 72.00 4496 4362 4393 4266 Length 70' 2627' 4437' 9. Well Name and Number: MPH-04 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 13-3/8" 105' 105' 2730 1130 9-518" 2562' 2525' 3520 2020 7" 4472' 4340' 7240 5410 ~); C . ^~hÍiÇ~) (' S~.ì ': ';<I~'- '-;i" 4086' - 4288' 3976' - 4168' Printed Name Sondra Stewman I"-~':::l Sign re' ·~7'\y·\ Form 10-404 Revised 04/2006 ORfG/~.f¡J 2-7/8",6.5# L-80 3720' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Screen Assembly: 7" Baker SC-IL packer and a 7" Baker '0' sump packer 3811' 4168' Treatment description including volumes used and final pressure: Re resentative Dail Avera e Production or In'ection Data Gas-Met Water-Bbl Casin Pressure 4 111 300 4 117 280 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 13. Tubin Pressure 316 o Oil-Bbl Prior to well operation: 74 Subsequent to operation: 73 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations Title Technical Assistant Phone Prepared By Name/Number: [1- 0 C ?Sondra Stewman, 564-4750 Submit Original Only Tree: 2-9/16" - 5M WKM Wellhead:11" 5M WKM wI 7/8" tbg. hng, 2.5" 'H' BPV profile and 8 rd. threads top and btm. KOP @ 1400' Max. hole angle: 18 to 21 deg. fl 2250' to TO Hole angle through perfs = 19 deg. OLS = 4 deg./100' f/1650' to 1850' 9 5/8", 36#/ft, K-55 Btrc. I 2562' 2-7/8", 6.5#/ft, 8rd EUE,L-80 tbg. (cap. = 0.0058 bpf, 10 = 2.441") 7", 26 ppf, L-80, Btrc. production casing (cap. = 0.0383 bpf, 10 = 6.276') Stimulation Summary: N Sands Frac Packed wI 8100 # 20/40 Sand 'perforation Summary: Ref. Log: CNL I LOT 10/16/90 Size SPF Interval (TVO) 'N' Sands 4.5" 24 4086' - 4099' (3976' - 3989') 4.5" 24 4111' - 4118' (4000 - 4007') 4.5" 24 4134' - 4154' (4022' - 4041') '0' sands 4.5" 5 4208' - 4238' 4.5' 5 4274' - 4288' 'N' Sands perted w/ 24 gm. BH 43C '0' Sands perted w/37 gm. HyperJet II (EHD = 0.49",TTP = 30.25") w/72 deg. phasing DATE 10/20/90 01/17/91 09/14/94 02/02198 03/10/01 07/12/05 09/18/06 REV. BY JBF JBF JBF M. Under B. Hasebe Lee Hulme R. Handy COMMENTS D & C by Nabors 27E Gravel Pack and initial ESP CampI. ESP Replacement by Nabors 4ES ESP Replacement by Nabors 4ES ESP Replacement by Nabors 4ES Set tubing Patch 4ES ESP RWOlTbg Clo Orig. GL = 3 72' (Nabors 27E) 27/8" Camco KBMM GLM w/ 1" sidepocket 140' Heat-Trace to 2250' MO Radioactive marker in collar at 3326' md 27/8" Camco KBMM GLM w/1" sidepocket 3525' 2-718" XN Nipple 10 2.25" 3667' Centrilift SX01:1 538/86P11 3681' GPINTXAR Intake 3691' Tandem Seal Section 3692' I GSB3 DB AB/HSNPFSAI Centrilift 76hp KMH 1360 3706' I volt/34 amp motor Pumpmate XTO 3718' I 6 Fin Centralizer 7' Baker SC-IL Pkr. @ 3811' md 2 7/8" blank pipe @ 3845' md 27/8" Bakerweld 12 ga. screen @ 4076' PBR (2.062" 10) @ 4155' md 27/8" Bakerweld 12 ga.screen @ 4156' 7" Baker '0' sump pkr. @ 4168' md Otis 'XN' Npl. (1.791" no-go) @ 4181' md WLEG @ 4182' md 7" Float collar 7" Csg.shoe 4393' 4472' MILNE POINT UNIT WELL H-04 API NO: 50-029·22064 BP EXPLORATION (AK) . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-04 MPH-04 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 9/14/2006 9/17/2006 Spud Date: 10/11/1990 End: 9/17/2006 9/13/2006 21 :00 - 23:00 2.00 RIGD P PRE Begin RD of sub, pits and Rig components. Lower and scope Derrick. Prepare for rig move from MPH-10. 23:00 - 00:00 1.00 MOB P PRE Move Rig components to MPH-04. 9/14/2006 00:00 - 03:30 3.50 RIGU P PRE Begin spotting Rig components over well slot MPH-04. Spot the Camp, Sub, Pits and Tiger Tank. Raise and scope Derrick. Connect lines to Tiger Tank. Accept Rig at 03:00 hrs on 9/14/2006. Begin taking on hot 2% KCL into Pits. 03:30 - 04:00 0.50 WHSUR P DECOMP PU Lubricator with Well Support Techs and pull BPV. Lay down Lubricator. Initial well pressures as follows: Tbg pressure = 260 psi, IA pressure = 320 psi. 04:00 - 05:00 1.00 KILL P DECOMP PJSM. Continue taking on 120 degree, 2% KCL to the Pits in preparation for well kill. 05:00 - 07:00 2.00 KILL P DECOMP Bleed gas off of well. Tubing pressure = 50 psi, IA pressure = 50 psi. Begin well kill taking returns up the IA to the Tiger Tank. Break circulation at 4 bpm I 50 psi with no pressure on the IA and no returns on surface. Increase pump rate to 5 bpm. Caught fluid with 40 bbls away and tubing pressure increased to 300 psi with IA at zero. Close choke with 50 bbls away and bullhead 25 bbls. Open choke and getting fluid returns on surface (thick crude). Continue circulating at 5 bpm 1600 psi with 200 psi on the IA. Pumped 450 bbls total, saw KCL returns wI 350 bbls pumped. 07:00 - 07:30 0.50 KILL P DECOMP PJSM. Monitor well. Well dead, slight vacuum on both sides. 07:30 - 08:30 1.00 WHSUR P DECOMP PJSM. Set two way check & test from bottom, pumping away @ 4 bpm, 120 psi for (2) minutes, charted & tested from the top @ 1500 psi, 5 minutes charted, OK. 08:30 - 10:00 1.50 WHSUR P DECOMP PJSM. Bleed void & N/D tree. 10:00 - 12:30 2.50 BOPSU P DECOMP PJSM. N/U 135/8" x 5M BOPE. 12:30 - 13:00 0.50 BOPSU P DECOMP PJSM. Rig up to test BOPE. 13:00 - 17:00 4.00 BOPSU P DECOMP PJSM. Conduct full test on BOPE. No failures. Tested @ 250 I 3500 psi. Performed drawdown test on accumulator. Set parameters on pit volume indicator alarms @ 2bbl gain, 2 bbl loss & 2% flow rate increase. AOGCC State Rep Chuck Sheve waived witnessing BOPE test, 24 hour notice given. 17:00 - 17:30 0.50 WHSUR P DECOMP PU Lubricator and pull TWC with Well Support Tech. Montior well dead - OK, still on slight vac. 17:30 - 18:30 1.00 PULL P DECOMP PU Landing Joint and MU to Hanger. Hanger threads are 2 7/8" EUE 8rd. Took 9 1/2 turns to MU to Hanger. BOLDS with Cameron representative (WKM wellhead). Pull Hanger to unseat, it came free at 49K. Pull the Hanger to the Rig Floor with an up weight of 43K. Break down and lay down Hanger. 18:30 - 00:00 5.50 PULL P DECOMP PJSM. POH with existing 2 7/8" EUE 8rd ESP Completion with Heat Trace. At 23:00 hrs, all Heat Trace cable out of the well. Continue POH with ESP Completion. 9/15/2006 00:00 - 01 :00 1.00 PULL P DECOMP Continue POH with existing ESP Completion with Heat Trace. Laying down all joints of tubing. Visually inspected all joints of tubing and found no holes. Recovered a total of (2) GLMs and 113 Joints of 2 7/8" Tubing. 01 :00 - 04:30 3.50 PULL P DECOMP On surface with ESP Assembly. Begin breaking down with Centrilift representatives. Found a small piece of rubber on top of the shaft in the pump section - maybe from patch? Cut ESP Cable and pull over Sheave to Spooling Unit. Put ESP components into boxes. Printed: 9/18/2006 11 :07:04 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-04 MPH-04 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/1 4/2006 Rig Release: 9/17/2006 Rig Number: Spud Date: 10/11/1990 End: 9/17/2006 Clear and clean Rig Floor. RD Elephant Trunk Hose. Perform final tests on ESP cable prior to bagging it. Burnt out in multiple places. Change out spools in Spooling Unit. Prepare to run new ESP completion. 06:00 - 06:30 RUNCMP Rig up to RIH w/2 7/8" tbg. 06:30 - 09:30 RUNCMP PJSM. RIH w/2 7/8" EUE 8 rnd tbg, 115 jts. 09:30 - 12:30 RUNCMP PJSM. POOH & stand back 2 7/8" tbg. Well is on a mild vacuum. 12:30 - 13:30 1.00 RUNCMP PJSM. Rig up floor to run ESP completion. 13:30 - 15:30 2.00 RUNCMP PJSM. Load pipe shed wI ESP equipment, bring bands & clamps & tools to floor. 15:30 - 17:30 2.00 RUNCMP PJSM. Pick up & service ESP pump & motor assembly. Pull MLE over sheave. 17:30 - 00:00 6.50 RUNCMP Pre·tour safety meeting with night crew. RIH with new 27/8" ESP Completion. Stopping every 1 ,000 ft to test the cables and pump through the Tubing. Pump at a rate of 0.75 bpm 1600 psi. At 20:00 hrs, begin running Heat Trace at a depth of 2,250' to surface. Continue RIH with ESP and Heat Trace. 9/16/2006 00:00 - 08:00 RUNCMP Continue RIH with 2 7/8" ESP Completion and Heat Trace. Pump through at a rate of 1 bpm 11,360 psi. 08:00 - 08:30 RUNCMP PJSM. P/U landing joint, MIU hanger. Install penetrator. Up wt 41 K, Oown wt 39K. Used (28) La Salle Clamps, (359) 6' flat guards, (15) 4' flat guards, (6) 3' flat guards, & (1135) flat bands. 08:30 - 13:00 4.50 RUNCMP PJSM. Attach field connector for ESP & heat trace & test same, OK. 14:00 - 14:30 RUNCMP PJSM. Land hanger, RILDs. 14:30 - 15:30 RUNCMP PJSM. Set two way check, test from bottom by bull heading @ 4 bpm 1120 psi. Test fropm top @ 1500 psi, 5 minutes, both tests charted. 15:30 - 18:00 RUNCMP PJSM. N/D BOPE. 18:00 - 23:00 RUNCMP Pre-tour safety meeting. NU new Adapter Flange and Tree with Cameron representatives. Once we got the Adapter Flange bolted to the Wellhead, noticed that some of the studs were too short due to a wider Adapter Flange. Call out for longer studs and replaced. 23:00 - 00:00 RUNCMP Pressure test the Hanger void to 5,000 psi for 30 mins with Cameron rep - good. Pressure test the Tree to 5,000 psi - good. 9/17/2006 00:00 - 01 :00 RUNCMP Perform final checks on ESP and Heat Trace cables. Final parameters as follows: On the ESP Cable: phase to phase = 2.2 ohms, phase to ground = 1.4 Gigaohms. On the Heat Trace: phase to phase = 2.8 ohms, phase to ground = 30 Gigaohms. The pressure at the intake = 1,160 psi, the temperature at the intake = 82 degrees. The temperature at the motor = 81 degrees. 01 :00 - 02:00 1.00 WHSUR P RUNCMP PU Lubricator and pull TWC with Well Support Techs. Well is still on a vacuum. Set BPV and attempt to test from below by pumping at a rate of 1 bpm I 20 psi with 8 bbls of 2% KCL- charted. Secure well and cellar. Released rig @ 02:00 hrs on 9/17/2006. Printed: 9/18/2006 11 :07:04 AM . Y2Jþ? RECEIVED STATE OF ALASKA I ALASKA Oil AND GAS CONSERVATION COMM SION SEP 2 2 2006 REPORT OF SUNDRY WELL OPERA tWcNi& Gas Cons. Commission 1. Operations Performed: Abandon 0 Alter CasingD Change Approved ProgramD Repair WellŒ Pull TubingD Operation ShutdownD Pluç¡ PerforationsD Perforate New PoolO Perforate 0 Stimulate 0 WaiverD Ancnorage OtherD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 1 go..o890 6. API Number 50-029-22064-00-00 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development 00 ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicO ServiceD 9. Well Name and Number: MPH-04 10. Field/Pool(s): Milne Point / Schrader Bluff Oil Pool 72.00 8. Property Designation: ADL-025906 11. Present Well Condition Summary: Total Depth measured 4496 feet true vertical 4362.4 feet Effective Depth measured 4393 feet true vertical 4266.0 feet Plugs (measured) Junk (measured) None None Casing CONDUCTOR SURFACE PRODUCTION Length 70 2527 4437 Size 13-3/8" 54.5# K-55 9-5/8" 36# K-55 7" 26# L-80 MD 35 - 105 35 - 2562 35 - 4472 TVD 35.0 - 105.0 35.0 - 2525.0 35.0 - 4340.0 Burst Collapse 1130 2020 5410 2730 3520 7240 Perforation depth: ~CANNEf) SEP 2 tZ ZGDt) Measured depth: 4086-4099,4111-4118,4134-4154,4208-4238,4274.4288 True vertical depth: 3976-3989,4000-4007,4022-4041,4092-4121,4154-4168 Tubinç¡ ( size, ç¡rade, and measured depth): 2-7/8" 6.5# L-80 @ 20 - 3681 Bottom of Centrilift Pump @ 3718 Packers & SSSV (type & measured depth): 7" Baker SC-IL Packer @ 3811 7" Baker D Sump Packer @ 4168 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: iRBDMS 8Ft SEP 2 6 2006 13 Prior to well operation: Subsequent to operation: Oil-Bbl SI 175 Representative Dailv Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure o 0 --- V 0 - Tubino Pressure 256 271 14. Attachments: ~ 15. Well Class after proposed work: ExploratoryO 16. Well Status after proposed work: OilŒ] GasD Development!!! ServiceD Copies of Logs and Surveys run _ Daily Report of Well Operations _ WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 I Sundry Number or N/A if C.O. Exempt: I N/A 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 ~Pla. '-'_./ £ ~ V Title Petroleum Engineer ~ ! Phone 564-5174 Date 9/20/06 Form 10-404 Revised 4/2004 U r \ Vi" r\ L- . . M PH-04 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/17/2006 T/I/0=0/0/300 ( Freeze Protect TBG & IA ) POST RWO Pump 20 bbls crude down TBG then pump 70 bbls crude down IA To Freeze protect well Post RWO. FWHP's=550/550/300 09/16/2006 Travel to Kup. Load diesel & transport back to Milne Point. Offload diesel into gray diesel 09/14/2006 PULL 1" DUMMY VALVES FROM BOTH GLM'S, SET 1" DPSOV (FLAGGED AND MARKED), SET 1" DUMMY VALVE (MARKED) ON SURFACE FOR RWO, CO-REP NOTIFIED. 09/11/2006 Demobe for RWO: Well Supports Tech pulled production lines, well house and foundation. Ready for RIG *** BPV was set on 09-09-06*** 09/11/2006 MPH-04 Centrilift took SBHP reading for RWO prior to rig move. 6.9K OHMS phase to ground on PHD calculates to 1117 psi. 09/09/2006 ***WELL S/I ON ARRIVAL *** RIH W/2.5 GR PULL AA-SLlP STOP @ 2571' SLM, PULL AD- 2 UPPER PACK -OFF @ 2572' SLM, PULL AD-2 LOWER PACK-OFF @ 2583' SLM RAN 2.3 CENT 2.5 JU TO PULL A-2 SLIP STOP @ 2585' SLM. PULL DV @ 3552 SLM AND DPSOV @ 118' SLM SET DV @ 118' SLM. SET BPV. NOTE LEFT BTM POCKET @ 3552' SLM EMPTY. ***LEFT WELL SI *** 09/09/2006 T/I/O=260/260/260 Freeze protect tbg , Pump 20 bbls crude down tbg. Pumped 3 bbls meoh and 1.5 bbls diesel down each flowline. FWHP's=260/260/260 09/02/2006 T/I/O= 250/280/310 Bleed OA. Bled OA for 310 psi to 145 psi in 1 hr. (all gas). Monitor OA pressure for 15 mins. OA pressure increased 20 psi. Final WHP's = 250/280/165 08/27/2006 T/IA/OA=200/320/320 PPPOT-IC PASSED Test IC hanger void to 3500 for 30 minutes Has old style test fitting's need short stinger tool. Gland nuts on tubing spool are bottomed out, will need new packing RWO 08/19/2006 T/I/O=299/360/340. Temp=77*. (UIC Report). Bled OA from 340 psi to 240 psi in 20 minutes, All gas. FWHP's=299/360/240. 07/08/2006 *** WELL S/I ON ARRIVAL *** PULL & RESET TUBING PATCH PULL AA TUBING STOP FROM 2569' SLM. PULL AD-2 UPPER PACKOFF & SPACER PIPE. PULL AD-2 LOWER PACKOFF. INSPECT AND REDRESS TBG PATCH. RESET PATCH, PAD OP TO POP WELL. *** WELL S/I ON DEPARTURE. *** 06/21/2006 T/I/O=350/300/320. (ESP trouble). Pump 40 bbls diesel down IA @ 1 bpm for flush. FWHP=300/150/300. Page 1 . . MPH-04 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS BBLS 1 Diesel --- PT Surface Equipment 6 Methanol 71 Diesel 110 Crude 188 TOTAL FLUIDS PUMPED Page 2 Tree: 2-9/16" - 5M WKM Wellhead:11" 5M WKM w/11" x 2 7/8" tbg. hng, 2.5" 'H' BPV profile and 8 rd. threads top and btm. KOP @ 1400' Max. hole angle: 18 to 21 deg. fl 2250' to TO Hole angle through perfs = 19 deg. OLS = 4 degJ100' f/1650' to 1850' 95/8", 36#/ft, K-55 Btrc. I 2562' 2-7/8", 6.5#Ift, 8rd EUE,L-80 tbg. (cap. = 0.0058 bpf, 10 = 2.441") 7", 26 ppf, L-80, Btrc. production casing (cap. = 0.0383 bpf, 10 = 6.276') Stimulation Summary: N Sands Frac Packed wI 8100 # 20/40 Sand Perforation Summary: -Ref. Log: CNL 1 LOT 10/16/90 Size SPF Interval 'N' Sands 4.5" 24 4086' - 4099' 4.5" 24 4111' - 4118' 4.5" 24 4134'-4154' '0' sands 4.5" 5 4208' - 4238' 4.5' 5 4274' - 4288' (TVO) (3976' - 3989') (4000 - 4007') (4022' - 4041') 'N' Sands perted wi 24 gm. BH 43C '0' Sands perted wi 37 gm. HyperJet II (EHD = 0.49",TTP = 30.25") wi 72 deg. phasing DATE 10/20/90 01/17/91 09/14/94 02102198 03/10101 07/12/05 09/18/06 REV. BY JBF JBF JBF M. Linder B. Hasebe Lee Hulme R. Handy Orig. R GL = 37' 2' (Nabors 27E) 2 718" Camco KBMM GLM wI 1" sidepocket 140' Heat-Trace to 2250' MO Radioactive marker in collar at 3326' md 27/8" Camco KBMM GLM w/1" sidepocket 3525' 2-7/8" XN Nipple 102.25" 3667' Centrilift SX01:1 538/86P11 3681' GPINTXAR Intake 3691' Tandem Seal Section 3692' GSB3 DB AB/HSNPFSAI Centrilift 76hp KMH 1360 3706' volt/34 amp motor Pumpmate XTO 3718' 6 Fin Centralizer 7' Baker SC-IL Pkr. @ 3811' md 27/8" blank pipe @ 3845' md 7/8" Bakerweld 12 ga. screen @ 4076' BR (2.062" 10) @ 4155' md 27/8" Bakerweld 12 ga.screen @ 4156' 7" Baker '0' sump pkr. @ 4168' md Otis 'XN' Npl. (1.791" no-go) @ 4181' md WLEG @ 4182' md 7" Float collar 7" Csg. shoe 4393' 4472' COMMENTS D & C by Nabors 27E Gravel Pack and initial ESP CampI. ESP Replacement by Nabors 4ES ESP Replacement by Nabors 4ES ESP Replacement by Nabors 4ES Set tubing Patch 4ES ESP RWOITbg Clo MILNE POINT UNIT WELL H-04 API NO: 50-029-22064 BP EXPLORATION (AK) . STATE OF ALASKA Jè 4/2&/0(" REC AL.A1 ,. OIL AND GAS CONSERVATION COM_ioN APQ2 0 ') REPORT OF SUNDRY WELL OPERATIONS ' , !, ¿ D D D .' 1. Operations Abandon D Repair Well [] Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 72 KB 8. Property Designation: ADL-025906 ' 11. Present Well Condition Summary: Total Depth measured 4496 true vertical 4362.36 Effective Depth measured 4393 true vertical 4266.01 Casing Conductor Surface Production Liner Size 13-3/8" 54.5# K-55 9-5/8" 36# K-55 7" 26# L-80 2-7/8" 6.5# L-80 Length 70 2527 4437 371 Perforation depth: Measured depth: 4086 - 4099 True Vertical depth: 3976.38 - 3988.77 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 114 89 x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development R¡ Stratigraphic r feet feet feet feet MD 35 - 105 35 - 2562 35 - 4472 3811 - 4182 4111-4118 4000.19 - 4006.85 Stimulate D J.9IDmilll &. Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 190-0890 6. API Number: 50-029-22064-00-00 . 9. Well Name and Number: Exploratory Service o{rarn'¿ MPH-04 . 10. Field/Pool(s): Milne Point Field/ Schrader Bluff Oil Pool Plugs (measured) Junk (measured) TVD 35 - 105 35 - 2524.97 35 - 4339.91 3713.24 - 4067.61 4134 - 4154 4022.06 - 4041.06 2-7/8" 6.5# L-80 2-7/8" D&D AD-2 Tubing Patch 7" Baker SC-IL Packer 7" Baker 0 Sump Packer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signat~ Form 10-404 Revised 04/2004 None None Burst 2730 3520 7240 10570 Collapse 1130 2020 5410 11160 4208 - 4238 4092.22 - 4120.55 4274 - 4288 4154.46 - 4167.62 20 - 3713 2583 - 2597 3811 4168 RBDMS 8Ft APR 2 8 2006 Tubing pressure 286 291 Service Title Data Mgmt Engr Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 31 323 300 13 107 300 15. Well Class after proposed work: Exploratory Development R 16. Well Status after proposed work: Oil R Gas r WAG Phone 564-4424 AL WDSPL Sundry Number or N/A if C.O. Exempt: N/A Date 4/12/2006 /.t. ""b,. \ Submit Original Only ~ c¡.¿.' .0," :#Æ Y;45;ا , . . MPH-04 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE ISm¡MM~f{~.,¡1 2/26/2006 ***WELL FLOWING ON ARRIV.*** . Pad OP. Shut in well LRS pumped 20 bbls of hot desiel Pulled AD-2 packoff, Elements gassed up and breaking up Reset new AD-2 packoff *** JOB COMPLETE, RDMO*** 2/26/2006 Assist Slickline. Pumped 20 bbls diesel down tbg. 2/26/2006 ***WELL FLOWING ON ARRIV.*** Pad OP. Shut in well LRS pumped 20 bbls of hot desiel Pulled Patch Set new at same depths 4/8/2006 T/I/O=250/280/300 (Flush tubing for slickline) Pump 25 bbls 100* diesel down tubing. FWHP's=350/300/300 4/8/2006 ***WELL S/ ON ARRIVAL*** PULL TBG PATCH AND RUN CALIPER PULLED PATCH. TAG ESP @ 3646' SLM. CLEAR IMPRESSION OF PUMP SHAFT. RUN PDS CALIPER FROM TOP OF ESP TO SURFACE. SET PATCH @ SAME DEPTH. *** WELL LEFT SI *** FLUIDS PUMPED BBLS 45 I Diesel TOTAL 45 A-~,L STATE OF ALASKA ~ ALASK AND GAS CONSERVATION COMIV,... .JlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 72' [] 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 2369' SNL, 4070' WEL, Sec. 34, T13N, R10E, UM MPH-04 At top of productive interval R E C E1V E ~) 9. Permit190.089Number/ Approval No. 1701' SNL, 3759' WEL, Sec. 34, T13N, R10E, UM 10. APl Number At effective depth 50-029-22064-00 1595'SNL, 3727'WEL, Sec. 34, T13N, R10E, UM APR ~- 2 Z00i 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 1568' SNL, 3720' WEL, Sec. 34, T13N, R10E, UM Alaska 0il & Gas Cons. C0mrnissior~ 12. Present well condition summary Total depth: measured 4472 feet Plugs (measured) true vertical 4345 feet Effective depth: measured 4393 feet Junk (measured) true vertical 4265 feet Casing Length Size Cemented MD TVD Structural Conductor 70' 13-3/8" 500 sx PF 'C' 105' 105' Surface 2527' 9-5/8" 1014 sx AS / 250 sx 2562' 2525' Intermediate Production , 4437' 7" 211 sx Class 'G' 4472' 4340' Liner PeRoration depth: measured 4086' - 4099', 4111' - 4118', 4134' - 4154', 4208' - 4238', 4274' - 4288' true vertical 3976' - 3989', 4000' - 4007', 4022' - 4041', 4092' - 4120', 4154' - 4168' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 3713' Packers and SSSV (type and measured depth) Screen Assembly: 7" Baker SC-IL packer at 3811' and 7" Baker 'D' sump packer at 4168' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior 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 for.egoing is true and correct to the best of my knowledge Signed TerrieHubble ~ ~ Title TechnicalAssistant Date Prepared By Name/Number: Terrie HuDDle, 564-4628 Form 10-404 Rev. 06/15/88 ORIGINAl_ Submit In Duplicat~ Legal Well Name: MPH-04 Common Well Name: MPH-04 Spud Date: 10/11/1990 Event Name: REENTER+COMPLETE Start: 3/7/2001 End: 3/9/2001 Contractor Name: NABORS Rig Release: 3/9/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES 31712001 06:00 - 08:00 2.00 MOB PRE Scope and lower derrick 08:00 - 10:00 2.00 MOB PRE Move rig from MPH-14 to MPH -04, Spot and berm sub and modules 10:00 - 12:00 2.00 RIGU PRE Raise and scope derrick, rig up Rig accepted at 12:00 Hrs 12:00 - 13:00 1.00 WHSUR DECOMP picked up lubricator and pulled BPV, laid down lubricator 13:00 - 16:00 3.00 KILL DECOMP hook up to kill well, spot and berm tiger tank, take on sea water purge and test lines to 3000 psi 16:00 - 18:30 2.50 KILL DECOMP PJSM w/co rep and perform well kill 18:30 - 19:00 0.50 WHSUR DECOMP Set TWC and Test to 3,500 psi 19:00 - 19:30 0.50 WHSUR DECOMP Nipple down tree 19:30 - 22:00 2.50 WHSUR DECOMP Nipple up BOP equipment 22:00 - 00:00 2.00 WHSUR DECOMP Test BOP to 250 psi / 3500 psi. BOP test witness waived by Chuck Sheve w/AOGCC 3/8/2001 00:00 - 01:00 1.00 BOPSUF DECOMP TEST BOP'S TO 250 LOW & 3500 HIGH. (TEST WAIVED BY CHUCK SHEVE) 01:00 - 02:00 1.00 PULL DECOMP INSTALL LUBRICATOR & PULL TWC & BOLDS IN WELL HEAD 02:00 - 03:00 1.00~ PULL DECOMP PULL HANGER TO FLOOR 03:00 - 10:30 7.50 PULL DECOMP PULL ESP COMPLETION & LAY DOWN SAME. 10:30 - 00:00 13.50 RUNCOI~! COMP CLEAN FLOOR & MAKE UP ESP EQUIPMENT & CHECK OUT SAME & RIH WITH SAME INSTALLING HEAT TRACE @ 2265' TO SURFACE. 3/9/2001 00:00 - 07:00 7.00 RUNCOI~ COMP LAND HANGER & RILDS & SET TWC & TEST TO 3500 PSI. 07:00 - 08:30 1.50 BOPSUF COMP NIPPLE DOWN BOP 08:30 - 10:00 1.50 WHSUR COMP NIPPLE UP TREE & TEST TO 5000 PSI. 10:00 - 11:00 1.00 WHSUR COMP PULL TWC & SET BPV 11:00 - 12:00 1.00 WHSUR COMP SECURE TREE AREA. Printed: 4/12/2001 9:25:42AM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P M E E L E W A T E R IA L U N D E TH IS M ARK ER R ;.'~-T~,f ' · STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I-'] operation Shutdown I"-] Stimulate I--I Plugging [--I Perforate I~ Pull Tubing . r--I Alter Casing I--I Repair Well I~ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 2369' SNL, 4070' WEL, Sec. 34, T13N, R10E, UM At top of productive interval 1704' SNL, 3753' WEL, Sec. 34, T13N, R10E, UM At effective depth 1597' SNL, 3780' WEL, Sec. 34, T13N, R10E, UM At total depth 1570' SNL, 3773' WEL, Sec. 34, T13N, R10E, UM 5. Type of well: [] Development [-] Exploratory [--I Stratigraphic I--I Service ESP Changeout 16. Datum Elevation (DF or KBE) KBE = 72' 7. Unit or Property Name Milne Point Unit 8. Well Number MPH-04 9. Permit Number / Approval No. 90-89 10. APl Number 50- 029-22064 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 4472' feet true vertical 4345' feet Effective depth: measured 4393' feet true vertical 4265' feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Size Cemented MD TVD 70' 13 3/8" 500 sx PF 'C' 105' 105' 2527' 9 5/8" 1014 sxAS/250 sx 2562' 2521' 4437' 7" 211 sx Class 'G' 4472' 4345' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSV (type and measured depth) 4086'-4099', 4111 '-4118', 4134'-4154', 4208'-4238', 4274'-4288' ~. ~~ . 2 7/8" 6.5~ L-80 to 3718' 0i/~ 7" Baker SC-IL pkr ~ 3811' & 7" Baker 'D' sump pkr 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAl 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments i---I Copies of Logs and Surveys run [~ Daily Report of Well Operations 6. Status of well classifications as: Oil I-'1 Gas I--1 Suspended Service 17. I hereby certify that the foregoing is true an.d/correct to the best of my knowledge Signed Title Staff Technical Assistant Date .~-~,/~ '~/ Prepared By Name/Number: Jeanne L. Haas, 5~4-5225 Form 10-404 Rev. 06/15/88 Submit In Duplicate Progress Report Facility M Pt H Pad Well MPH-04 Page 1 Rig Nabors 5S Date 26 February 98 Date/Time 27 Jan 98 06:00-22:30 22:30-06:00 28 Jan 98 06:00-08:30 08:30-10:00 10:00-12:00 12:00-18:00 18:00-01:00 29 Jan 98 01:00-05:00 05:00-06:00 06:00-07:30 07:30-09:00 09:00-15:30 15:30-17:30 17:30-18:00 18:00-18:30 18:30-23:00 23:00-00:00 30 Jan 98 00:00-03:30 03:30-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-12:00 12:00-12:30 12:30-13:30 13:30-17:30 17:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-22:00 22:00-23:30 23:30-03:00 31 Jan 98 03:00-03:30 03:30-06:00 06:00-06:30 06:30-12:00 12:00-12:30 12:30-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-02:30 01 Feb 98 02:30-03:30 03:30-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-09:30 09:30-10:30 10:30-11:00 11:00-06:00 Duration 16-1/2 hr 7-1/2 hr 2-1/2 hr 1-1/2 hr 2hr 6hr 7hr 4hr lhr 1-1/2 hr 1-1/2 hr 6-1/2 hr 2hr 1/2 hr 1/2 hr 4-1/2 hr lhr 3-1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr lhr 4hr 1/2 hr 1/2 hr 1-1/2 hr lhr lhr 1-1/2 hr 3-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 4hr 1-1/2 hr 1/2 hr 1-1/2 hr 6-1/2 hr 1 hr 1-1/2 hr 1 hr 1/2 hr 1-1/2 hr lhr 1/2 hr lhr 1/2 hr 19hr Activity Rig moved 100.00 % Circulated at 3661.0 ft Rigged up Hanger plug Removed Wellhead primary components Installed BOP stack Tested BOP stack Rig waited: Equipment Repaired Annular preventor Rigged down Hanger plug Retrieved Tubing hanger Rigged up Hose reel pack Pulled Tubing in stands to 2000.0 ft Rig waited: Assessed situation Held safety meeting Held safety meeting Pulled Tubing in stands to 0.0 ft Rigged down sub-surface equipment - ESP Conducted slickline operations on Slickline equipment - Tool run Ran Tubing to 600.0 ft (1.315 in OD) Held safety meeting Ran Tubing in stands to 2500.0 ft Reverse circulated at 2500.0 ft Ran Tubing in stands to 3783.0 ft Reverse circulated at 3783.0 ft Washed to 3811.0 ft Washed to 4035.0 ft Held safety meeting Worked toolstring at 4035.0 ft Ran Tubing in stands to 4393.0 ft Pulled Tubing in stands to 3700.0 ft Circulated at 3811.0 ft Washed to 3811.0 ft Washed to 4181.0 ft Worked toolstring at 4181.0 ft Pulled Tubing in stands to 3811.0 ft Held safety meeting Pulled Tubing in stands to 0.0 ft Held safety meeting Rigged up sub-surface equipment - Electrical submersible pumps Ran Tubing in stands to 1436.0 ft Held drill (Abandonment) Installed Electric cable Ran Tubing in stands to 3700.0 ft Installed Tubing hanger Tested Cable splice - Via string Ran Tubing on landing string to 3718.0 ft Held safety meeting Rigged down All rams Installed Xmas tree Retrieved Hanger plug Circulated at 2000.0 ft Installed Hanger plug Serviced SCR STATE OF ALASKA ?""%. ALAS~.. ?OIL AND GAS CONSERVATION ,,.,OMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate []Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP completion & heat trace 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2369' SNL, 4070' WEL, Sec. 34, T13N, R10E, UM At top of productive interval 1704' SNL, 3753' WEL, Sec. 34, T13N, R10E, UM At effective depth 1597' SNL, 3780' WEL, Sec. 34, T13N, R10E, UM At total depth 1570' SNL, 3773' WEL, Sec. 34, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE - 72' 7. Unit or Property Name Milne Point Unit 8. Well Number MPH-04 9. Permit Number / Approval No. 90-89 94-189 10. APl Number 50-029-22064 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 4472' feet true vertical 4345' feet Effective depth: measured 4393' feet true vertical 4265' feet Casing Length Structural Conductor 70' Surface 2527' Intermediate Production 4437' Liner Plugs (measured) Junk (measured) Size Cemented MD TVD 13 3/8" 500 sx PF 'C' 105' 105' 9 5/8" 1014 sx AS/250 sx 2562' 2521' 7" 211 sx C/ass 'G' 4472' 4345' Perforation depth: measured true vertical 4086'-4099',4111'-4118',4134'-4154',4208'-4238',4274'-4288' 3976'-3989',4000'-4007',4022'-4041',4092'-4120',4154'-4168' Tubing (size, grade, and measured depth) Packers and SSV (type and measured depth) 2.88" 6.5# L-80 to 3701' RECEIVED .~aska Oil 7" Baker SC-IL pkr @ 3811' & 7" Baker 'D' sump pkr 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the f/0?going is true and correct to the best of my knowledge · ,,¢~' ¢"t / ,% . S,gn, ed ~/~,,,~,i~, --:',, ,, ~j,.'~..~,) )~;/~ Title ' I ' Prepared By Name/N~mber: Submit In Duplica~ Form 10-404 Rev. 06/15/88 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPH-04 Rig Name: N-4ES AFE# 339036 Accept Date: 01/16/97 Spud Date: . Release Date: 01/19/97 JANUARY 17, 1997 ACCEPT RIG @ 21OO HRS, SPOT RIG, RAISE SCOPE DERRICK RIG LINES TO TREE TEST TO 3000# RIG UP LUB, PULL BPV TBG = 579# CSG = 880# FILL PITS W/SEAWATER BULL HEAD 65 BBLS 8.5 DOWN TUBING MON WELL TBG (0) CONT CIRC 8.5 UNTIL RETURN 8.5 WELL DEAD, FLUID LOSS 6 BPH INSTALL TWC ND TREE/NU BOP. JANUARY 18, 1997 NU BOP, CHG PIPE RAMS TO 2 7/8" TEST BOP MU LUB PULL TWC MU LANDING JT PULL LD HANGER CIRC COND HOLE, INITIAL FILL 24 BBLS SPOT 20 BBL XANVIS ON PERFS MON WELL/STATIC. TOH W/2 7/8" TUBING W/ESP ASSY RIG UP HOWCO RUN 5.9 GR & JB TO 3800, POOH, RIH W/BAILER TAG TD @ 4288' POOH W/SAMPLE IN BAILER RIG DOWN HOWCO. MU SERVICE ESP MOTOR SHAFT EXT TO LONG, HAVE TO CHANGE OUT MOTOR W/O CENTRILIFT 1 HOUR TO GET NEW MOTOR MU & SERVICE NEW ESP. JANUARY 19, 1997 SERVICE NEW ESP MOTOR CONT LINE TEST SAME. TIH W/2 7/8" TUBING W/ESP RIG UP TO RUN HEAT TRACE TIH W/2 7/8" TUBING W/HEAT TRACE W/ESP SPACE OUT MU HANGER MEGGAR HEAT TRACE MU ESP HANGER SPLICE LD TUBING RILDS, LD LANDING JT SET TWC NU BOP NU TREE UNABLE TO TEST HANGER & ADAPTER FLNG LEAK IN NEAK SEALS ND TREE CHANGE SEALS, NU TREE TEST HANGER & ADAPTER FLNG GLAND PKNG LEAKING ON LD SCREWS, REPK SAME. JANUARY 20, 1997 REPAIR GLAND PACKING NUT, CHASE THRDS ON WELL HEAD, INSTALL NEW PACKING ON LDSCREWS. TEST TREE & ADAPTER FLNG TO 5000# PULL TWC INSTALL BPV. FREEZE PROT ANNUL & TUBING RIG DOWN CELLAR, SECURE WELL RIG RELEASED @ 1300HRS 1/19/97. Page 1 of 1 STATE OF ALASKA ~ :~ AL, ,,.,KA OIL AND GAS CONSERVATION COMMIS~,JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing X Alter casing Repair well 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2369' SNL, 4020' WEL, SEC. 34, T13N, RIOE At top of productive interval 1704'SNL, 3753' WEL, SEC. 34, T13N, RIOE At effective depth 5. Type of Well: Development X Exploratory Stratigraphi¢ Service ORIGINAL At total depth 1562' SNL, 3720' WEL, SEC. 34, T13N, RIOE 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 4496 feet Plugs (measured) 4362 feet 4393 feet Junk (measured) 4265 feet Perforate Other .... 6. Datum elevation (DF or KB) KBE = 72' 7. Unit or Property name Milne Point Unit 8. Well number MPH-04 9. Permit number/approval number 90-89/94-189 10. APl number 50- 029-22064 11. Field/Pool Schrader Bluff Casing Length Structural Conductor 70' Surface 2527' Intermediate Production 4437' Liner Perforation depth: Size Cemented Measured depth True vertical depth 13-3/8" 500 sx PF "C" 105' 105' 9-5/8" lO14 sx AS/250 sx "G" 2562' 2521' 7" 211 sx Class "G" 4472' 4345' measured 4086'-4099', 4111'-4118', 4134'-4154', 4208'-4238', 4274'-4288' feet true vertical 3976'-3989', 4000'-4007', 4022'-4041', 4092'-4120', 4154'-4168' Tubing (size, grade, and measured depth) 2-7/8", L-80 tubing to 3701'MD Packers and SSSV (type and measured depth) 4" Baker SC-IL packer @3811' MD; Baker "D" Packer @ 4168' MD; Centrilift FPL T-ARC ESP @ 3742' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl oCT 1 7 1994 Casing Pressure l uomg Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certi~ that the foregoing is true and correct to the best of my knowledge. Signed /'/~_~,'~ ~ ~'.F~ ~/'x~ ~- Title Drilling EngineerSupervisor Form 10-403 Rev 06/1~/88 Date SUBMIT IN DUPLICATE MP H-04 09/05/94 4,472' MOVE RIG F/MPU H-02 TO H-04. SET HERCULITE AND MATS. SPOT RIG, PITS AND PIPE SHED. RU AND RAISE DERRICK. TAKE ON FLUID IN PITS. ACCEPT RIG @0600 HR'S 09/05/94. 09/06/94 4,472' LOAD PITS W/8.7# BRINE. LAY HARD LINE TO KILL TANK. TEST. PU LUBRICATOR AND PULL BPV. DISPLACE WELL TO 8.7# NACL THROUGH PORTED NIPPLE @3666'. MONITOR WELL. DEAD. INSTALL BPV. ND TREE. NU BOPE. PULL BPV AND INSTALL TWC. TEST BOPE AND ANNULAR. PULL TWC. BOLDS. PULL TBG HANGER TO FLOOR. LD SAME. CIRC AND WARM WELLBORE. POH STANDING BACK 2 7/8" TUBING. SLM AND DRIFT. COILING ESP CABLE ON GROUND. 09/07/94 4,472' SERVICE RIG. FINISH POH. LD ESP. RECOVERED 259 STRAPS AND 4 FLAT GUARDS. RU CAMCO. RIH. TAG FILL @4277' OKB. POH. RD CAMCO. LOAD PIPE SHED W/3.5" DP AND 1" CS HYDRIL. REPAIR 3" VALVE ON CHOKE MANIFOLD. SET TEST PLUG. CHANGE PIPE RAMS TO 3.5". TEST. PULL TEST PLUG AND SET WEAR RING. RIH W/500' 1" CS HYDRIL ON 3.5" DP. TAG UP @4279' OKB. CBU @4259'. RU BJ. TEST LINES. LAY SAND PLUG IN TWO STAGES. POH TO 4120'. 09/08/94 4,472' SERVICE RIG. RIH AND TAG FILL @4128' AND WASH DOWN TO 4148' AND REVERSE ClRC AND CONDITION HOLE @4148'. MONITOR WELL. POH AND LAY DOWN 16 JTS 1" CS HYDRIL TBG. MU 3" REVERSE ClRC JET PUMP AND BAKER SNAP LATCH ASSY AND RIH TO 3783'. RU BJ. FOAMED ACID STIMULATION EQUIPMENT. TEST LINES. PUMP 500 GAL 15% HCL ACID / 10% XYLENE THROUGH SURFACE EQUIPMENT AND DOWN WORK STRING DISPLACE W/SOURCE H20 12 BBL AND REVERSE OUT. STING INTO PACKER WITH SNAP LATCH AND PUMP ACID. 09/09/94 4,472' CONTINUE WITH ACID STIMULATION. PUMP TOTAL OF 271 BBL ACID AND FLUSH. RIG DOWN BJ EQUIPMENT. RIG KILL LINE TO ANNULUS AND TEST. FLOW BACK ACID STIMULATION. 09/10/94 4,472' oCT 1 7 1994 Oit & Gas Cons, Commission Anchorage CONTINUE TO POWER PUMP WELL TO REC. ACID FROM STIMULATION JOB. KILL WELL W/8.7 BRINE AND MONITOR WELL. POH AND LAY DOWN 10 JTS DP. PICK UP 1" CS HYDRIL AND 1.25" HYDRIL FOR CL-OUT STINGER. 09/11/94 4,472' SERVICE RIG. RIH, TAG SAND PLUG @4160'. REVERSE CIRC AND WASH THROUGH SAND PLUG 4160-4316'. REVERSE CIRC 4316-4348', 4348- 4381' WASH DOWN. PUMP 40 BBL XANVIS SWEEP WITH LITHIUM BREAKER. POH TO 4300'. CUT 84' DRLG LINE AND WAIT ON SAND TO SETTLE TO CK FILL. RIH AND TAG FILL #4365'. WASH F/4365-4381'. ClRC AND COND HOLE. DROP DAR AND OPEN PUMP OUT SUB AND ClRC BOTTOMS UP AT PKR TOP. 09/12/94 4,472' SERVICE RIG. POH AND LAY DOWN 3 1/2" DP. CHG. PIPE RAMS TO 2 7/8". RIG UP TO RUN 2 7/8" TBG. LAY DOWN 1" AND 1.25" CS HYDRIL CLOUT STRING. PULL WEAR RING AND TEST DOOR. RIG UP TO RUN 2 7/8" TBG. RIH W/ESP. INSTALLING HEAT TRACE CABLE AND ELECTRIC CABLE. 09/13/94 4,472' GROUND FAULT DETECTED IN HEAT TRACE CABLE, POH TO 1500'. CHANGE OUT HEAT TRACE CABLE AND ClRC HOLE TO 38 DEG RETURNS. TEST HEAT TRACE CABLE AND RIH INSTALLING SAME TO 2000'. CHECK HEAT TRACE CABLE AND DETECTED GROUND FAULT. DISCUSS WITH RAYCHEM IN CALIFORNIA ABOUT PROBLEM. DECISION MADE TO LAY DOWN HEAT TRACE. POH LAYING DOWN CABLE. CLEAN FLOOR OF BANDS AND FLAT GUARD ETS. RIH W/ESP & 2 7/8", 6.5# L-80 8RD. EUE TBG TOTAL OF 115 JTS TO 3741' USED 38 FLAT GUARDS AND 233 STEEL BANDS. MU HEAT TRACE PENETRATOR TO HANGER AND ESP CABLE AND TEST LINE. LAND TBG HGR AND RILDS AND TEST HGR. BACK OUT LANDING JT, INSTALL TWC. NIPPLE DOWN BOPS. 09/14/94 4,472' INSTALL LIFTING CLAMPS ON BOP AND NIPPLE DOWN SAME. NIPPLE UP ADAPTER FLG AND TREE AND TEST. PULL TWC AND PUMP 75 BBL DIESEL DOWN ANNULUS AND U-TUBE TO TBG. WELL FLOWING DUE TO REDUCED HYD. SET BPV WITH LUBRICATOR. CLEAN PITS AND DISPOSE OF FLUIDS. RELEASE RIG @1700 HR'S ON 09-13-94. RECEIVED 0CT 1 7 1994 ~i~,~kft 0il & GaS Cons. Commission Anchorage MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: 'David Jo~ DATE: Chairma~ September 5, 1994 THRU: Blair Wondzell, ~- P. I. Supervisor Petroleum Inspe~ctoi- FILE NO: AWPIIEBD.doc BOPE Test - Nabors 4ES BPX - MPU - H-04 PTD # 90-0089 Approval # 94-0189 ~o.'<~.) Milne Point Field Monday, September 5, 1994: I traveled this date to BPX's MPU well H-04 and witnessed the BOPE test on Nabors rig 4ES. As the attached AOGCC BOPE Test Report shows there were 2 failures. The Dart floor safety valve leaked and the air pump on the accumulator unit would not work. These items are to be repaired and I am to be notified with-in 24 hours. Testing on this rig is very time consuming due to the offset tubing hanger. A sub has to be screwed on the bottom of the test joint when testing the pipe rams and annular preventer. The sub must be pulled up against the rams after they are closed to hold the test joint in place when pressure is applied. ! talked to Tom Anglen, BPX rep., and Gene Sweatt, Nabors tool pusher, about my concern and they both agreed that something needed to be changed. Summary: I witnessed the BOPE test on Nabors 4ES - Test time 6.5 hours - 2 failures. Tuesday, September 6, 1994: I spoke with Tom Anglen this afternoon and he informed me that new test joints for each size pipe being used by this rig were being prepaired. He also told me that the air pump on the accumulator pump was repaired and the dart valve was being repaired. Attachment: AWPIIEBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover:X Approval#94-189 DATE: g/5/94 Drlg Contractor: NABORS Rig No. 4ES PTD # g0-0089 Rig Ph.# 65g-2235/34 Operator: BPX Rep.: TOM ANGLEN Well Name: MPH-04 Rig Rep.: GENE SWEATT Casing Size: 7" Set @ 4437' Location: Sec. 34 T. 13N R. IOE Meddian U Test: Initial X Weekly Other Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: O...._~K Well Sign OK Upper Kelly/IBOP I 500/5,000 I 1 Housekeeping:. OK (Gen) Drl. Rig OK Lower Kelly / IBOP I 500/5~000. I 1. Reserve Pit N /A Ball Type I 500/5,000 ' Inside BOP I 500/5,000 Quan. 1 I 5OO/5,00O 500/5,000 I 500/5,000 I 500/5,000 2 500/5,0OO I 500/5,000 N/A Test Pressure P/F 300/3,000 P P P P P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Visual Alarm Tdp Tank N lA NO Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES CHOKE MANIFOLD: No. Valves 8 No. Flanges 26 Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 500/5,000 I P 500/5,000 P Functioned P Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 6 ~ 2100 3,000 J P , p, 0 minutes 32 sec. minutes 48 sec. YES Remote: YES Psig. Number of Failures: 2 ,Test Time: 6.5 Hours. Number of valves tested 14 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I J[ II II I I I I I I I REMARKS: Failures: The Dart valve leaked The air pump on the accumulator unit would not work - These 2 items are to be repaired within 24 hours and the inspector notified. Distribution: orig-Well File c - Oper./Rig c- Database c - Tdp Rpt File c- Inspector FI-021L (Rev. 7/19) STATE WITNESS REQUIRED? YES X NO Waived By: VV'rtnessed By: 24 HOUR NOTICE GIVEN YES X NO ,, ~ II AW~IIEBD.XLS BOBBY D. FOSTER ~ ~ STATE OF ALASKA ALAoKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend ~ Operation Shutdown ~ Re-enter suspended well~ Alter casing__ Repair well X Plugging ~ Time extension ~ Stimulate X Change approved program ~ Pull tubing x Variance ~ Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory ~ Stratigraphic ~ Service 4. Location of well at surface 2369' SNL, 4020' WEL, SEC. 34, T13N, RIOE At top of productive interval 1704'SNL, 3753' WEL, SEC. 34, T13N, RIOE At effective depth At total depth 1562' SNL, 3720' WEL, SEC. 34, T13N, RIOE 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical RECEIVED JUL -8 1994 Alaska 0ii & Gas Cons. Commission Anchorage 4496 feet 4362 feet 4393 feet 4265 feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) KBE. 72' 7. Unit or Property name Miine Point Unit 8. Well number MPH-04 9. Permit number 90-89 10. APl number 50- 029-22064 11. Field/Pool Schrader Bluff ORIGINAL feet Casing Length Structural Conductor 70' Surface 2527' Intermediate Production 4437' Liner Perforation depth: Size Cemented Measured depth True vertical depth 13-3/8" 9-5/8" 500 sx PF "C" 105' 1014 sx AS/250 sx "G" 2562' 7" 211 sx Class "G" 4472' measured 4086'-4099', 4111'-4118', 4134'-4154', 4208'-4238', 4274'-4288' 105' 2521' 4345' true vertical 3976'-3989', 4000'-4007', 4022'-4041', 4092'-4120', 4154'-4168' Tubing (size. grade, and measured depth) 2-7/8", L-80 tubing to 3775' MD Packers and SSSV (type and measured depth) 4" Baker SC-IL packer @3811 'MD; Reda DN-800 ESP @ 3736' MD 13. Attachments Description summary of proposal x Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 8/1/94 16. ff proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,-' ['/,,,, ,,~' ~ ~ -~ Title Drilling Engineer Supervisor ' ~' "" ....... '~=OR COMMISSION USE ONLY Conditions of appffgval:~" Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance Mechanical Integrity Test~ Subsequent form required 10-~O~'. J Approval No?~..../oO? Approved by order of the Commission ORIGINAL SIGNED ElY RUSSELL A. nm m.~, ~,~, Form 10-403 Rev 06/15/88 Commissioner Approved Copy Returned SUBMIT IN TRIPLICATE Milne Point H-04 RWO and H¢I ~timulation Obiective: - The objective of this work is to pull a failed electrical submersible pump from the well, perform an acid stimulation and flowback with Nabors 4ES workover rig, then recomplete with a new ESP. The work is expected to begin 8/1/94. Work Outline: . Pre-rig: Open AVA ported nipple at 3666 MD. Circulate crude from well with Milne source water. Freeze protect with diesel. Install BPV. . MIRU Nabors 4ES wokover rig. Pull existing 2 7/8" tubing and ESP assembly. . Check PBTD with slickline (a fill cleanout may be performed if excessive fill covers lower perfs. Set plug in XN nipple at 4181 MD. . Run seal assembly and jet pump on workstring. Sting into packer at 4155 MD. . Pump nitrified HCl acid stimulation. Flowback well via jet pump and workstring. . Pull workstring and lay down seal assembly and jet pump. Pull XXN plug. . Recomplete well with new ESP and heat trace on 2 7/8", 6.5#, L-80 tubing. . RDMO Nabors 4ES. Place well on production. RECEIVED JUL - 8 1994 Alaska 0il & Sas Cons. C0mmisslon Anchorage DBR, 1:55 PM, June 22, 1994 NOTES: WELL No. H-4 COMPLETION SKETCH MILNE POINT UNIT (P) APl No.: 50--029-22064 PERMIT No.: 90-89 COMPLETED: 1/17/91 LAST WORKOVER: N/A WKM 2 7/8" TUBING HANGER W/ "H" PROFILE BPV ALL DEPTHS MEASURED RKB = 35' FROM RIG 27E KDB-SL = 72' KDB-GL = 37" 2. MAX. ANGLE = 21.2' @ 4415' 3. K.0. P. = 1500' 4. SLANT HOLE: YES 5. TREE TYPE: WKM 2 9/16", 5000//, W/ 2 7/8" 8rd TREETOP CONNECTION 6. MIN ID = 1.791" @ 4181' 115 JTS., 2 7/8", 6.5#, L-80, 8rd EUE TUBING --ESP CABLE - No. 2 REDA BLACK COMPLETION FLUID: 8.6 PPG NaCI W/ 12% METHANOL STIMULATION: FRAC (4208'-4288') PUMPED 104,233# OF 16/20 MESH CARBO-LITE FRAC-PACK (4086'-4154') PUMPED 8080// OF 20/40 MESH GRAVEL 3666' AVA PORTED NIPPLE (2.259" ID) W/ ISOLATION SLEEVE (1.875" ID) ESP ASSEMBLY: REDA DN-800 PUMP WITH 191 STAGES, 75 HP, llOOV/41.SA MOTOR, STANDARD INTAKE, LSB PROTECTOR, PSI UNIT RECEIVED 3736' TOP OF ESP 3775' BOTTOM OF ESP / ,.~ ~ '¢ ','. ¢ .%. JUL - 8 1994 oil & Gas cons, commimion Annotate ' N SAND PERFORATION DATA MI) TVD DEPTH: 4086'-4099' ~. 3976'-3989' 4111'-4118' q 4000'-4007' 4134'-4154'~o 4022'-4041' DENSITY: 24 SPF, 24 GM 0 SAND PERFORATION DATA MI) DEPTH: 4208'-4238' 4274'-4288' DENSITY: 5 SPF, 37 GM 7" CASING @ 4472' TVD ,'t'1 4092'- 4120'(,~ ~ 4154'-4168' (Jq') 3811' BAKER SC-IL PACKER (4.0" ID) 3845' BAKER 2 7/8" BLANK PIPE (231') 4076' BAKERWELD 2 7/8" 12 go SCREEN (79', 2.441" ID) FRAC PACK (N-SANDS) 20/40 MESH GRAVEL 4155' BAKER POLISHED BORE RECEPTACLE (2.062" ID) 4156' BAKERWELD 2 7/8"2 TELL-TALE SCREEN (10', 2.441" liD)g° BAKER MODEL "D" PACKER (3.25' ID) OTIS "XN" NIPPLE (1.791" ID) WIRELINE RE-ENTRY GUIDE (1.81" ID) PBTD 4168' 4181' 4182' 4393' CONOCO INC. J_A_PpROVED_ ............ BY: HDS/BGA DATE: 7/2g/g2 OPERATOR: CONOCO, INC. WELL: MPU H-4 MILNE POINT UNIT H-4 FINAL DRILLING REPORT /~,~~1 ~~..~1 'w~ka · /,9,.9j FIELD: KUPARUK Oil& 8a, Co, PTD: 4496 MD CASING: 13 3/8" @ 115 9 5/8" @ 2562 7" @ 4472 CURRENT TD: 4496 PROGRESS: 0 DATE: 10-13-90: 10-14-90: 10-15-90: 10-16-90: 10-17-90: 10-18-90: 10-19-90: Description of Operations: Move in & RU. PU rig at 1000 hrs 10-12-90. Drill 115 to 632. Drill 632 to 1203. Short trip. Drill to 1364. Trip for bit. Drill to 1886. KOP @ 1500'. LD 4 jts. Ream out dogleg. Ream to 1886. Drill 1886 to 2570. Circ. Short trip. Circ. POOH. Run 4 arm caliper on E/L. Run 65 jts 9 5/8", 2521', 36//, K-55, BUTT csg. FS @ 2562. FC @ 2481. Cmt w/334 BBL Artic Set cmt and 51.6 BBL G cmt. Bump plug. Cmt returns to surface. ND diverter. Install speed head. NU BOP. Test same. MU 8 1/2" bit & steerable BHA. Test csg to 1500 psi. Drill out float equip. Drill 2570 to 2580. Run leakoff to 12.5 PPG EQUIV. Drill to 3412'. Drill 3412 to 3790. Short trip. Drill to 4496. C & C. Short trip. C & C. POOH. RU E/L. Log w/DITE-NGT-CNL-LDT-CAL. Fin rng log. RIH to 4496. C & C. POOH. LD DP & BHA. Run 111 its, 4431 ', 268, L-80, Butt csg. FS @ 4472. FC @ 4392. Circ. Cmt w/45 BBL G cmt. Disp w/9.2 PPG NACL. Bump plug. Test csg to 1500 psi. Install & test packoff. ND BOP's. NU tree. Clean pits. Release rig to I-1 @ 0130 hrs 10-18-90. Operations suspended. RIG RECEIVED: 10-12-90 SPUD DATE: 10-12-90 RIG: NABORS 27 DAYS: 7/8 FOREMAN: Polya DATE: 10-22-90 .~Onoco Inc. Anchorage Division To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed . Jcord of Shipment of Confidential Information Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 June 10, 1993 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Quantity Contents 1 L~ ~E-7 Final Drilling & Completion Report 0~\'~-' ~-7 Core Analysis Report _ 1 ~.~tE-.7 Sidewall Descriptions ~01"~'? .{-1~.-2 Final Drilling Report _C~.~ .-~1-3 Final Drilling Report °'Z~I~'F~-H-4 Final Drilling Report (~rl~~!-I Final Drilling Report ~:~1~-~ I ,~rI-2 Final Drilling Report C~,,~ ~I'3 Final Drilling Report -3 No Whole Core or Sidewall Cores taken as noted on completion report. ~ 1~::~ J I-4 Final Drilling Report 1 f-4A Core Analysis Report ~-1 Final Drilling Report ~-1 1., ~J-2 1 Core Analysis Report Core Description Report Final Drilling Report Completion History Final Drilling Report Final Drilling Report Final Drilling & Completion Report Final Drilling & Completion Report Final Drilling & Completion Report Core Description Report Core Analysis Report RECEIVED JUN 1 1 993 & Gas Cons. Commission Anchorage Signed By Transmittal Approved By Instructions: Please Received By Remarks Date by signing and returning second copy. Date Transmittal Copy Only To Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 March 10, 1993 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: Enclosed are magnetic tapes in LIS format for Milne Point Unit wells H-2, H-3, H-4 and I-1. Verification lists for the tapes are also enclosed. The well locations, AP! numbers and tapes enclosed are as follows: Well# APl# Location Tape Tape Date Depths H-2 50-029-22062 Sec 34, T13N, R10E OH EDIT 10/25/90 3082.0 - 6208.5 , .... ., H-3 50-029-22063 Sec 34, T13N, R10E OH EDIT 03/17/91 2825.0 - 5680.5 · , , ,, , . , 50-029-22064 Sec 34, T13N, R10E OH EDIT 03/17/91 2493.5 - 4543.5 ,,. I-1 50-029-22065 Sec 33, T13N, R10E OH EDIT 11/14/90 3222.0 - 6248.0 YOU had also requested two logs for Well No. H-3, titled "4-Arm Caliper" and "Gamma Ray-CCL". We didn't run logs with these specific titles, however, the "Borehole Geometry Log" was run using a 4-Arm caliper tool, and the Gamma Ray curve and CCL may be found on the "Completion Record" log. Both of these logs have previously been provided to AOGCC. To confirm arrival of these data, please sign the second copy of the letter and return it to me at the letterhead address. Should you have any questions, please phone me at 564-7614. Sincerely, Linda M. Starr Technical Assistant cc: SFD MAR WELL COMPLETION OR RECOMPLETION hEPORT AND LOG ;--~, STATE OF ALASKA ~ 1"1 I;I I ~, I [ ....... ~ ALASKA :AND GAS CONSERVATION C( ~IISSION v .~ · v, .~,-,: - OIL [~ GAS [] SUSPENDED :~-~/ ABANDONED [] SERVICE [] ------ 21 Name of Operator 7.' Permit Number CONOCO INC. 90-89 Pouch 340045 Prudhoe Bay, Alaska 99734 "-~ .... ~ 4. Location of well at surface ! 2. tt 2369'FNLx4020'FEL of Sec. 34, T13N, R10E, Umiat Mer~':~ At Top Producing Interval AT'~ 1701'FNLx3758'FEL of Same Section ~ V~RJFIE~- At Total Depth 1562'FNLx3720'FEL of Same Section ~ 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 72 KB I ADL - 25906 12. Date Spudded 13. Date Y,O. Reached 10-11-90 10-15-90 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I'VD) 4496 + 4362 4393 + 4265 22. Type Electric or Other Logs Run 8. APl Number 50-029-22064 9. Unit or Lease Name Milne Point Unit 10. Well Number H-4 1 1. Field and Pool KUPARUK RIVER FIELD 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 01-17-91 N/A feet MSLI 2 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost YES [~ NO [][NONE feet MDI +- 1800 23. CASING SIZE 13-3/8 9-5/8 WT. PER FT. 54.5# 36# GRADE K-55 J-55 7 26# L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 35 105 30 500 sxs PermaFrost C NONE 2562 35 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) N Sands 4086-99~D 3976TVD 24SPF, 24'~,4111-18, 4134-54MD 4041TVD O Sands 4208-40MD 4093TVD 5SPF, 37GM 4274-88MD 4168TVD 12-1i4 1014 sxs Arctic Set NONE 250 sxs G 35 4472 8-1/2 211 sxs G NONE 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8 3775 NONE 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 4208-4288 104.223# 16-20 Mesh Proppan= 27. PRODUCTION TEST Date First Production 4-22-91 IMethod of Operation (Flowing, gas lift, etc.) Submersible Pump PRODUCTION FOR IO'L-BBL IGAS'MCF TEST PERIOD I~ I 78 / 16 CALCULATED .~ I O,L-BB' IGAS-~CF 24-HOUR RATE "~1 156 ~ 32 Date of Test 4-23-91 Flow Tubing Press. 3 12 Hours Tested 12 Casing PressUre 0 WATER-BBL 276 WATER-BBL 522 CHOKE SIZE IGAS'OILRATIO 209 I 204 OIL GRAVITy-APl (curt) NA 28, CORE DATA None Taken Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top of "N" Sand Top of "0" Sand GEOLOGIC MARKERS MEAS. DEPTH 4086' 4208' 31. LIST OF ATTACHMENTS _~. Plat, Gyro Survey 32. TRUEVERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, ali fluids recovered and gravity, GOR, and time of each phase. 3976' 4093' NA I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~'J~/~~ Title Sr. Prod. Foreman Date 4-28-9l ( . INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- 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". Form 10-407 A = 04,'58'!7" R .~ 954.93' T = 41,4.5' L = 82, B6' ~'~/~5-40,59,' z~ = 58'08'48" > R ..w 954.95' T = 530,93' L - 969.11' CH PAD PI #10 /~ Y-- 6,009,620,71 X= 556,30,B.B8 Y= 6,010.4,29,32 ×= 556,535.9t PROPOSED PAD ~PAN$10N ~ NOTES: .,..--~ H PAD MILNE PT. VICINITY MAP MILES STATE PLANE COORDINATES ARE ZONE 4. ALL G~OD~C POSITIONS ARE BASED ON N.A,D. 1927, OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION OORNER POSITIONS. LEGEND EXISTING WELL o PROPOSED WELL AS-BUILT WE LL DATALOCATED WITHIN SECTION ,34, · r. ~ .., .. ~o ~:,, u..., WELL PLANT A,$.P. ZONE 4. LATITUDE SEC. LINE NO. COORDS COORDS LONGITUDE OFFSETS , H-1 N 1199.'~3 ....... Y 6,009,889.10 70' 26' 15.660" 254.2' FNL E 879.69 X 556,576.05 14.9' 32' 19.320" 4.070' FEL H-2 N 1260.28 Y 6,009,947.33 70' 26' 16,171" 24.84.' FNL E 879.92 X 556,592.64 14,9' 32' 18,820" 4.053' FEL H-3 N 1519.75 Y 6,010,004,65 70' 26' 16.734" 24.27' FNL E 879.66 X 556,608.4,6 14.9' 32' 18.343" 4.037' FEL H-4- N 1380.11 N 6,010,062.74. 70' 26' 17.304," 2;.'569' FNL E 879.70 E 556,624.81 149' 32'17.850" 4.020' F'EL ,,, -- II II i III · . SURVE:¥6~,'S i HEREBY CE~RT1FY THAT t AM PROPERLY REGISTERED CERTIFICATE AND LICENSED ,TO, PRACTICE LAND SURVEYING IN THE ~'OF I STATE OF ALASKA, AND THAT THIS PLAT REPRESENTS J A LOCATION ~URVEY MADE BY ME OR UNDER MY DI,~- I ECT SUPERVloION.AND THAT ALL DIMENSIONS AND .c.~'L~.~ ¢'~/~J~' "._' .~Y-~ I llll I - II II I~ . I II Milne Point H No. 4 COMPLETION HISTORY Kuparuk River Field - North Slope Borough, Alaska W.I. 1.0 Milne Point H No. 4 CONFIDENTIAL AFE 10-61-1262 Location: 2369' FNL, 4019' FEL, Sec 34, T13N, R10E, U.M., NSB AK Location: Bottom Hole 1602' FNL, 3721' FEL, Sec 34, T13N, R10E, U.M. 01-03-91: R/U on H-4. Rig accepted as of 1630 hrs 01-02-91. Clean rig. N/U BOP. Mud wt. 9.2 NaC1 Viscosity: N/ACum. Cost: $ 862,953 POOL 102 (0-7-1) Drilling Foreman: BRADY 01-04-91: NU BOP. Test choke manifold & BOPs. P/U bit, scraper & TIH. Tag bottom @ 4393' Measure RKB @ 29.40'. Filter 120 bbls brine. Reverse ci~c 9.2 ppg brine out of hole w/ filtered 8.6 ppg brine. Dilute 9.2 ppg brine (120 bbls) to 8.6 ppg w/ HzO & methanol. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 880,522 POOL 102 (0-7-2) Drilling Foreman: BRADY\KOTARA 01-05-91: Finish diluting 9.2 ppg to 8.6 ppg w/ water & methanol. Mix & reverse circ pill (20 bbl dirt magnet, 20 bbl H20, 20 bbl dirt magnet). Filter fluid while circ. POOH. Run gyro (G.T.C.) on EL. RIH w/ perf guns (5 SPF, 37 gm). Perf "O" sand from 4274'-4288'. P/U to make 2' perf interval from 4238'-4240'. Gun did not fire. POOH. RIH w/ perf guns (5 SPF, 37 gm). Perf "O" sand from 4208'-4238'. R/D Schlumberger. P/U 2 jts D.P., Champ III PKR, jars, 4 DCs & TIH on 3-1/2" D.P. Set PKR at 4045'md. R/U Dowell Schlumberger for frac job. 01-06-91: Pressure test lines to 8000 psi. Pump 100 bbls prepad (WF-40) @ 25 bbl/min. Injection press - 3100 psi. ISIP - 1000 psi (gradient -.68 psi/ft). Pump 571 bbls pad (YF140D) @ avg press ~ 3400 psi. Start pumping prop in stages. ISIP - 1116 psi. Monitor DP pressure. Press - 680 psi. Pressure up on annulus to 500 psi & test. OK. Open bypass on Champ III PKR. DP press showed 580 psi., csg press - 400 psi. Monitor DP pressure & csg pressure. 01-07-91: Bleed 4 bbls off well. DP press - 230 psi, csg press - 180 psi. R/U to rev circ. Circ ± 35 bbls up drill pipe. Shut well in. Press on DP 90 psi. Monitor well pressure. DP press - 160 psi, csg press - 165 psi. Bleed 4 bbls off well. Unseat Champ III PKR & pull 4 stds DP. Shut well in & monitor. Press - 45 psi. R/U slickline. TIH w/ impression block & tag sand @ 4265'. Top perf @ 4208'. Est. 130' sand to PBTD (~ 5 bbls). POOH w/ slickline. Shut in well & monitor pressure. Press on well - 45 psi. TIH to 4200'. R/U to rev circ. Rev circ DP vol ~ 30 bbls. Lost 4 bbls. Shut well in. Press on well 40 psi. R/U filter unit. Filter fluid on surface. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,140,124 POOL 102 (0-7-5) Drilling Foreman: KOTARA\MARTIN Milne'Point H No. 4 Completion History Page 2 01-08-91: Rev circ 1 hole volume. Well dead. POOH. P/U bailer assby. TIH w/ bailer. Tag sand @ 4209'. Bail sand from 4209'-4345'. Could not make any more hole. POOH w/ bailer. Recovered ~ 5.5 bbls sand. Est 1.5 bbls sand left to bail. TIH to bail sand. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,189,163 POOL 102 (0-7-6) Drilling Foreman: KOTARA\MARTIN 01-09-91: RIH w/ bailer. Tag sand @ 4335'. Bail frac sand f/ 4335'-4392'. Make 5 etd short trip. Wait 30 min. RIH to bottom. Tag sand @ 4383'. POOH w/ bailer. Retrieved 1.2 bbls sand. R/U Schlumberger wireline. RIH w/ Baker model "D" sump PKR. Set PKR @ 4168'md. POOH w/ wireline. P/U TCP assby & TIH on 3-1/2" DP. Tag sump PKR. Run seals thru seal bore and make positive location. P/U assby to shooting depth & set Champ III PKR. Pressure up down DP to 500 psi to assure seals in place. OK. R/U Halliburton test head, flowline to rig manifold. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,235,161 POOL 102 (0-7-7) Drilling Foreman: KOTARA\MARTIN 01-10-91: Pressure test surface lines to 1500 psi. OK. Pump 24 bbls diesel down DP to achieve 300 psi underbalance. Drop bar. Guns fired. Perforated interval: 4086-99, 4111-18, 4134-54 @ 12 SPF. Rev circ. Unseat PKR. P/U TCP assby #2. RIH on 3-1/2" DP. Fill DP w/ diesel on way in hole for 300 psi underbalance. Tag sump PKR @ 4168'. Space out. R/U test head. Set Champ III PKR. R/U surface flowlines. Test annulus to 500 psi. Test surface lines to 3500 psi. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,257,325 POOL 102 (0-7-8) Drilling Foreman: KOTARA\BURMAN 01-11-91: Press up on DP to 3000 psi. Guns fired. Perforated interval @ 12 SPF: 4086-4099, 4111-4118, 4134-4154. Flow well for 1 hour. Well flowed 6 bbls. Shut well in. Press up on annulus to 2200 psi. APR-M2 circ valve failed to open. Press up to 3500 psi. Not open. Open by-pass ports on Champ PKR. Pump down annulus thru by-pass. No returns at surface. Pumped 3 bbls into formation. Attempt to circ down DP - failed. Unseat Champ PKR. Pull 5 stds & set Champ PKR. Press up on annulus to 3000 psi. Circ valve failed to open. TIH sump PKR & work seal assby thru PKR. OK. Pull 30 stds. R/U TIW valve. Attempt to circ well. Could not circ. Set PKR. R/U Schlum. RIH to 1871 . Fire guns (4' @ 4 SPF). Press up on annulus - positive indication of communication. POOH w/ gun. Rev circ diesel out of DP. Unseat Champ PKR. POOH. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,287,005 R E~ ~D(0-7-9) Drilling Foreman: KOTARA\BURMAN Milne Point H No. 4 Completion History Page 3 01-12-91: POOH w/ TCP assby. Found APR-M2 circ valve closed in both positions - to the annulus & down drill pipe. TIH w/ circ assby/junk baskets. Tag sump PKR @ 4168'_ Circ. Run stinger thru seal bore. POOH to 3993'. Circ/filter fluid. POOH. P/U Baker gravel pack assby. TIH w/ gravel pack assby on 3-1/2" DP. 01-13-91: TIH w/ gravel pack assby. Tag sump PKR @ 4168'. Space out. Drop ball. Pressure up to 2500 psi. PKR set @ 3810' Pressure up on backside to 1200 psi. Test OK. P/U int~ reverse position. Pressure up to 3700 psi. Ball sheared. Position tool in the reverse position and pump gel & super pickle. Disp w/ brine. Mix gravel pack slurry. 01-14-91: Pumped 20 bbls of prepad - shift tool to lower circ position. Pumped 10 bbls of 2 ppg slurry, 25 bbls of 2 to 8 ppg slurry. Pumped 15 bbls of 8 ppg slurry for annular pack, 5 ppg post pad and displacement. Position G.P. PKR f/ reverse position to circulating position and reverse circ excess after sand out achieved. TOOH w/ 3-1/2" DP. LD gravel pack tools. RU Schlumberger. RIH w/ CCL, TDT-P tool. Log indicates a good gravel pack. POOH. RIH w/ CCL, bull nose. Tag glass disk. Could not break disk. POOH and RD Schlumberger. Depth indicates possible fill ± 1' on disk. MIRU S/L unit. RIH. Tag PKR @ 3800'wlm. Work into PKR. RIH and tag hard @ 4143'wlm. Jarred for 40 min. Cannot break disk. POOH and prep to RIH w/ W/L bailer. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,470,140 POOL 102 (0-7-12)Drillinq Foreman: HARRINGTON/STEVENS/BURMAN 01-15-91: RIH w/ 1-3/4" pump bailer. Work bailer. POOH. Recovered gravel pack sand. RIH w/ 1-3/4" pump bailer. Work bailer down to 4153'wlm. Broke disk. RIH and tag fill @ 4330'wlm. RIH w/ 3-1/2" DP and POOH, LD same. Load pipe shed w/ 2-7/8" tbg. Change pipe rams. PU ESP equipment. RIH w/ ESP assby. PU 2 JTS 2-7/8" 8rd EUE. MU AVA ported nipple w/o sleeve. RIH. PU 2-7/8" 8rd EUE tbg. RIH banding each JT ± 4' from each connection. 2 bands per JT. Check cable every 10 stds. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,629,231 POOL 102 (0-7-13) Drilling Foreman: STEVENS/BURMAN 01-16-91: Continue PU and RIh w/ 2-7/8" 8rd EUE tbg. Rabbit each JT and band cable ± 4' from each connection. 2 bands per JT. Check cable every 10 stds. Hydraulic problem on spooling unit and rig air supply problems due to cold weather. MU tbg hgr. Make ESP cable splice @ hgr. Check/megger cable @ top pig tail/penetrator - OK. Land hgr. Lock down. Test hgr. Set 2-way check. ND BOP. NU tree. Test tree to 5000 psi. Turned actuator 180° before testing tree. Start cleaning pits. Pull 2-way ch~c~~a~3~2 bbls diesel down csg and Oil & Gas Cons. Commission Milne Point H No. 4 Completion History Page 4 allow tbg to set BPV. Set BPV. Pump 11 bbls diesel down tbg. RU to inject down 9-5/8" x 7" annulus. Inject junk brine into 9-5/8" x 7" annulus, 185 bbls. Freeze protect w/ 52 bbls diesel. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,655,562 POOL 102 (0-7-14) Drilling Foreman: STEVENS 01-17-91: Clean pits. Vac out bottoms. Dump water tank and vac out. Release rig @ 0230 hours 01/16/91. Mud wt. 8.6 Viscosity: N/A Cum. Cost: $ 1,664,844 POOL 102 (0-7-15) Drilling Foreman: STEVENS SUB.SURFACE DIRECTIONAL ~URVEY ,~ ~ UIDANCE [~]ONTINUOUS ~IOOL Company CONOCO~ [NC. Well Name MPU H-4 {2369' FNL,4019' FEL,SEC 34,T13N~R10E).. Field/Location SCHRADER BLUFF, NORTH SLOPE. ALASKA Job Reference No. 74274 Logged By; FORMICA SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR CONOCO. INC. MILNE POINT UNIT H-4 SCHRADER BLUFF NORTH SLOPE, ALASKA SURVEY DATE= 04-JAN-lB91 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: ENGINEER: JEFF FORMICA TANGENTIAL- Avecage~ Oeviation an~ azimuth LINEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 20 DEG 41 MIN EAST CONOCO, INC. MJLNE POINT UNIT H-4 SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE: 17-JAN-91 PAGE 1 DATE OF SURVEY: 04-JAN-1993 KELLY BUSHING ELEVATION: 72.00 FT ENGINEER: JEFF FORM[CA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HOR[Z. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -72.00 0 0 N 0 0 E 100.00 100.00 28.00 0 9 $ 5 5 W 200.00 200.00 128.00 0 8 S 11 20 E 300.00 300.00 228.00 0 4 5 15 18 E 400.00 400.00 328.00 0 0 S 30 20 W 500.00 500.00 428.00 0 1 N 79 50 W 600.00 600.00 528.00 0 12 S 17 7 W 700.00 700.00 628.00 0 15 $ 6 55 E 800.00 800.00 728.00 0 9 S 5 35 E 900.00 900.00 828.00 0 16 S 11 26 W 0.00 0.00 0.00 N 0.00 E 0.00 N 0 0 E -0.22 0.00 0.21 S 0.07 W 0.22 S 17 50 W -0.45 0.00 0.47 S 0.03 tv 0.47 S 3 52 W -0.61 0.00 0.65 S 0.00 E 0.65 S 0 10 E -0.67 0.00 0.72 S 0.02 E 0.72 S 1 22 E -0.68 0.00 0.74 S 0.02 E 0.74 5, 1 33 E -0.86 0.00 0.89 S 0.07 W 0.89 S 4 43 W -1.26 0.00 1.30 S 0.11 W 1.31 S 4 48 W -1.56 0.00 1.64 S 0.05 W 1.64 S 1 48 w -1.88 0.16 1.98 S 0.08 W 1.98 S 2 13 W 1000.00 999.99 927.99 0 24 S 5 16 E 1100.00 1099.99 1027.99 0 16 S 4 31 E 1200.00 1199.99 1127.99 0 40 S 1 47 W 1300.00 1299.98 1227.98 0 43 S 1 20 W 1400.00 1399.98 1327.98 0 11 S 22 29 E 1500.00 1499.96 1427.96 2 10 N 24 46 E 1600.00 1599.70 1527.70 5 41 N 17 42 E 1700.00 1698.60 1626.60 11 38 N 19 48 E 1800.00 1795.93 1723.93 13 47 N 21 11 E 1900.00 1893.12 1821,12 13 34 N 21 58 E -2.49 0.36 2.62 S -2,96 0.00 3.14 S -3.66 0.19 3.87 S -4.86 0.00 5.15 S -5.69 0.78 6.05 S -4.29 3.68 4.88 S 2.74 3.20 1.77 N 17.14 6.36 15.41 N 40.07 0.73 63.61 0.02 0.13 W 2.62 S 2 45 W 0.07 W 3.14 S 1 16 W 0.10 W 3.87 S 1 28 W 0.12 W 5.15 S 1 19 W 0.11 tv 6.05 $ 1 3 tV 0.78 E 4.94 S 9 4 E 3.07 E 3.54 N 60 0 E 7.70 E 17.23 N 26 32 E 36.88 N 15.76 E 40.11 N 23 8 E 58.75 N 24.46 E 63.64 N 22 36 E 2000.00 1990.05 1918.05 15 32 N 19 4 E 88.15 2100.00 2086.10 2014.10 16 27 N 20 2 E 115.96 2200.00 2181.85 2109.85 17 26 N 19 18 E 144.80 2300.00 2276.92 2204.92 18 34 N 19 24 E 175.81 2400.00 2371.53 2299.53 19 9 N 20 23 E 208.18 2500.00 2466.19 2394.19 18 36 N 21 2 E 240.42 2600.00 2561.03 2489.03 18 18 N 22 11 E 272.11 2700.00 2656.12 2584.12 17 45 N 22 59 E 303.07 2800.00 2751.28 2679.28 18 20 N 22 3 E 333.76 2900.00 2846.16 2774.16 18 20 N 22 35 E 365.34 3.06 0.16 2.51 0,97 0.54 0.40 0.46 0.69 1.06 0.47 81.67 N 33.25 E 88.18 N 22 9 E 107.90 N 42.50 E 115.97 N 21 30 E 134.98 N 52.44 E 144.81 N 21 14 E 164.33 N 62.49 E 175.81 N 20 49 E 194.78 N 73.50 E 208.18 N 20 40 E 224.93 N 84.90 E 240.42 N 20 41 E 254.41 N 96.54 E 272.11 N 20 47 E 283.02 N 108.41 E 303.07 N 20 58 E 311.35 N 120.24 E 333.77 N 21 7 E 340.60 N 132.20 E 365.36 N 21 13 E 3000.00 2941.06 2869.06 18 26 N 23 6 E 396.86 3100.00 3035.75 2963.75 19 8 N 23 12 E 428.96 3200.00 3130.07 3058.07 19 40 N 24 5 E 462.14 3300.00 3224.36 3152.36 18 33 N 23 37 E 495.38 3400.00 3319.97 3247.97 16 14 N 20 37 E 524.66 3500.00 3415.95 3343.95 16 23 N 20 31 E 552.7t 3600.00 3511.81 3439.81 16 46 N 20 11 E 581.18 3700.00 3607.41 3535.41 17 19 N 20 8 E 610.52 3800.00 3702.79 3630.79 17 39 N 19 19 E 640.57 3900.00 3798.40 3726.40 16 15 N 17 24 E 669.85 0.48 0.83 0.69 4.34 0.54 0.38 0.71 0.41 0.11 0.58 369.64 N 144.51 E 396.89 N 21 21 E 399.21 N 157.09 E 429.00 N 21 29 E 429.65 N 170.40 E 462.21 N 21 38 E 460.04 N 184.02 E 495.48 N 21 48 E 487.23 N 194.89 E 524.76 N 21 48 E 513.48 N 204.77 E 552.80 N 21 44 E 540.16 N 214.71 E 581.27 N 21 41 E 567.70 N 224.83 E 610.60 N 21 36 E 595.99 N 234.97 E 640.63 N 21 31 E 623.81 N 244.18 E 669.89 N 21 23 E COMPUTATION DATE: 17-JAN-91 PAGE 2 CONOCO, INC. MILNE POINT UNIT H-4 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 04-JAN-1991 KELLY BUSHING ELEVATION: 72.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 4ODD.OD 3894.29 3822.29 16 52 N IB 30 E 698.18 0,97 4100.00 3989.77 3917.77 17 47 N 18 14 E 727.86 1.37 4200.00 4084,68 4012.68 18 52 N 16 49 E 759.33 O.9B 4300.00 4178.93 4106.93 20 14 N 15 51 E 792.62 1.16 4393.00 4265,99 4193.99 20 42 N 15 19 E 825.20 0.00 FEET FEET FEET DEG 650.78 N {'~52.94 E 698,21 N 21 14 E 678.97 N 262.30 E 727.88 N 21 7 E 709.01N 271.84 E 759.34 N 20 59 E 741,07 N 281.18 E 792,62 N 20 47 E 772,61N 289,90 E 825.21 N 20 34 E COMPUTATION DATE: 17-JAN-91 PAGE 3 CONOCO, INC. MILNE POINT UNIT H-4 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 04-JAN-1991 KELLY BUSHING ELEVATION: 72.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -72.00 0 0 N 0 0 E 0.00 0.00 1000.00 999.99 927.99 0 24 S 5 16 E -2.49 0.36 2000.00 1990.05 1918.05 15 32 N 19 4 E 88.15 3.06 3000.00 2941.06 2869.06 18 26 N 23 6 E 396.86 0.48 4000.00 3894.29 3822.29 16 52 N 18 30 E 698.18 0.97 4393.00 4265.99 4193.99 20 42 N 15 19 E 825.20 0.00 0.00 N 0.00 E 0.00 N 0 0 E 2.62 S 0.13 W 2.62 5 2 45 W 81.67 N 33.25 E 88.18 N 22 9 E 369.64 N 144.51 E 396.89 N 21 21 E 650.78 N 252.94 E 698.21 N 21 14 E 772.61 N 289.90 E 825.21 N 20 34 E COMPUTATION DATE: 17-JAN-91 PAGE 4 CONOCO, INC. MILNE POINT UNIT H-4 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 04-JAN-1991 KELLY BUSHING ELEVATION= 72.00 FT ENGINEER= JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVZATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M[N FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -72.00 0 0 N 0 0 E 72.00 72.00 0.00 0 9 S 14 5 W 172.00 172.00 100.00 0 9 S 13 44 E 272.00 272.00 200.00 0 5 S 12 4 E 372.00 372.00 300.00 0 1 S 2 0 E 472.00 472.00 400.00 0 0 N 42 57 W 572.00 572.00 500.00 0 9 S 24 30 W 672.00 672.00 600.00 0 15 S 0 13 W 772.00 772.00 700.00 0 10 S 9 13 E 872.00 872.00 800.00 0 13 S 8 22 ~ 0.00 -0.15 -0.39 -0.58 -0.67 -0.68 -D.78 -1.15 -1.49 -1 .77 0 O0 0 O0 0 O0 0 O0 0 O0 0 OD 011 0.00 0.00 0.16 0.00 N 0.00 E 0.00 N 0 0 E 0.14 S 0.06 W 0.15 S 21 42 W 0.40 S 0.05 W 0.41 S 6 36 W 0.62 S 0.01 W 0.62 S O 37 W 0.72 S 0.02 E 0.72 S 1 22 E 0.74 S 0.02 E 0.74 S 1 51 E 0.81 S 0.04 W 0.81 S 3 7 W 1.18 S 0.12 W 1.19 S 5 39 W 1.57 S 0.06 it/ 1.57 S 2 14 ~ 1.87 S 0.06 ~ 1.87 S 1 43 ~ 972.00 972.00 900.00 0 24 S 3 21 W 1072.01 1072.00 1000.00 0 17 S 7 52 E 1172.01 1172.00 1100.00 0 33 S 4 16 W 1272.02 1272.00 1200.00 0 45 S 0 3 W 1372.02 1372.00 1300.00 0 22 S 2 19 E 1472.03 1472.00 1400.00 1 19 N 33 17 E 1572.19 1572.00 1500.00 4 48 N 17 56 E 1672.93 1672.00 1600.00 9 43 N 19 2 E 1775.36 1772.00 1700.00 13 48 N 20 51 E 1878.28 1872.00 1800.00 13 32 N 21 52 E -2.31 -2.84 -3.37 -4.52 -5.58 -5.10 0.19 12.09 34.20 58.52 0.04 0.00 0.63 0.33 0.86 2.46 3.39 7.67 0.44 0.25 2.42 S 3.01 S 3.57 S 4.79 S 5.92 S 5.60 S 0.66 S 10.66 N 0.13 W 2.42 S 3 3 W 0.08 W 3.01 S 1 36 W 0.08 W 3.58 S 1 21 W 0.11 W 4.79 S 1 20 W 0.13 W 5.92 S 1 13 W 0.39 E 5.61 S 3 58 E 2.29 E 2.38 S 73 52 E 6.02 E 12.24 N 29 27 E 31.40 N 13.66 E 34.24 N 23 30 E 54.03 N 22.56 E 58.55 N 22 40 E 1981.30 1972.00 1900.00 14 54 N 19 56 E 83.28 2085.30 2072.00 2000.00 16 24 N 19 55 E 111.80 2189.68 2172.00 2100.00 17 15 N 19 39 E 141.74 2294.81 2272.00 2200.00 18 31 N 19 21 E 174.15 2400.50 2372.00 2300.D0 19 9 N 20 23 E 208.35 2506.13 2472.00 2400.00 18 36 N 21 6 E 242.37 2611.55 2572.00 2500.00 18 17 N 22 15 E 275.73 2716.68 2672.00 2600.00 17 41 N 23 3 E 308.14 2821.83 2772.00 2700.00 18 28 N 22 3 E 340.65 2927.22 2872.00 2800.00 18 20 N 22 50 E 373.89 3.83 0.39 2.37 1.07 0.55 0.36 0.42 0.61 0.46 0.24 77.08 N 31.62 E 83.31 N 22 18 E 103.99 N 41.08 E 111.82 N 21 33 E 132.10 N 51.42 E 141.75 N 21 16 E 162.77 N 61.94 E 174.16 N 20 50 E 194.93 N 73.55 E 208.35 N 20 40 E 226.75 N 85.60 E 242.37 N 20 41 E 257.77 N 97.90 E 275.73 N 20 48 E 287.69 N 110.40 E 308.15 N 21 0 E 317.74 N 122.83 E 340.66 N 21 8 E 346.49 N 135.51 E 373.91 N 21 15 E 3032.63 2972.00 2900.00 18 36 N 22 54 E 407.21 3138.40 3072.00 3000.00 19 22 N 23 30 E 441.62 3244.53 3172.00 3100.00 19 41 N 24 18 E 477.12 3349.98 3272.00 3200.00 16 49 N 21 29 E 510.49 3454.20 3372.00 3300.00 16 17 N 20 39 E 539.83 3558.44 3472.00 3400.00 16 32 N 20 28 E 569.27 3662.92 3572.00 3500.00 17 8 N 20 13 E 599.53 3767.70 3672.00 3600.00 17 33 N 19 32 E 630.80 3872.48 3772.00 3700.00 16 37 N 17 37 E 662.08 3976.72 3872.00 3800.00 16 39 N 18 22 E 691.47 0.76 0.46 0.18 2.60 0.08 0.40 0.51 0.51 2.34 0.86 379.18 N 148.56 E 407.24 N 21 24 E 410.84 N 162.11 E 441.67 N 21 32 E 443.34 N 176.56 E 477.20 N 21 43 E 473.99 N 189.84 E 510.60 N 21 50 E 501.42 N 200.24 E 539.93 N 21 46 E 528.99 N 210.57 E 569.36 N 21 42 E 557.39 N 221.04 E 599.62 N 21 38 E 586.78 N 231.73 E 630.87 N 21 33 E 616.39 N 241.84 E 662.14 N 21 25 E 644.42 N 250.82 E 691.51 N 21 16 E COMPUTATION DATE: 17-JAN-91 PAGE 5 CONOCO, INC. MILNE POINT UNIT H-4 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 04-JAN-1991 KELLY BUSHING ELEVATION: 72.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 4081.34 3972.00 3900.00 17 32 N 18 14 E 722.20 1.15 4186.61 4072.00 4000.00 18 46 N 17 2 E 755.02 0.99 4292.61 4172.00 4100.00 20 9 N 15 53 E 790.08 1.36 4393.00 4265.99 4193.99 20 42 N 15 19 E 825.20 0.00 673.59 N 260.53 E 722.22 N 21 9 E 704.88 N 270.58 E 755.03 N 21 0 E 738.62 N 280.48 E 790.0B N 20 48 E 772.61 N 289.90 E 825.21 N 20 34 E CONOCO, INC. MILNE POINT UNIT H-4 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER LAST READING GCT TD DRILLER COMPUTATION DATE: 17-JAN-91 INTERPOLATED VALUES FOR CHOSEN HORIZONS DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: PAGE 6 04-JAN-1991 72.00 FT JEFF FORMICA SURFACE LOCATZON = 2369' FNL & 4019' FEL, SEC34 T13N RIOE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 4343.99 4218.27 4146.27 755.21 N 285.34 E 4393.00 4265.99 4193.99 772.61 N 289.90 E CONOCO, INC. MILNE POINT UNIT H-4 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER LAST READING GCT TD DRILLER COMPUTATION DATE: 17-JAN-91 STRATIGRAPHIC SUMMARY MEASURED DEPTH BELOW KB 4341.99 4393.00 DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: PAGE 7 04-JAN-1991 72.00 FT JEFF FORM[CA SURFACE LOCATION = 2369' FNL & 4019' FEL, SEC34 T13N RIOE TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 4218.27 4146.27 755.21 N 285.14 E 4265.99 4193.99 772.61 N 289.90 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 4393.00 4265.99 4193.99 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 825.21 N 20 34 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY CONOCO. INC. WELL MILNE POINT UNIT H-4 F I ELD SCHRAOER BLUFF COUNTRY USA RUN ONE DATE LOOOED 04 - JAN - REFERENCE ?42?4 WELL' MPU H-4 --"? !2369'. FNE, 4019' FEL, SEC 3 T13N, RIOE) HORIZONTAL PROJECTION I~RI'H I~XI RE:F' '74~P'74 lOOO 400 S~UTI. I -400 ~ T" ~'~'"~" '~ ' ' · ' ' ' ' ' ~-~~ : , ' ~ ! ~ : i : ' ~'~'"~~' 1 ......... ~.+4-;.. -;...:...¢...;..Li...:...i...~... : .': ,~' · .4. 4 -400 -200 O 200 400 600 800 10013 F. R6T V/ELL: HPu H-4 ..... (.2369.'=. FA!L, 4019' FEL, SEC . T13N, RIOE) VERTICAL PROJECTION -400 -200 0 0 200 4O0 60O :::~~ ...... ~ · ~ ~ ::: , , · - } I { iii il~ !ii :i: ii :iii : i :'' - , -,, , - iii! i'ili,,i} -- · .~, .... liiZi ..., ~~ai _''~ ..... :.:: :::; i,:[ iii: ;i;i i'~ :i ~ [t''l"'{ ~' iii ] 5T '' T~-??~-T'"!"?"?~'?'?"i"'i ...... f..l+_.+ ..... ~ i ~ i ~ ~ i ~ ~ ~-T-T T ~ ~ ~ ' ? ~ i ~ ; + i i--~4-.~-4-H~:+- ..;~._~.~_.;.~...;_.L.;...,.; ...... l...;-.i; .... ;...~...,..~.., i; ~'~'-' , ~'iiiiiii] i i il iiii ~+tii~i l ii~~ i l~] :: : :::: :::::::::::::: ::::::::::::: :::::::: ::::::::: :::::::::::::::: . 21. PROJECTION ON VERTICGL PI. lINE 21. - 201. 6CI~.ED IN VERTICRL DEPTHS HORIZ SCALE = 1/200 IN/FT AOGCC GEOLOGICAL MATERIALS iNYENTORY L~ST o~)' WELL NAME /~/~' ,/'j-' ~ t_.J .?.~/....~'J CO. CONTACT ~ ~.~., check off or list data as it is received.~list received date for 407. if not uired list as NR drillinu histo,-v survey well tests core descri cored inl~crv~i~ core analysis ~v',~ dry ditch intervals di§itaJ data ...... ~ ~ ~_.~ ,, , i , n~, -rvn= i RUN "i~ ' , , ~ ............ INTERVALS ,[t,o,,thc nearest foot] ..... I [inch!lO0~] I 10I / / SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 JAN] 6 lggl CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 AHention:. Van ~ine~erger IILF..A~E REPLY TO $CHLUMSE~GER WELL SERWC£SPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed are_Z_BL_prints of the Gravel Pack Log, Run l, 1/13./91 Company CONOCO, Inc, Well Milne Point Unit H-4 Field Milne Point Additional prints are being sent to: I BI, prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 A~n: George Lamb - OF 2018 PER _ , on: County. North Slope , State Alaska ~rints, I RF Sepia C~N~C~. Tn¢~ · 1000 South Pine Ponca City, OK 74603 Attn: Glenn Welch 7~60R~W I BL prints, 1RF Sepia OXY U.S.A., Inc. _~._D_~ta Drive Midland., TX 79710 A~Cn: John Carrol *(915/685-5600) _l_Jlh_prints, I RF Sepia Chevron U.S.A. 11111 South Wilcrmm~ .... ~ Ho.~t~n~ T~w~ 77~qq Attn: Priscilla MacLeroy .'713/561-3652 ~l'~as~a Oil & Gas Conse~a~ion c~mmiSsion ' 3001 porcup±ne Dr~ve ~ Anchorage, AK 99501 ~,~'~ '~,. Attn: John Boyle ~??~'~' The film is returned to Conoco, Log LJbrary. prints Received by; Date: We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES David M, Saalwaechter DI~TR~CT M&NAGER SW.~-- ! 327.F SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 :JAN ! ~ 1991 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 A~ention: Van L~neberser ~F.J~E RElY TO SCHLUMBERGER WELL ~R¥1CES?ouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore_2_BL_prints of the Compony CONOCO, Inc. Well Milne Point Unit H-4 Tubing Puncher Rec, Run 1, 1/10/91 on: Field Milne Point/Schrader Bluff Additionolprintsore being sentto: I BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 At;n: George Lamb - OF 2018 PER ... County Morth Slope Stote Alaska _l_BL_prints, 1RF Sepia CONOCO; 1000 South Pine Ponca City. OK 74603 Attn: Glenn Welch 7~60RD~ 1BL prints, 1RF Sepia OXY U.S.A., Inc, . 5 Des~_a_.~_rAve . Midland, TX 79710 Attn: John Carrol *(915/685-56OO) _L_]LC_prints, 1RF Sepia Chevron_U.S.A. ~1111 South WJ]cremt. ~Hnumtnn¢.Tmwae 77~QQ Attn: Priscilla MacLeroy ~'713/561-3652_ 1 BL nrin[s,~.~l.,~RF~Sepl~.. Alaska "0~t~'~K-~~~t ion CQm~{ssion ~' ,'Porcupine Drive ~Attn: .John. Boyle. . Tke tilm i~ ~etur~ed We oppreciote the privilege of serving you. prints prints prints ReceJ ved by: Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M, Saalwaechter DISTRICT HANAGER SwS,-- 1327-F SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 JAN ! 3 ?gg? CONOCO, Inc. 3201 '"C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineber.ger ~$E REPLY TO SCHLUMBERGER WELLSE~ICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen* Enclosed ore_2_BL_prints of the, Packer Setting Record, Run 1, 1/8/91 Company CONOCO,, Inc, Well Milne Point Unit H-4 on~ Field . Milne Point/Schrader Bluff County .Nnrtb Slope Additional prints ore being sent to: I BL prints CONOC0, Inc. 600 North Dairy Ashford Houston,.TX 77079 Attn: George Lamb - OF 2018 PER . Stote. Alaska _l__~rints, 1 RF Sepia CONOCO~ T~c, 1000 South Pine Ponca City, OK 74603 Attn_: Glenn Welch 7~60_R~W. 1 BL prints, 1 RF Sepia OXY U.S.A., Inc. .,~ Desta Drive ...Midland,. ~X 7.9710 Attn: John Carrol *(915/685-5600) _l_Jlh_prints, I RF Sepia _Chevron U.S.A. 11111 South Wilcrm~r._ _ _Hnn~tnn: T~wan 77Aqq Attn: Priscilla MacLeroy ,~,713/561-3652 AlaSka Oil & G, as,,.Conservai~ff'~ ~,. "Commission 3001 Porcupine Drive Anchorage, AK 99501 ,~ ~k. Attn: John Boyle The film is returned to Conoco, Log Library. prints prints , , printsRFCE!VED 199! __ReceJ ved by; Date: We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER SWS-- 1327-F SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMB£RGER TE:CHNOLO~Y CORPORATION HOUSTON. TEXAS 77251-2175 JAN 0 3 1991 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van ~ineberger ~f.A~E REPLY TO SCHLUMBERGER WELL ~RVICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed are~rints of the Company CONOCO, Inc. Well Milne Point Unit H-4 Perforating Depth Control/GCT, Run 1, 1/4!gl on' Field ....Mi!ne Point/Schrad~_r Bluff Additional prints are being sent to: I BL prints CONOCO, Inc, 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb , OF 2018 PER County North Slope State Alaska _J~BL_prints, 1RF Sepia CONOCO, Tn¢. 1000 South PJne Ponca City, OK 74603 Attn: .Glenn Wel~h 7360RDW I BL prints, 1RF Sepia OXY U.S.A., Inc. ._6 Desta]~r~.x~___ Midland, TX 79710 Attn:.. John Carrol *(915/685-5600) _l_J~rints, I RF Sepia Chevron U.S.A. . 11111 South WJlcrast_ _ _ Hnl],~t art; Tmw~_~ 77r)qq Attn: Priscilla MacLeroy ,~.~13/~61-3652 as~a 051 ~ Gas Conserva~on .. Commas sion' ~ 3001 Porcupine Drive ) .. Anchorage' .~ . 99501 ... / ~A~: John Boyle ~ The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. . prints ,_ prints prints RECEIVED JAN 14 1991 Alaska 0ii & Gas Cons. Commission Anchorage Received by: Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M, Saalwaechter DISTRICT MANAGER SWS-- 1327.F co c, Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 January 2, 1991 Mr. Lonnie C. Smith Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Milne Point Unit Well H-4 Application for Sundry Approvals Dear Mr. Smith: Attached is the Application for Sundry Approvals (Form 403) requesting approval to complete the MPU well H-4. If there are any questions pertaining to this well please call me at 564-7625. Very truly yours, C. Van Linebe Sr. Production Engineer CC: CVL, PMS, Sr. Production Foreman, H-4 Well File RECEIVED i ' STATE OF ALASKA ALASKA OIL AI~ID GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Alter casing Repair well Change approved program Operation shutdown.... Re-enter suspended well Plugging __ Time extention m Stimulate X Pull tubing_ Variance Perforate X Other X 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 200 Anchorage, AK 99503 4. Location of well at surface 2369' FNL, 4019' FEL, Sec. 34, T13N, R10E, U.M. At top of productive interval 1704' FNL, 3753' FEL, Sec. 34, T13N, R10E, U.M. At effective depth 5. Type of Well: Development X Exploratory . .. Stratigraphic Service NSB AK NSB AK At total depth 1602' FNL, 3721' FEL, Sec. 34, T13N, R10E, U.M. NSB AK 6. Datum elevation (DF or KB) KB 35' AGL feet 7. Unit or Property name Milne Point Unit 8. Well number H-4 9. Permit number 90 -89 lO. APl number 50-029-22064 11. Field/Pool Schrader Bluff 12. Present well condition summary Total depth: measured true vertical 4472' feet 4345' feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Structural Conductor 115' Surface 2562' Intermediate Production 4472' Liner Perforation Depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size 13-3/8" 9-5/8" 7" Cemented Measured depth True vertical depth Sudace 115' 80' Sudace 2562' 2521' T.O.C.@3000' 4472' 4345' RECEIVED JAN 0:~ 1991 ~.&, Gas Cons. ~cafnml,~l)n '' ~chorag~ 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 1/2/91 16. If proposal was verbally approved Lonnie C. Smith Name of approver 1/2/91 Date approved 15. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certif~ that the foregoing is true and correct to the best of my knowledge. Signe . -- C. Van Lineberger Title Sr. Production Engineer FOR COMMISSION USE ONLY Date 1/2/91 Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- JApproval No. ~/_ (~(;:= / Approved by order of the Commission Commissioner Date Form 10-403 Rev O6/15/88 SUBMIT IN TRIPLICATE MILNE POINT UNIT I{-4 WELT, PROPOSED COMPLETION PROCEDURE - SUMMARY 1/2/91 - CVL NOTE' · Hold frequent on site safety/environmental meetings prior to all potentially hazardous tasks. 1. MIRU on H-4 well. Test BOP's. 2. GIH w/ bit and scraper to PBTD. Reverse circulate well clean. 3. RU electric line. Run Gyro survey. Correlate with open hole logs and perforate "0" sands at 5 SPF over 4208'-40' and 4274'-88'. RD electric line. 4. GIH with squeeze packer and set above top perf. 5. MIRU frac equipment. Pressure test all lines. Pump frac job to stimulate "O" sand perf's. RD frac equipment. 6. Clean out proppant from wellbore, if necessary. 7. RU electric line and set gravel pack sump packer above "O" sand perf's and below proposed "N" sand perfs. 8. Perforate "N" sands at 12-24 SPF over 4086'-99', 4111'-18', and 4134'-54' utilizing electric line or tubing conveyed perforating (TCP). If TCP is used, apply 300 psi underbalance and allow well to flow for approximately 20 bbls. Kill well and POOH. 9. PU gravel pack assembly and GIH. pumps/blenders and test surface lines. packer. RU gravel pack Set gravel pack 10. Pickle workstring. Establish injection profile. Pump gravel pack. Stress test gravel pack and POOH. 11. PU and run electric submersible pump (ESP) on tubing. Freeze protect. ND BOP's and NU tree. 12. Leave well shut in until surface equipment installation is complete. sC~. V~nro~n~bn~in~er October 19, 1990 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 Lonnie C. Smith Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-1433 RE' Milne Point Unit Well H-4 Application for Sundry Approval Attached is the Application for Sundry Approval (Form 403) requesting approval to shutdown operations on MPU well H-4 with rig 27-E, pending completion with rig EWS 4. If there are any questions pertaining to this well please call me at 564- 7637. Very truly Yours, R. S. Rossberg Sr. Drilling Engineer cc' MPS file # 500.21.08 Oil & Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator Conoco, -rnc. 3. Address 99503 3201 C Street, Suite 200, Anchorage', AK 4. Location of well at surface 2369' FNL, 4019' FEL Sec. 34 T13N Attopofproductiveinterval ' ' ' 1704' FNL, 3753' FEL, Sec. 34, T13N, Ateffectivedepth Attotaldepth 1602' FNL, 3721' FEL, Sec. 34, T13N, 5. Type of Well: Development Exploratory Stratigraphic Service RIOE, U.M., RIOE RIOE NSB, AK 6. Datum elevation(DForKB) KB 35' AGL Z UnitorPropedyname Milne Point Unit 8. Welt number H-4 9. Permit number 90-89 10. APl number 50-- 029-22064 11. Field/Pool Schrader Bluff feet 12. Present well condition summary Total depth: measured true vertical 4472 4345 feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Structural Conductor 115 ' Surface 2562 ' Intermediate Production 4472 ' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size 13-3,/~8'' 9-5/8" 7" Cemented Measured depth True vertical depth Surface 115' 80' Surface 2562' 2521' T.O.C. @3000' 4472' 4345' 13. Attachments Description summary of proposal __ Detailed operations program __ Shut down operations ~±th ~±§ 27-E pend±ng couplet±on. BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: 12/90 16. If proposal was verbally approved Oil X Gas __ Name of approver Date approved Service 17. I hereby certify that the foregoing is [rue and correct to the best of m,¢ knowledge. ~.. / Signed ~ ~-¢~'/~ ~-- Title Sr. Drilling Engineer Steve Rossberg - ~/ FOR COMMISSION USEONLY Conditions of approval: Notify Commission ~'o representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- /~'~ ~7 ORIGINAL ~IGNED §'f Approved Copy Returnl~d LONNIE C. SMITH I()! ~'! ~,..~_ Commissioner Approved by order of the Commission Suspended __ Date 10/19/90 Approval Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 7725 1-2 I 75 PLEASE REPLY TO SCHLUMBERGER WELL SERVICES OCT ! 9 1990 Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberser Gentlemen: Enclosed are 2 BI. prints of the Company CONOCO, Inc, Well Milne Point Unit H-4 Field Milne Point DITE/NGT/Porosity/Raw Data/Cyberlook, Run 2, !0/!5/90 .County_ North Slope , State Alaska Additionalprintsare being sentto: I BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 A~tn: George Lamb - OF 2018 PER _ ~rints, 1RF Sepia CONOCO= ThC, 1000 South Pine Ponca City, OK 74603 Attn: Log Library on: 1 BL prints, 1 RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 797_10 At,n: John Carrol * ( 915/685- ~600) ~rints, 1 RF Sepia Chevron U.S.A. 6001Bollinger Canyon Road _San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy *(415/842-1000) 1BL nHdts, F'Sepia ~-'~ AlaSka Oil & Gas Conservatio~ ,,, Commission 3001 Porcupine Drive Anchorage., AK 99501 Attn: John Boyle.. · The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints _ prints prints _ ~ece~ved by: .Alaska 0il ~ ~s ~'2' Yew truly yourS, SCHLUMBERGER WELL SERVICES SwS-- ! 327-F David M, _Saalwaechter DII~TR ICT MANAGER July 27, !990 Telecopy: (907)276-7542 David L. Mountjoy Sr. Drilling Foremmn Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Re: Milne Point Unit No. H-4 Conoco Inc. Permit No. 90-89 Sur. Loc. 2369'FNL, 4019'FEL, Sec. 34, T13N, R10E, UM. Btmhole Loc. 166I'FNL, 3693'FEL, Sec. 34, T13N, R10E, UM. Dear Mr. Mountjoy.. Enclosed is the approved application for permit to drill the above referenced Well. The pe~t to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Very t~ly yours, Commissione%oz Alaska Oil a~d Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA" STATE OF ALASKA AND GAS CONSERVATION C( PERMIT TO DRILL Re-Entry _ Deepen 20 AAC 25.005 AISSION lb. Type of well. Exploratory ,~ Stratigraphic Test ~ Development Oil Service _3 Developement Gas ;-- Single Zone/~ Multiple Zone~ 2. Name of Operator CONOCO TNC. 3. Address PA.ch 341304~_ P~'.dhn~ Bay.. Al( 99734 4. Location of wel'i at surface 2369 FNL, 4019' FEL, SEC. 34, T13N, R10E At top of productive interval U.M., NSB, AK 1850' FNL, 3780' FEL, SEC. 34, T13N, R10E At total depth . 1661' FNL. 3693' FEL, SEC. 34, T13N. RIOE 12. Distance to nearest I 13. Distance' to property line 3430 'FSI feet 60'F/H-3- e 500' fee' 5. Datum Elevation (DF or KB) KB 35' AGI feet 6. Property Designation ADL-2.~906 7. Unit or property Name HTINF POTNT UNTT 8. Well number H-4 9. ApProximate spud date SEPTEHBER 21, 1990 i~;.'NU'imber of acres in property' 2560 44 10. Field and Pool KUPARUK RIVER FIELD 11. Type Bond (seo 2o AAC 25.025) BLANKET Number 8086-15-54 Amount .$200,000 15. Proposed depth m~o ~r,d TVD) 96' HD. 4386' TVD~et 16. To be completed for deviated wel[s ..:i"..i'.':' ..... ,.';" 17.'"Anticipated pressure (see 20 AAC 25.035 Kickoff depth 1500 feet Maximum hole angle.17 0 Maximum'surface 1900 psig At total'depth fTVD) 2000 ps~g 18. Casing programI ........... J ................ ...... Setting Depth size I Specifications ......... [ ................. Top Bottom Quantity of cernent Hole 8.5 C°upling"" 1 Length' I~11='1 n I ¢~, BTRS' ~461' .... (include stage data) LA~K CL/C DI:DM~,I:'DI't~T P , , vv v, .~v· kltl II 1..lvv I v 19. To be completed for Redrill, Re-entry, and Deepen O'~b'i~'~.'t'i~h'~, ...... Present well condition summary Total depth: feet feet measured true vertical ~57~ SKS PERMAFROST E ~2fi9 SKS CRASS G ~40 SKS PERMAFROST E -264 SKS CLASS G Plugs (measured) Effective depth: measured feet Junk (measured) true vertical feet DOWNSQUEEZE _+273-SKS PERMAFROST C +60 BBLS DEAD CRUDE Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length r Size .,:. Cemented Measured depth True Vertical depth L UL i 11990 measured ~J~Sk~ 011 & Gas Co.So ~BIOS;,',.;~ true vertical ' -~ ~Oh0fa~" PIT SKETCH X 20. Attachments Filing fee~ Property plat~ BOP Sketch~ Diverter Sketch~ Drilling programX_: Drilling fluid program~ Time vs depth plot~ Refraction analysis ~ Seabed report ~ 20AAC25.050requiremonts~ 21. ! hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~. .~,~~~,¢/~.v.~-'~'~~ '~," T tie SR. DRILLING FOREHAN - '-'~'~'-~'~":; " -- ~" '/"~-'~)mmission Use Only '~ - ~¢ 50--oz. ~- ~- 2 cD ~- z/ 07/27/90 Conditions of ~pproval Samples requ_ir,ed ~ Yes '~No Mud log requ~re~ :2} Yes ,,~No Hydrogen sulfide measures ~ Yes ,,~ No Directional survey required ~,Yes ;£ No Required working pressure for DOPE ¢2M; E~ 3M; ~ SM; [] 10M; ~ 15M Other: b~---~¢% j:, _._.~~ ------~. by order of Approved % Commissioner the commission Form 10-401 Rev. 12-1-85 Date See cover letter for other requirements Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT H-4 Conoco Inc. P. O. Box 340045 Prudhoe Bay, Alaska 99734 I. Casing and Cementing Program ae The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ±485 sacks of Permafrost Type "C". Be The 9-5/8" surface casing will be cemented with ±572 sacks of Permafrost "E" cement followed by ±259 sacks of Class "G" Cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±40 sacks of Permafrost "E" cement pumped around the casing shoe followed by ±264 sacks of Class "G" cement. The secondary cement job will consist of +273 sacks of Permafrost "C" cement followed by ±60 barrels of Arctic Pack pumped down the 7"x 9-5/8" annulus. II. Drilling Fluid Program ae 0' - 2528' 9.0 ppg freshwater spud mud. B. 2528' - 3770' 9.2 ppg low solids non-dispersed. C. 3770' - TD 9.4 low solids non-dispersed. III. Drilling Program Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River Field (Upper Cretaceous-West Sac). The mud system will be low solids, non-dispersed with a mud weight in surface hole of 9.0 ppg. Mud weight at TD will be 9.4 ppg. A 20", 2000 psi diverter will be installed on the 13- 3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. BOP's, choke manifold, upper and lower kelly safety valves will be tested to 500 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is H-3 with a closure of 60 feet at a depth of 500'. The well will not be completed or tested at this time. ae Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Be Drill a 12-1/4" surface hole to ±2500' TVD 2528' MD and set 9-5/8" casing. Ce Drill a 8-1/2" production hole to ±4368' TVD to 4496' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YD PV VIS FL 0 0 Gravel 1-1-4 9.0 32 20 90 15 500 500 Sand/Clay 1-1-4 9.0 25 20 65 15 3440 3509 "K" Sand 1-1-4 9.2 25 15 35 10 3690 3770 "M" Sand 1-1-4 9.4 25 15 35 10 3912 4001 "N" Sand 1-1-4 9.4 25 12 35 05 4086 4183 "O" Sand 1-1-4 9.4 25 12 35 05 4386 4496 TD 1-1-4 9.4 25 12 35 05 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. 3.]. I II I --Imm _ -- _ II II NOTES: 1, -""STA?E PLANE COORDtNATE`S ARE ZONE 4 2, ALL GEODETIC PO`SITION8 ARE BASED ON N,A.D. 1927 OFF,~ET$ TO ,SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE ,~ECTION CORNER POSTtON8 290' 30' 40' H PAD II III LOCATION IN SEC. WELL H-'I H-2 H-3 H-4 MILNE POll,IT UNIT ,/ MILNE PT, VICINITY MAP 0 6 ~ MILES 34, T13N, R1OE, UMIAT MERIDIAN FROM EAST LINE FROM NORTH LINE 4070, .... 2~42. ' 4055' 2484' 4036' 2426' 4019' 2369' STATE PLANE COORDINATES-ZONE 4 WELL H"'I H-2 H-4 Y 6,OO9,889,28' 6,OO9,947,O4' 6,O10, OO4.80' 6,O10, O62.66' X 586,676.42' 556,~92,64' 556,608.85' 556,625.07' GEODETIC PO$1TION$ NAD 1927 WELL NORTH LATITUDE 70* 26'15.6012' 70' 26'16,1680' 70* 26'16.7350' 70* 26'17,3019" WEST LONGITUDE · 149' 32'19.3,O9" 149' 32'18.820"' 149' 32'18,331' 149' 32'17,843' TYPICAL SECTION~ ' ' NO ~c',',t. ~ ~.0../ CHECKED ¢IELD BOOK 3CALE 1',2OO' JOB HO. 87033 _ _ ' -- _ III .. -~ _ ~1 _ III I~ .. I I J III T 13 N R 9 E T 13 N R 10 E T 13 N R 11 E MILNE POIN'i c~v"°" - -(~' co.oco ET ^,. ~ CONOCO ~T ~ m Unit Boundary [ ~-255~2533~C ADL-47434 2S.OAC ADL 47433 2 ~RON ~ ~ CH~R~ CHEVRON 1 23 24 lg 20 ~ 22 23 24 18 2~ 21 22 ADL-25516 4D~-.I.646 1250 AC ADL-4?43T 25~0 ~-25~14 25~0 AC ADL-25515 2~4 AC ~26o Ac .......... 30 2~ 28 2T 26 . EXt $1 3 $3 34 Baled on Uml. 35 36 31 32 Mllee O A~-25517 ~ III 223SAC ~DL-25~ 2560 AC AOL-2SSla 2560AC ADL-28231 ~55 4C , UNIT flumbefa 35.744 AC~' -~, .. 6/84 40 BIT A ~INT UNIT AREA Metldlln,Alalll I 2 Scale iii i CH~¥o · OHIO CONOCO INC,--NAB©ES RIO 27E 3-5/8" 56088 BOP Fill Llne AFI 13-5/B' ~1 APl 13,-~¢1~' 5t4 APl 13-5/8' APl 1~-~,~' ~ x 11" ~1 ,APl 11' 5M TI'~e~led Comection Flow Line Annular Preveqtgr Ram Rom C'hoke Line, 3" 5000~ Hanua[ & 3" HCR VALVE Kill Line, Two 3" 5000~ Hanuat Valves Rom Tubing Spool w/ 2"-5000~ Side Casing Spool w/ 3"-5000~ Side 9-5/8" SurFace Outlets Outlets Co~;lng 13-3/8" Conductor Casing SYSTEM Valve Gate l, BOP STACK SIZE RATING HEETS AP] RP53 & SPEC 6A FOR CLASS 5H 2, BOPE TO BE OPERATED EACH TRIP AND TESTED WEEKLY, 3, BOP HYDRAULIC CONTROL SYSTEH TO INCLUDE (5) STATION CONTROL HANIFOLD LOCATED REHOTE WITH 160 GALLON ACCUHULATOR, RESERVOIR UNIT, & AUXILIARY ENERGY SOURCE FOR S¥STEH AC TI Y AT _I O N, ~r, HINIHUH ONE SET BLIND RAHS & TWO SETS APPROPRIATE PIPE RAHS, 5, CHOKE & KILL MANIFOLDS SHOWN SEPARATELY TO MEET APl RP 53 CLASS 5H REOU]REHENTS, KILL MANIFOLD FROM REV, OT£ HIGH PRESSURE PUMP NOTE: !. H~R~ULI¢ CONtROl STST£W FOR BOP STACK 8 S/A ~NTROL ~AklF~ PLUS VARIABLE CHOKE ~ s~s. S. KILL UANIF~O SIZE- RATING Z'- 5~0 ( CHOKE WANIFO~ SIZE - RATING 5'- 5~0 R[VIOTE PRESSURE GZ,,SE SENSC~ HY[~R~ULIC CONTROLLED RE~,OTE OPERATED DRILLING SPOOl. HYDRAULIC CONTROLLED REMOTE OPERATED REMOTE PRESSURE GAGE SENSOR CHOKE ADJUSTABLE ADJU~ABLE MANIFOLD CHOKE · ___...TO SHALE SHAKER I 1 BLFFD LINE TO ATV, OS?HERIC TO PIT ~,UD/GAS SEPARATOR CHOKE & i</LL ~,ANIFOLDS FOR ctS?8'~ 8 7" OD CASING P~OP STACK BOP I,!ANIFOLD LAYOUT - CONOCO, INC. , CONOCO, INC. MILNE POINT UNIT DIVER"rER S.rACK FOR 13 3lB* CONDUCTOR 1. The hydraulic control syste~a will be in accordance with API specifications and ~ requirements. 2. The HCR valve will open when thg preventer closes. A single I0" pelief line will pun off of the drilling spool HCR valve and will have a targeted downstream tee for downwind diversion. Valves on both sides of the tee will be full opening and linked together to enabl~ one to always be open and the other to be closed. · MUO TROUGH i I MU0 CL[AN£R PlJId~$ W&T[R ~ FILl.. PU~P ' I I MiX) il, j[ HO~R$ i FUkI~ PUM.O2 I. !:c~ r.;D : (~ AGIFAT(~ NABORS D~LL~G LI:z~TED A~.E£r~TA .__~_ ,2,~__~ ~8: "ZZ ~'w"__Z . FLOw SHEET ~ELSEN INOUST~E~ LTD, __ _ WELL NAME: MPU ~4 ...... · 12-Jan-90 CONDu, CTOR SETTING DEPTH: SURFACE CASING SETTING DEPTH: INTERMEDIATE CASING SETTING DEPTH: PRODk~CTiON CASING DEPTH (OR TD): 8O 4496 DEPTH OPERATION: 0 1 RIG MOVE: ~ RiG-UP, SET CONDUCTOR: (2,528) 3 DRL/SURVEY SURFACE HOLE: (~,528) 4 SURFACE HOLE LOGGING: ~z,o~o. 5 CONDITIONING TRIP: (2,528) 6 RU/RUN SURFACE CASING: (2 528) 7 RU/CEMENT SURFACE CASING: (2,528) 8 CHNG BOPs~- PU BHA~ RIH: (2,628) 9 DRL OUT;. TEST; TOOH~. RIH: (o 628) 10 DRILL INTERMEDIATE HOLE: (~,628) 11 LOGGING OPERATIONS: (2,628) I'~ CONDITIONING TRIP:. (2,628) 13 RU/RUN INTERMEDIATE CASING: CUM HOUR DAYS DAYS 6 0 ~ 0 25 12 0.50 0.75 45 1.85 2.60 0 O. O0 2.60 3 0.11 2.71 9 0. Z~8 ~.'~-. 09 6 0 25 '~- 34 9 0.36 3.70 9 ~-~. 37 4.06 0 O. 00 4.06 0 0.00 4.06 0 0.00 4.06 0 0. O0 4.06 O. oo 4. oa 0. O0 4.06 0.00 4.06 i. 82 5.89 0. O0 5.89 0. (-~0 5.89 8 0.35 6.24 14 0.57 6.81 4 ¢-~. 19 6.99 12 O. 50 7.49 12 O. 50 0.50 i-.- ~ 0.5("~_ 1. O0 · -' 0 50 I 50 (2,628) 14 RU/CEMENT INTERMEDIATE CASING: 0 (2 628) 15 CHNG BOF's; PU BHA; RIH 0 (2,628) i6 DRL OUT; TEST; TOOH; RIH 0 (4,496) i7 DRILL PRODUCTION HOLE: 44 (4~496) 18 CORING OPERATIONS: 0 (4,496) 19 LOGGING OPERATIONS (MWD ONLY): 0 (4~496) 20 CONOiTiONING TRIP: (4,496) 21RU/RUN PRODUCTION CASING: (4~496) 22 RU/CEMENT PRODUCTION CASING: (4~496) 23 RD DRLG RIG (4~496) 24 RU COMPLETION RIG: (4~496) 25 RD DRLG RIG (4,496) 26 RU COMPLETION RIG: (4,496) 27 RI) DRLG RiG (4,496) 28 RU COMPLETION RIG: ~4,' 496~. ~,~-~ RD DRLG RIG (4,496) .5]0 RU COMPLET .T_ ON R!G: -..,,,' (...IUIJ %., '% I T I i I ?,..' .5 4 [3t~IlI_LIh4C~ L,, ~ :':, CONOCO, ]: no. Pad H, Well No~ 4 HI Ins Point Unit, Revised Proposal North Slope, Alaska 0 _ RKB ELEVATIO#~ 3~' :::13 c; 1 000 _ 2000. . :3000 _ 4000 KOP TVD=!500 TMD=1500 DEP=O BUILD 3 DEO PER 100 FT EOB :VD-204Z THD=2055 DEP-80 .... 9 $/8 CSG PT TVD=2500 THD=2528 DEP=215 AVERAGE ANGLE 16 DEG 39 HI N 5000 0 1000 VERTICAL SECTION HORIZONT^L PROJECTION SCALE 1 ]:N. = 500 FEET CONOCO. !hQ. Pad H, We I I No = 4 Rev I aed Propoaa I HI Ins Point Unit, North Slope, Alaska z 1000 1 500 1000 _ SURFACE LOCAT! ON' 2369' FNL. 4019' FEL SEC. 34. TI3N, RIOE 500 _ ....................... $00 SO0 WEST-EAST 0 $00 I I / $~,^0~ ( ) N 24 DEG 44 MINE 571 ' (TO TARGET) 1000 TD LOCAT ! ON ' 1661' FNL. 36g,3' F'EL SEC. 34. Tt3N. RIOE TARG'~T / N SNDS TVD=36gO TND-3770 DEP=SZ1 NORTH $19 EAST 239 TARGET LOCAT ! ON, I GSO' FNL. 37'80' F1EL SEC. ,34. T13N. RIOE 2250 _ 2300 _ 2350 _ 2400 _ 2450 _ ; 2500 _ Z550 _ !600 _ :650 _ 4150 4100 4050 I I I i 4150 4100 %. %. i 4050 4000 / / I / / / ~2100 / / 700 500 '~ @oo "1400 3950 3900 I 3850 I _ 225C : I _ 230C I _ 2350 I L__ I _ _ -q !~'~~L 2400 _ 2450 I I I _ 2500~ I '~1~00~-~ 1~!~_ 2550 %. %11 oo %. %, 4000 I 3950 3900 t 3850 26O0 2650 (2 thru 8) (8) (3) Admin ffP~- 'C~ ~. ~.=u (ZO ~d L3) (4) (14 thr~ :22) (23 thru 28) YESNO .......................................... ...... ., ~s 2. Is well to' be located in a defined pool ............................. 3 Is well located proper distance from property line ..... 4 Is well located proper distance from other wells ........ 5 Is sufficient undedicated acreage available in this pool 6 Is well to be deviated and is we!lbore plat included ... 7 Is operator the only affected party ......... ~ .......... 8 Can permit be approved before fifteen-day wait ......... 9. Does operator have a bond in force .................................. ,,/~ 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ................................... 12. Is the lease number appropriate ..................................... ~ 13. Does the well have a unique name and number ......................... -/ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. !s cdnductor string provided ........................................ Wi!l surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover ail known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an emisting we!lbore ............. Is old weilbore abandonment procedure included on 10-403 ............ Is adequate weilbore separation proposed ............................ Is a diver=er system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. ,~ , ,, Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ............................. ~... ,,, ,..5"'o0" (29 thru 31)' Geology~ Engineering: ~.~ DWJ ~ LCS BEW ', rev: 01/30/89 6.011. · For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INIT'~L GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,, , Additional Re~arks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. * AbASKA COMPUTING CENTBR ~mmmmmmm~mmmm~mm~mmm~mm~mm~ comPAnY wA.E : CONbC~] INC. wELL NAME : ~IbME POINT UNIT FIEbD NAME ~ SCMPADFR BLUFF eomou~ : ~O~T~ STATE : ALASKA API NU~BMR : 50-0~9-~2064 ~EFE~EMCE NO ~ 93101 MIi I OFI[MED a i0 ~"1 .... ~ ~- / ...... /oo, ~hl~;~bet'ger AlaSka ComPL~t~nO Center 9-~AR-1993 09~01 PAGM: **** REEl.. NEADRR [)A'rF ! 91/03/~7 O~ICI~ : wLIC CONT!~tIATIOH # ! Cn~4~'EWT : CONOCO, SCMRADER BLUFF,MILNE POINT UNIT H-4, 50-029-22064 **** TAPE HEADER SFRVICE NAME : EDII ~&T~' t 91/03/17 OPIG,[N ! WbIC TAP~ NA~E : 7415~ C~NTIN[.I~T!~ # : 1 PREVIOUS TAPE CO~uE~T : CONOCO, SCHRADER BLIIFF,~!ILNE POINT UNIT H'-4, 50-029-22064 F~L~ NA~E : EDIT .00! VPRgIOM ! 00!A06 D~T~ ! 9~/03/~7 ~AX ~EC S~Z~ FIL~ TYPE : LO L~ST FILE CO~PAN¥ NAM~: CONOCO !NC. ~F[,b: ~ILN~] POINT UNIT H-4 F?ELD! SCHRADER BL[.IFF S~'ATE: APl N!I~BEP: 50-029-2~064 2369' ~N[, & 40!9' FEL 34 TOWNSHIP: 13N ~ANGE: ]..OE MS[., ELEVATION: 0' -h]umber'.~er Alaska ComP,]tino Center ~-~AR-1993 09:01 k~!,EYAT!ON$ KS: 7~' DF: 70,5' GL: 37' DaTE Tn DRTL~EP: 16-0CT-1990 4496' ~490' CaSI~;C,: 9 5/~" (~ .~RII~I.,~.;~ DEPTH OF 2562' AI,!~ LOGGER DEPTH Or 2568' ~TT SIZE: .R 1/2" Tvp~~. FLUID Tr'~ }-{D[.,F.j: [.,OW SOb]DS - [.,IG['ITLY DISPERS~D ~: 9,6 FLUtD LOSS! 5 ~,1!JD ~E~,~TSTIVITY~ ~T!.,TRATE ~ESISTIVITY: ~{~ C~ RESIST'IV!TY: 2,89 m 69 2,62 m 65 3,27 m 68 TII{F CIRCULATIOn! ENDED: 20:00 16-OCT 'F!~U [.,O~GER Or4 BOTTOM: 00117 17-0CT ~AXI~L;~ TE~P ~ECO~DED: 96 DISTRICT: F~IGIMEE~?: BAY /~OI;NTjOY TOF![~ NL~BERSI TC~-AB t07 TCC-A 123 CNC-Hn 1675 DP$-C 4847 DIS-[]C 276 AMM-AA 724 N~D-B 739 M$C-E 760 DIC-EB 271 .4" TErLO~,~ STANDOFFS AND ~.CORN BOTTO~ NOsE USED ON THE TOOL T[{ING, DENSITY NEU'~r~N MATRIX'= SA~6, HOLE CORRECTif~ = C~LI. ' TIED t~-;TO SURFACE RUN: BGT-GR, PAGEt cn~r~i.!TT~;G CENTER AKCC P}~$OR PROCESSED ENHANCED RESISTIVITY [~ATA ALS[] INCLUDED ~b~ THIS LIBRarY TAPE: IDP~,[~$= UPGRADED P[iASOP ILl) F~ES~STIVITY IDK!~,PHS= EN%~A~CED ~ESOT.~UTIO~} PHASOR TLD ~ESISTIVITY IDVR,PHS= VERY E~!ANCED R~SOL, UTIf]N PHASOR I[~O RESTSTIVITY ~GT L)ATA IS FILTratED USI~G LEAST SOUARES ~JO~ R~FM~E~CE NO: 74151 T.,DP/A ~3 A: Ver).ftcation Llst~no AlasKa ComPutlnO Center 9-~A~-1993 O0:Oi PAGe: FILM - EDXT.O0! CONOCO INC. SCHgADER ~LUFF MILNE PO~.T UNIT M-4 50-0~g-~2064 DTE/bDT/CUL/NGT DaTa FROM MAIN PASS FIELD FILE .004 PAT5 SA~PI, ED ~VERY -.5000 FEET DATA INCL~DED- TOOt, EXTEgSION ToOL TYPE USED N~E DIT-E .DTE D!T-E .PHS [,DT .L~T CMT-A!DI~ .CNL M~T ,NGT PgASOR DUAL INDUCTION SFb 4482' TO 2567' EgHAMCED DHASOR PROCESSING ILD 4482' TO 2567' LITHO DEMSITY 4466' TO 2567, COMPEN$.ATED NEUTRON 4454' TO 2567' NATURAL G~A SPECTROSCOPY 4426' TO 2567' ****************************************************************************** ** DA~A FnR~AT SP~iCIF!CATI~N PECO~D ** ** SET TYPE - 64EM ** ''''''''''''''''''''''''''''''REP. CODE VALUE l 66 0 2 66 0 3 73 312 4 66 .~ 5 66 6 73 7 65 ~ 68 0,5 ': 65 FT ~ 66 26 12 68 13 66 0 1 ~ 65 FT IS Tape verification tt. stj. nq shl!lm~'er-qer Alast<a ComDt!tino Center 9-MAR-1993 09:01 ............... · 66 {666 1 0 66 0 1T,,u, IDPH DT~ IFR~ I DOF I~or OTE CI~P I:~RP I tRu C~ TENS DTE 'I DP~.~ I h~ PHS DPH T t,DT RWOA DPNO [,DT P E F L l) T OL, S bDT OSS LDT bS LDT L U b;, I, 1 'r u L D T SSI bDT SS2 LDT I, SHV LOT SS~V S~ ~ t, DT bi,IR ~ bDT CaLl UHM~ 540084 O0 OH~H 5490g4 O0 MV 54~084 90 0~ 5490~4 O0 O~W~ 54908A 00 HZ 54qog4 O0 5490~4 O0 ~4q084 00 Mf4HO 54.90~A O0 ~Hn 549084 O0 ~HO 5490~4 O0 ~MHO 540084 O0 ~HO 54q0~4 oo GAPI 5490~4 00 GAPI 549084 O0 L,B 5490~4 O0 DEGF 549054 O0 t,a 54~0~4 OO 0~ 549084 O0 OH~M 549084 O0 PU 549084 ~/C3 5490~4 00 G/C3 5490a4 O0 5490~4 O0 5490~4 00 5490~4 O0 CPS 549084 00 CPS 5490m4 CPS 54qOR4 O0 CPS 5490~4 O0 CDS 5490a4 O0 CPS 549084 O0 V 5490§4 O0 V 549084 O0 G/C3 5490~4 O0 G/C3 54908~ O0 G/C3 549084 O0 tN 549084 OO 000 O0 000 O0 000 O0 nO0 O0 000 O0 000 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 OCO O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 00' 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 OOO O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 0 1 1 1 4 68 0000000000 0 1 1 t 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 ~ 4 68 0000000000 0 1 1 1 4 68 0000000000 0 t 1 1 4 68 0000000000 0 ! 1 1 4 68 0000000000 0 I 1 I 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I 1 I 4 68 0000000000 0 1 I 1 4 6e 0000000000 0 i I ! 4 68 O0000000OO 0 1 1 1 4 6~ 0000000000 0 1 1 I 4 68 0000000000 0 1 I I 4 68 0000000000 0 1 I 1 4 68 O00000nO00 0 1 1 1 4 68 O00OO00000 0 I 1 1 4 68 000000000,0 0 1 1 ! 4 68 0000000000 0 1 1 1 4 68 0000000000 0 I 1 1 4 68 0000000000 C) i 1 1 4 6~ 0000000000 0 1 I 1 4 6~ 0000000000 0 ! I 1 4 69 0000000000 0 I 1 I a 68 0000000000 0 1 i 1 4 68 0000000000 0 I 1. 1 4 68 0000000000 0 1 1 1 a 6~ 0000000000 0 1 I ! 4 6~ 0000000000 0 1 .1 1 4 68 0000000000 0 1 I 1 4 6~ 0000000000 0 l ! ! 4 6~ 0000000000 0 I ! 1 4 69 0000000000 0 1 1. ~ a 6~ 0000000000 0 ! 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 1 1 1 4 68 0000000000 0 i I 1 4 68 O000OO0000 0 I 1 1 4 6~ Or)O0000000 0 1 1 1. 4 6~ 0000000000 0 1 1 1 4 68 0000000000 Veri f..icat ] on LI st'inq Alaska Computing Center g-,AR-1993 09:01 PAGE 'ID [)RDEP ~ bn~ TYPF CI,~SS MO CGR bDT GaP! 549084 O0 000 O0 0 TFN$ LDT {,R 549084 O0 000 O0 0 MTE" I,DT DEGF 549094 O0 000 O0 0 MPES LDT OMM~ 549094 00 000 00 0 HTEY LI)T LB 549004 O0 000 O0 0 NUHT CNL PU 549084 O0 000 O0 0 TNPF CNL PU 5490~4 O0 000 O0 0 T~R~ CN5 549084 O0 000 O0 0 NPO~ CNL PU 540094 O0 000 O0 0 ~CNT C~L CPS 549084 O0 000 O0 0 ~CFT C~L CPS 549094 O0 000 O0 0 C~T~ CNL CPS 5490~4 O0 000 O0 0 CFTC CNU CPS 549084 O0 000 O0 0 SCR C~L GaP! 549094 O0 000 O0 0 CGR ClVL GAPI 549084 O0 000 O0 0 CSLT CNL IN 549084 O0 000 O0 0 TFN$ CNb LF 5400~4 O0 000 O0 0 MPE$ CNL [)r~M~ 549084 O0 000 O0 0 ~Eu CNb DEGV 549084 O0 000 O0 0 HTE~ CNL bB 549094 O0 000 O0 0 SC~ UGT ggPl 549084 go 000 O0 0 CGR ~GT GAPI 549084 O0 000 O0 0 T~[]~ ~T PPM 5490~4 O0 000 O0 0 POT~ ~GT P}..I 549084 O0 000 O0 0 !,!~AN NG~ PP~ 549084 O0 000 O0 0 wl~C ~? CPS 5490n4 O0 000 O0 0 W2NC NGT CPS 540084 O0 000 OO 0 W]N~ NGT CPS 549084 O0 000 O0 0 W4N~ NGT CPS 5400~4 O0 000 O0 0 WS~C NGT CPS 540084 O0 000 O0 0 TFNS ~GT L,B 549084 O0 000 O0 0 ~TEu NGT bEG? 54908~ O0 000 O0 0 ~P~ NGT ONMM 549084 O0 000 O0 0 CS ~GT F/N~ 549084 O0 000 O0 0 NTE~ ~GT LB 549094 O0 000 O0 0 I 1 1 4 6~ 00000 ! 1 1 4 68 OOOO0 1 1 I 4 6~ 00000 I I 1 4 68 00000 I 1 1 4 68 00000 i 1 t 4 68 00000 1 I !1 4 68 00000 1 1 ! 4 68 00000 1 1 1 4 68 00000 1 ~. 1 4 68 00000 1 1 1 4 69 00000 1 I 1 4 68 00000 i 1 ! 4 68 00000 1 1 1 4 68 0()oo0 1 1 1 ~ 68 o0000 1 1. ! 4 68 00000 1 I 1 4 6~ 00000 I 1 1 4 68 00000 I i 1 4 68 00000 1 1 I 4 68 00000 1 1 1 ~ 6~ 00000 1 1 1 4 68 00000 1 I 1 4 68 00000 1 ! 1 4 68 00000 1 1 1 4 68 1 1 1 4 68 1 1 1 4 68 I 1 1 4 68 1 I I 4 68 1 1 i 4 68 1 ! 1 4 68 1 1 1 4 68 1 1 1 4 68 . S X) 00000 00000 00000 00000 o0000 00000 00000 00000 00000 00000 00000 00000 00000 000o0 000oo 00000 00000 00000 00o00 00000 00000 00000 0o000 00000 000000o0o0 o000000000 0000000000 0000000000 0000000000 oooonooooo O00OO00000 000000oo00 0000000000 0000000000 O00000000O DFPT. 4543.500 8FLU DTE 2 =81~4 sp.oT -5.4 ,o ZDP :OTE T~m'I)TF 324.250 IIXO DmE 57:~9 8 :.,-:.... . . ,' · ] - i. 06.0o0 up ,. s4 DPHT.LDT 24.273 RHOB.LOT 2.2}9 Ok, 8. [,D'r -0.009 ()SS.bDT 0.0 9 Lt,. bDT 255,875 LITtt. [.,DT 16~ 625 LStlV. bDT 1.244.000 SSHV.LDT 131:000 Ib~, DTE ~ 777 IbO DT~ D..E 2:787 IrgE DTE CIDPoDTE 393.500 CIMP.DTE II~.DTE 334.750 SC~.DT~ gTE~.DTE 95 375 HRES.DTE IDER.PH$ 2:536 !DVP.PHS DRHO.LDT 0.125 PEF.LDT LS.LDT 474.750 LU.LDT SSi.bDT 252.875 S$2.LDT S1RH.bDT 1.876 bSRH.LDT 2.533 20.000 358.500 0.000 1..886 2.531 2.412 437.500 340.250 2,!23 tS Tone Verification ~,istino ."hl,.~mber'~er Alaska ComD,ltina Center LU!~W. b~T ~. 127 CALl. bDT TFN$.LDT I 735.000 ~,,iT.C~L ~0~4.946 ~CFT.CNb SGP .CNI, 0.000 CGR. CN b ~3S. CNb 1.896 ~TEM.CNb CGm. MGT 44' 4~ wl ~-4C. NGT 40~.7~6 W2NG.NGT wSWq.wG~ 8.037 TE~4$.NGT CS. NGT 1540. 000 DEPT. 4500.000 ,qFLU. DTE SV.DTE -5.480 IDPH.DTE II~OW.DTF 3.000 I~,OF.DTE I!PD.DTE 324,250 IIXD.DTE CG~.DTE 10.8~3 TENS.DTE H~E~.;. DTE 941.000 IDPH.PWS DPHI.LDT 24,273 RHOB.LDT OLS. bDT -0. 009 OSS. bDT LL.LDT 255.875 blTH.LDT LS~V.bDT 1245.000 SS~V.LDT Lt~RH.LDT 2.~97 CALl.bDT T~'~S. LI)T 32~5.000 MPHT.CML 43.515 TNPH.CML RCN~.CNL 20S4.946 RCFT.CNL SGR.CNL 134. 110 CGR.CNb MPES.CNL 1.8~6 ~TE~.C~4L CGP.NG~ 10.711 THOR NGT I,; { ~C. ~GT 408.7~6 W2NG~!GT WSNG.NGT 8.0~7 TE~S NGT CS. ~{GT 1541.000 HTEM. ~GT D~,PT. 4400. 000 SFLU.DTE SP.DTE -~l. 125 .IDPH. DTE IDOl'. ~TF, 0.000 I~. n~ 238.375 II~O DTE HTEN.DT~ 971 50(,) !Dm[4.pHs D~HI.I,DT 18~7~4 aLS. [,DT -0.037 OSS bDT LL.LDT 170.375 TE~{S.LDT 3410 000 ~,ITEa.LDT NOHT.CNL 40~142 TMOH.CNL RC~'T.CMb ~36 781 ~(q~T_ CNL ,SG~. CML 108.848 . ~R ~ C~L !.oo6 W ~ ~G,. ~GT 342.715 W2NG.NGT WSN¢.~GT !0.762 TENS.NGT CS.MGT 1510.000 HTMN.NGT 9-MAR-lg93 09101. 9.383 SGR.LDT 95.3~5 ~RES.bOT .ooo -1~6.000 814 IL~.OTE .goo 7 .ooo 0.059 161o~25 SSI.bDT 1311. 00 $1RH.bDT 9 3 SGR.LDT 42.691 TNRA.CNL 535.459 CNTC.CNL ~0.8~3 CALI,CNh 95.375 MTEN.CNL 2.777 POTA.NGT 194.030 W3NG.NGT 3~75 000 ~TEM~.NGT 941~000 3.439 3.561 0.000 33 719 41o:ooo 3 563 2~340 0 95:§ 1311.000 8.914 95 13 40:~49 599.927 80.735 10 5 ~6 0 341~ 9 7 000 971 500 ILM'.DTE IMPH.DTE CXDP.OTE IIRM.DTE MTEM.DTE IDER,PHS D~HO,5DT bS.DDT SSi.bDT S1RH.,bDT SGR,LDT ~RES,bDT TNRA.CNL CNTC.CNL CAbI.CWb HTEN.CNL POTA.N~T W3NG'NGT MTE~.~GT 0.000 1.886 3.589 1954.490 9.383 -196.000 1.699 73.479 95.375 ~.~77 2. 87 393,250 334.750 9~.375 .548 0.125 474.75O · 876 134.110 1.886 3.589 1954.490 9.383 94~.000 ~0.006 3.479 95,375 3.520 3.563 280.500 265.500 95.313 3.607 0.010 32g.250 208.125 289 367 97~.500 3 454 74~503 95.313 CGm.LDT HTE~.LDT NPOP.CNL CWTC.CNL TENS.CNb SG~.NGT URAM.MGT W4NG,NGT MRES.NGT ILD.DTE IFRE.DTE CI~P.OTE SGP.DTE ~RES..DTF IDVR.PHS PEF.LDT LtJ.LDT SS2.LDT LSR~oLDT CG~ LDT ~PO8 CNL cwTCicNL TENS.CNb SGR.NGT URAN.NGT W4~G.NGT MRE$.WGT ILD.DTE IFRE.DTE CIMP.DTM SGR.DTE MRES.DTE IDVR.PHS PE~.LDT LU.LDT SS2.LDT bSRM.LDT CGR.LDT HTEN.L~T NPO~.CNL CFTC.CNL TENS.CNL SGR.NGT UR~M.MGT W4UG.NGT MRE$.NGT PAGEt 0.000 -196.000 42.601 553.059 1735.000 134.110 4.577 47.072 1,886 2.533 20.000 358.500 134.110 1.886 2.543 2.293 437.500 340.250 2.123 1.0,823 941,000 42 691 553~059 3275.000 134.110 16,412 47.072 !..886 3.539 20.000 280.500 108.848 1.906 3.599 2.920 3~7 750 5125o 2,328 80.7]5 971 50O 40:790 620.986 3410.000 107.997 1.480 8.278 ~.906 Tame Verification LJstlno :blumber'qer Alaska Commutlnq Cern:er DEPT. 4300.000 SF!.U.DTE SP.DTE -2B.203 IDPW.DTE lPO~.l)TE 0.000 YMOF.DTE II~n.mTE 201,375 IIXD,DTE CGP.OTE 63,176 TgN$.DTE HTEW.DTE 1057.000 IDPH.PH$ DPHT.[,DT 22.164 RHOB.LDT OLd.bDT -0.00! O$S.LDT Dh.bDT 191.875 LITH.LDT LSHV.bDT 1244.000 SSMV.LDT DUN~.LDT 2.2~3 CALI.bDT TF~$.b~? 3250.000 ~TE~.LDT NPF~.CNL 41.~4 TNPH.CNL RCNT.CNL 22~8.253 RCFT.CWb SG~.CNL 89.074 CGR.CNL NRE$.CNL 1.946 MTEM.CNL CG~,NGT 57.2~ THOR.NGT W~N~ ~GT 274.3~0 W~NG.NGT Wb{4~:NGT ~0.744 TENS. NGT C$.NGT ~548.0~0 UTEN.NGT DMPT. a~o0,0n0 SWbU.DTE SP.DTM 36,219 IDPM.DTE ImO~.DTE 0,000 I~OF.DTE !!RD.DTM 142.500 IIXD.DTE CG:.DTE 77.196 TEN$.DTE HTEM.~T~ 94~.000 IDPH.PHS DP~,LDT 18.3~9 ~HOB.LDT ObS.LDT -0.0~3 QSS.LDT L~,,[,DT 180.250 LITH.LDT LSHV.!~,IOT ~245.000 SSHV.LDT bl!~.bPT ~.301 CALI.LDT T~NS.LD'? 3230.000 ~TE~.LDT N~HT.CNL 35.438 TNPH.CNL RCNT.CNL 2336.752 ~CFT.CNb SGP.CNL 98.857 CGR.CML M~E~.CML ~.997 ~TE~.CNb CGm.MGT 9~.1~5 THOR.NGT ~,!N~,NGT 3~7.919 W2~G.NGT WbNG.NG~ ~2.386 TENS NGT C~.NG+ ~545.000 N..TEN:NGT g-MAR-1993 09:0! 4.996 IbP.DTE 4.266 IHPH.DTE 0.000 CIDP.DTE 28.672 IIRM.DTE 3~50.000 ~TEM.DTE 4.270 XDER.PHS 2.2~4 DRNO.LDT 0.022 b$,bDT 110,000 SSI.bDT 1~11.000 S1R~obDT ~.750 SGR.bDT 95,438 MRFS.LDT 40.876 TNRA.CNL 585.086 CNTC.CNb 6~.176 CALI.C~b 95.438 WTEN.CNb 7.707 POTA.NGT 133.884 W3NG.NGT 3250.000 ~T~M.NGT 1057.000 5.7~3 6.1 3 .0 00 1..172 3230,000 6.138 2,348 0.034 10! 813 131i:000 35 926 69! 069 77 ~96 95 250 12 ]79 161 024 ~0 0 IbM,DTE IMPH.DTE CIDP,DTE II~M,DTE ,TE~,DTE IDER.PH8 DRHO.LDT LS,LDT .SS~,bDT S1RH.bDT SGR.LDT MRES,LDT TN~A,CNb CNTC,CML CALI.CNb ~TEN.CNb POTA,NGT W3NG.NGT MTEM.NGT CP'DTE -37 438 IOPN DTE 6.50 o'. ..... 4 IMPH.DTE o.ooo o ooo II~D,DTE 134,125 IIXD.D-~E 10:086 IIRM.DTE CG~,~T~ a8.185 TENS.DTE ]~45.000 HTE~.DTF 95~.500 IDPH PHS 6.5~6 IDER.PHS DP?II.LD? 15.054 RHaB:LDT 2.4~ 2 DRHO.LDT [,L.LD$ 154.625 I, ITH:LDT 76.~-.5 S$1.bDT LSNV.LDT ~.245.000 $$HV.LDT !31!.000 8!RM.bDT LURH.LD? 2.391 CAbI.LDT 9 ~4~ SGR.LDT TMNg.LDT 3145.000 MTE?~.LDT 94:~ 13 MRES,bDT ~;PN?,CNh '40.4~8 TNPH.CNL 39'350 TNRAoCNL 4.!25 4.355 23~.{25 ~27.125 95.438 4.660 0.006 360.500 208.750 2.254 89.074 ~.946 3.407 2065.926 8.750 1057,000 1.711 42.975 95.~38 852 ~'973 . 69..875 60.875 95.250 6.002 0.043 344.~50 219.500 2.195 9R 857 1:997 3~142 94~: 313 000 2.697 52.849 95.250 6,234 6 035 ~5):625 151 125 94:81) 6.273 0.014 97250 o6:6 s 2.334, 67.253 1.993 3.404 ILD.DTE IFRE.DTE CIMP.DTE SGR.DTE MP~S.DTE IDVR.PH$ PEw.[,DT LU.LDT SS2.LDT L, SRH.LDT CG~.LDT HTE~.LDT NPOR,CNL CFTC,C~L TENS.CNL SGR.NGT UR~N.~GT w4NG.NGT ~RES.NGT ILD.DT~ IFRE.DTE CI~P DTE SGR:DTE MRES.DTE IDVR.PHS PEF.LDT bU.LDT SS~.LDT LSRH.bDT CGR.LDT MTEN.LDT ~POR.CNL CFTC.CNb TEN$.CNL SG~.~GT U~a~.~GT W4NG.NGf ILD.DTE IFRE.DTE CIMP.DTE ~RES.QTE IDVR.PH$ PEW.I,DT LU.LDT S$9.LOT LSRW.LDT CG~.LDT MTEN.LDT NPOR.C~L PAGE: 4.211 20.000 229.500 99.074 1.946 4.875 2.688 337 250 290:250 2.277 63,176 1057.000 40.57~ 608.755 3250.000 89.431 4.229 11.570 1.946 6.152 20,000 167 375 98]857 1..997 5,9~8 2,617 328,000 297,750 2.303 77,196 942.000 35.970 705,552 3230.000 94.005 0,782 9.909 1.997 6.500 20 000 652625 67.253 1,993 6.320 2.7~3 285.000 2~4.250 2.3~7 48,185 952 500 34:635 '.~ ?ane yerificatlon Listing :blnmberqer AlasKa Comput!nO Center RC~,T.CN!., 2625.120 RCFT.C,I, gGu.C~L 67.253 CGR.C~5 CGW.MGT 34.758 T~O~.NGT w!NG.~GT 231.782 W2MG,NGT CS.~G~ ~553.000 HTEM.NGT D~PT. 4000.000 SFI,U,DTE SP.DTE -60.031 IDPH.DTE IDOW.DTE 0,000 I"OF..DTE ]IR~.~T~ 252.875 II×D.DTE CG~.~T? ~0.]06 TENS.DTE ~TE~.DTE !01.7.500 IDPH.P~S DPH?'.LDT 26.7~3 RHOB.LDT OLS LDT -0.070 OS$.bDT 5L~LDT 2~6.695 blT~.LDT LSHV.LDT 1~43.000 SSH¥.LDT bURg.!,DT 2.205 CALl.GDT T~NS.bDT 31~0.000 ~TEM,LDT NPHT.CNL 42.550 TNPH.CNL RCNT.CNb 2487.~7] RCFT.CNb SG~.CN5 73.134 CGR.CN5 MPE$.CNL ~..972 CG~.NGT 74.842 THOR.NGT W~G.~GT 217 89~ W2~G.NGT wGN~.NGT 9194~ TENS.N~T CS.~GT ~586.000 NTEN.NGT DFPT, 3900.000 SFLU DTE · SP.DT~ -46,18~ IOP~:DTE IDOW.~TE 0.000 IMOF.DTE ~!W~.DTM 1~6.375 II×D.DTE HTEN.D~ 9g6.000 DP!i~ .b[~T 1~.947 RHOB.LDT ObS, bDT -0. 009 OSS. I,,t,. LDT 1~7,6~5 bSHV.LDT 1244.000 $S~V [,DT t~iI~.L[)T 2.289 CALIiLDT F~)~.LDT ~995.000 ~T~ LDT NP~!,.CNI, 3~.0~0 TNDH.CNL RC~T.C~L ~074.905 RCFT.CNL ~G~.C~L ~3.469 CG~.C~L ~ES.CNL 2.004 ~TEN.CNL C~ EGT 51 397 THO~ NGT wSgC.gGT 6,1~4 TENS.,GT CS.NGT 15~4.000 HTEN.NGT D~iPT. 3800.000 SWLU.DTE SP.DTE -50.063 !DPH.DTE /DOW.DTM 0.000 IgOF.DTE I~Rg. OTE 17~.750 IIXD.DTE CG~.DTM 46.13! ~'ENS.DTE 9-~AR-1993 09:01 64~.536 CNTC.CNL 48.185 CALI.CNL 94.813 ~TEN.CNL ].614 POTA.NGT 97.454 WGNG.NGT 3~45.000 95~.500 4.~73 IGN.~TE 3.~89 IHPH.DTE 0.000 CIDP.OTE 33.000 3~40,000 MTE~,DTE 3.29~ IDER.PHS 2.~09 DRHO,LDT 0.023 LS,bDT 137.000 SSI.GDT 1311.000 S1RH,LDT 8,586 SGR,GDT 94.~0 ~RES.hDT 43.1 TMRA.CNb 641.969 CMTC.CN~ ~60.,06 CALI.C~b 94,500 10,156 POTA,~GT 117.647 WGNG.NGT 3140.000 ~TEg. NGT 1017,500 5 434 IL~,OTE 7~613 IMPH,DTE 0 000 CIDP,DTE 16~43B IIR~.DTE 2995.000 MTE~.DTE 7.618 IDER.PHS 2.337 DR~O.bDT 0.029 LS.LDT 110 688 SSI.bDT 1311~000 $1RH.DDT 9.680 SGR.bDT 93,313 ~RES,LDT 40 303 TN~A.CNL 61~966 CNTC.CNL 63 050 CALI.CN5 93:313 ~T~N.CNL 7 ~31 POT~,,NGT 2995 000 ~TE~.gGT 996~000 5.199 ILM.DTE 5.!7~ IMPH,DTE 0.000 CIDP,.DTE 20.875 IIP~.DTE 3090.000 WT~.DTE 2207.972 9.141 952.500 1.299 35.119 94.813 3.342 3.338 303.750 279.250 94.500 3.30~ -0.001 408.000 ~08.875 34 1.972 3.47l 2327.~75 8. 86 .500 101 .217 35.626 94.500 6.508 6.992 13! 250 1441875 93 313 6 898 0.040 354.500 221.750 170 82.004 3,313 2083~644 9.6~0 996.000 1.509 47.244 93.313 5.07~ 5.102 193.250 185.125 93.125 CfTC.CNG TENS.CNG SGR.NGT URa~.~GT W4NG.NGT gRES.NGT ILD.DTE IFRE.DTE CI~P.QTE SGR.DTE M~ES.~TE IDVR.P~S PEF.LDT LU.LDT SS~.LDT [,SRH.I,DT CGR.LDT HTEN.LDT NPOR.CN!, CFTC.C~L TENS,CML SGP.NGT URAN.MGT W4NG.NGT MRES.NGT lbD.DTE IFRE..DTE CI~P.DTE SGR.DTE MRES.DTE IDV~.PHS PEF.[,DT LU.L, DT SS2.LDT LSRH.LOT CG~.LDT HTEN.LDT NPOR.CNL CFTC.CML TENS.CML SG~.NGT UR~M.MGT W~MG.~GT MRES.~GT ILD.DTE IFRE.DTE C!~P.~TE SGR..DTE MRES.DTE PACE: 665.900 3145.000 67.024 4.150 7.0~4 1,993 3,277 20.0O0 299,500 73.134 1.972 3,220 2.408 383.000 ~94,000 2.209 60.306 10~7 500 43:054 660.044 31~0.000 74.102 -0.158 7,457 1,972 7 246 20~000 142.875 83.469 2.004 6.507 2.939 333.750 303.500 2.287 63.050 996.000 43.575 6~2.996 2995 000 75~0~4 3.758 7,874 2.004 5,141 2O,000 ~95,875 74,762 2,039 Tame Verification ;,istin~ .-hlUmber'_~r alaska Computinq Center HTE,k~. riTE , 1007.000 IDPH.PHS DPH! .LDT 24.035 ObS. LDT O. 006 eSS.bDT L~,.LDT 203.500 [,ITH.LDT LSHV. LDT 1243.000 LU~.t, DT 2.258 CALI.LDT NPM~.CNL 4~ ·906 TM¢H.CNL ~C['T. C~;I. ~390.103 RCFT.CNL SGP. CN[, 74. 762 CGR. CNL ~PM~.CNt., 2.039 ~TE~.CNL CGP.NGT 44.362 THOR.NGT W!N~.NGT 240.806 W~NG.NGT wbNG.NGT 5.254 TEN&.NGT C$.NGT ~ 585.000 HTEN. MGT DEPT. ~700,000 ~P,DT~ -60,~19 XDPH·DTE IDO~.DTt~ 0.000 I~OF.DTE II~.DTE 152.875 IIXD.DTE CG~.DTE 48.7]8 TENS. DTE HTE~ .DTK 967.000 IDPH. PHS DPHT.[,DT 25.397 RHOB.LDT ObS. [,DT 0.009 OSS.bDT LL.t,DT 208.875 LITH.LDT LSgV.LDT 12~.000 SSHV..LDT LU~.~,DT '2'246 CALI.LDT T~['S. BDT 2955.000 gTE~I BDT NO~.CNL "4.3.0~. 4 TNPH:CNL ~C~,~T.CML 2338.84i RCFT.CNL SG~. C~I, 65,451. CGR. CG~.~GT 37~7~0 THOR.MGT WI~lC.NGT 21~'799 W2NG.NGT W5~,C. ~GT 5. 263 TENS. NGT CS. ~GT { 587. 000 gT~g. NGT DF, PT. 36'00.000 SFLU.DTE SP.DTF; 43.656 IDPI'{.DTE i n.O~'. ~T,~ 0.000 I~OF CG~.DT~ 64.265 TEMS !o!5.5oo D¢~I'.!,DT 28.733 0LS.LbT -0.028 eSS.bDT bf,.t.,Dm ~30.750 LITH.LDT [,S~U. t, DT 1244.000 SSHV.LDT LUR~.LDT 2.166 CALI.bDT TFb'g'LDT 3075,000 ~TF~.LDT N~HI CNL 49.572 TNPH,CMb [{C~T [ C~L t946,147 RCFT.CNL SG~. C~J~., 85,3 ?9 CG~.CNL ~{~ES.CNL 2.008 ~T~.CNL CGR.MGT 7~.-230 THOR.NGT wlN~.NGT 276·074 W2NG.NGT O-MAR-1993 09101 5.175 !DER.PHS 2 2~) D~HO.BDT 0~0 3 'LS.LDT 118.750 SS1.LDT 131! ,000 SlRH.LDT ~.5B6 SGR.LDT 93. { 25 MRES. bDT 41.146 TNRA.CNb 627.222 CNTC.C~L 46.~3! CALI.C~L 93.125 HTEM.CMb 4·784 POTA.NGT 119.089 W3NG.NGT 3090.000 ~TEM.NGT 1007.000 5.7 0 U.DTE 0.000 CIDP.DTE 2955.000 MTEM:DTE · DRHO,LDT -o ool 5S.%DT 1~41625 S$1.~DT 1311'000 Sl~H.bDT 8.438 SGR.LDT 9~.750 MRE$ bDT 4~,~76 TNRAiCNL 65~..214 CNTC CNB 4 .730 CALI,CNL 92.750 ~TEN,CN5 4,71t PDT~,MGT 94,737 W3NG.~T 2955,000 ~TE~.NGT 967.000 4.695 IbM DTE 4·664 ]MPt{:DTE 14! 95 IIP~.DTE 3075 000 ,TE~ DTE 4.669 IDER:PH$ 2.~76 DRHO.LDT 0.02~ L$.LDT ~30.500 SS!.bDT !31~.000 S~Rg.bDT 8,~$3 SGR.LDT 92.~88 MRE$.bQT 47 05~ TM~.CNL 478~967 CNTC.CNL 9 1~$ HT~.CNL I ~65 ¢OTA,NGT ~29.711 W3NGoNGT 5.{24 0.004 379.250 209.125 2.234 74.762 2.039 3.44{ 2204.253 8.5~6 1007.oo0 1.617 42.032 93.;25 5.523 5.457 173.750 170.250 92.750 5.542 -0.006 38 000 2o : so ~.26~ 65.451 485 2223.145 8.438 967.000 1.~17 2~.807 9 ·750 509 214.125 21~.000 92.~88 4.747 0.006 435.000 215.000 2.~43 ~5.339 ~.00~ 3.$79 ~870.~66 8.883 1015.500 2.027 46.450 IDVR.PHS PEF.LDT I.,U.LDT SS?.LDT LSRH.LDT CG~.[.DT HTE~.L~T NPOR.CNL CFTC.CN;, T~NS.CN}, SGR.NGT URA~).NGT W4~G.WGT ~ES.~GT ILD.DTE IFRM.DTE CI~m. DTE SG~.DTE uRES.DTE IDV~.PHS PEF.LDT LU bDT LSRM.bDT CGR.LDT HTEN.bDT NPOR.CNL CFTC.END TENS.CML SGR.~GT URAN.NGT W4~G.NGT ~RES.NGT ILD.DTE IFR~.DTF CI~P.DTE SG~.DTE IDVR.PHS PEF. LDT LU. LDT SS~. bDT LSRF.LDT CGR.LDT HTEM.LDT NPO~.CNL CFTC.CWL TENS.CML SG~.NGT U~AN.MGT W4NG.NGT PAGE: 5.096 2.680 351.500 292.000 2.248 46.131 1007.OO0 41.775 647.679 3090.000 74.692 3.951 13.135 ~.039 5.71.1 20,000 183.1~5 65.451 2.016 5,508 2.455 35~ 500 2 5:soo 48.738 967.000 42.843 641.870 2955.000 493 7.0~,8 2,016 4.621 20.000 221.750 85.339 2.008 4.~51 2.742 408.500 305.500 2.168 64.~65 1015.500 48.354 494.744 3075.000 1.671 7'0~! [$ Ta~.e Verlf,!.catton ,-hlr~ber'oer Alaska Computtno Center W~C.NGT 12.970 TEL:S. NGT CS.NGT 2056.000 HTEN.NGT I)~PT. 3500.000 SFLU.DTE SP'. DTE -57.6~8 IDPH.DTE IDOW.~TE 0.000 ]~OF.DTE [~.nT~ 13~.000 IIXD.DTE CGm.bTE a0.769 TEMS,DTE HTF~'.PTE 988.500 IDPH.DH~ DP~ ~ . ~,DT 33 . 79 ] ~HOB. LDT OLS. LOT -0 . 0 ! 3 OSS. L~T [,~,. LD~ 269.750 LITH.LDT LSMV.LDT 1243.000 SSHV.LDT [,U~. LDT ~. 096 CALl. LOT TM~S. LDT 29a5.000 ~TEM.bDT N~HT.CNL 43.450 TNPH.CNL ~ES:CNu ~. 043 MTEM.CNL CGP.NGT ~.466 THOR.NGT W]NG.NGT 174.769 W2NG.NGT WSNC.~GT ~ 157 TEM8. NGT C8.NG~ 205fl:000 HTEN.N~T D~]PT. ~00.000 SFbU.DTE 8P D'I;~ -58,063 IDPH,DTE CG~.DT~ 45.059 TENS.DTE MTE%~, DT[C 1003.000 IDPH.,PH8 D[?~ .bDT 34.915 RHOB, bDT ObS. [,D· O. 006 OSS. I, DT L~,.LOT 278.500 LITH..LDT b~V. !.,QT 1244.000 LURg. LDT 2,090 CAbI.LDT TFNS.LDT ~8~5.000 N~HT, CNI,, 46,9~6 TNPH.CNL RCNT,CML 2~76,404 RCFT.CML SGr, C~b 59.6~6 CGR. ~ES CNL 20a9 ~TEM.CNb CG~: NGT ~1: 794 THOR.NGT W.~ ~JG. UGT 199.074 WgNG.NGT WS~. NGT !. 157 TENS. NGT C~. ~JOm 2106.0o0 HTEN.NGT DEPT. 3300.000 SFLU.DTE SP,DT~ -58.250 IDPH.DTE I~OW.DTF n. O00 I~OF,DTE ITR~.PTF 146,~50 IIXD.DTE CG~ DTF 42,90 ~ TENS,. DTE HT~ :DT~: 103!.000 !DPH.DH8 DPN~ .bDT 67.212 ObS.t.,~T -0.o04 LT~. T,[)T 6~5 000 bITH, bDT LSHV, ~,DT ]243:000 SS~V. I,DT 9-MA~-!993 09:01 3075.000 1015.500 6.512 IL~.DTE 6.395 I}~PH.DTE 0.000 CIDP.DTE 12.594 IIg~.DTE 2945.000 ~TE~.DTE 6.399 IDER.PH$ 2.09~ DRNO.bOT 0.018 LS,bDT 17~.625 SSi,bDT 1311.000 SI~H.LDT 8.461 SGR.LDT 90.938 MRES.bDT 41 ~3 TNRA,CNL 4o 7~o ca~,~.c~b 90:938 HTE~J.CNb ~.)13 POTA,NGT 7 .074 W3NG.NGT 2945.000 ~TEM.NGT 988.500 6.203 ILM.DTE 6.309 X~PH.DTE 0.000 CXDP.DTE 13 336 iIRM.DTE 2825:000 MTE~,DTE 6 31] IDER.PHS ~:074 DRHO.LDT 0 0~3 bS.LDT !85i875 $81,BDT ~31! 000 S1RH.LDT 8.64~ SGR,LDT 90438 44:267 61 550 CNTC.CNL 545:059 CALI,C~ 282 000 ~T~,NGT 1003,000 3.219 ILM.DTE 6.105 IMPH.DTE 0,000 CIDP DTE 7.629 IIR~DTE ~760,000 ~TE~,DTE 6'I1~ IDER.PHS 1.541 D~HO,LDT 0.030 L$.LDT 564: 000 $SI.LDT 131!:000 SIRH,bDT 9~.188 6.137 6.254 156.250 153.500 90.938 6.487 -0.005 5OO.75O 212 500 2:113 52.857 2.043 3.510 2337.507 8..461 988.500 1.467 35.880 90.938 5.781 6,078 158.375 162.750 90:438 6.406 =0,012 51.1.500 208.875 2.133 59.616 .049 .718 2080.349 8.641 100~.000 .76~ 33.565 00.438 5.781 5.453 J63.625 162.875 90.125 5.287 1309.000 226.125 1,615 MRES,~GT ILD,DTE IFRE,DTE CIMP,DTE MRES,DTE IDVR,PHS PEF,LDT LU.bDT SS~.IoDT bSRH.LDT CGP.LD? }-{TEN.[,DT NPOR.CNb CFTC.C~b TEN$,CNL SG~,MGT w~G.NGT ILD.DTE IFRF DTE C!~'P:DTE '$GW. DTE MRE$.DTE !DV~ PHS PEF:X,.DT LU. LDT SS2.I.,DT hSgM. LDT CGR.t, DT HTEN .bDT NPO~. CNL CFTC.CNL TEN S. CNb SG~.~GT Ug~N. ~GT W4MG.NGT ILD.DTE !F~E.DTE CIMD.DTE SGP.DTE MRES.DTE !DVR.PHS PEF.I!DT LU.LQT SS2.LDT LSRH.LDT PAGE: 1 0 2.008 6.320 20.000 159.750 52.857 2.043 6.506 2.256 461.500 307.750 2.096 40.769 988.500 40.627 678.~4 ~945.000 52.959 3,405 5.787 2.043 6.246 90.000 164.500 59.616 2.049 6.296 2.268 466.000 395.250 2.084 45.059 ~003 000 577.960 2825.000 58.493 ~,~39 2.315 2.049 5.867 20.000 183.375 43.943 2.049 5.575 1.041 1248.000 354 500 1:556 chlumbef~er Alask8 ComD,.ltt. nO Center I,URN.I, DT 1.56] CALI.[.DT TFNS.LDT 2760.000 ~TEM..LDT ~!P!-{!.CN5 74.142 TNPH.CNL RCNT.CNL 1415.164 RCFT.CNb SG~.CNL a3.943 CGR.CNL ~E~.CM5 2.049 MTE~.CNL CGm. NGT 53.016 THO..NOT W~Ng. NGT 130.636 W2NG.MGT WS'MG.NGT ~0.405 TENS.NOT C$.NGT ~007.000 ~TEM.~GT DEPT. ]200.000 SFLU.DTE S~.DTF -54.094 IDP~.DTE I~OF.OTE 0.000 I~OF.DTE ITRD.DT~ 147.7~0 CG~.DTF 56.143 TEN$.DTE ~?E~.DT~ 978,500 IDPH.P~$ DPHI.I, PT 34.0~7 ObS.[,DT -0.025 OSS.LDT L!~.LDT 272.000 I, ITH.LDT I,S~tV.~,OT 1244.000 SSHV.bDT t, URH.!,~T 2.092 CALl.bDT TFWS.LDT ~730.000 ~TE~.LDT ~.f~q! CML a7.~.49 TNPH.C~!L ~GR,CNL 79.I01 CGR.CNL ~ES.~r,, 2.0~0 ~TE~.CNb CGR,MGT 58.554 THOR.NOT W~q~.~GT ~6~,574 W2NG.N~T WSN~.NGT 8.102 CS.MGT ~007.000 D~PT 3!00.000 SFbU,.DTE SP:DTE 60.7t9 IDPM.DTE IDOW.DTE 0.000 !~OF.DTE II~.DTE 129.000 IIXD.DTE HTE%'.DTE ~006.500 IDPH.PHS DPHI.LDT 33.080 RHOB.LDT OI.,$.[,~ -O.0n5 OSS.LDT bL.!,.,~T 268,~50 hlTH.LDT LSMV.LDT 1244.000 SSHV.bDT LUP~.LO~ ~.105 CAt, I.LDT TM~S. [.DT 2600.000 ~TF~.LOT NPH~.CNL d3.1~ I'MPH.C~L ~C~T.CMI, ~339.235 ~CFT.CNb ~ES.CNI, 2.219 ~TE~.CWL CG~.~GT 44.084 T~4OR.NGT wl,~c NGT 231.1~] W2NG MGT WS~C~MGT 5.376 mE~$~NGT C~.NGT ]9~4.000 WT~N.NGT 9-~AR-1993 09:01 .4 77 SGR.LDT 9 .125 MRES.LDT 84.033 TNRA.CNb 267.063 CNTC.CNh 42.901 CALI.CNL 90.~25 ~TEN.CNb 7,826 POTA.NGT 63.584 W3NG.NGT 2760.000 ~TEM,MGT 1031.000 5.6~2 ILM.DTE 5.9 $ IMPII.DTE 0.000 CIDP.QTE 12.695 IIRM.DTE 2730.000 MTEM.DTE 5.940 IDER.PHS 2.089 DRHO.bDT 0 023 L$.LDT 16~!125 SSI.bDT 131 000 SlPH.bDT 8 883 SGR,LDT 89:438 MRE$.LDT 47.569 TNR~,CNb 474.373 CNTC'CN5 56 143 CALI.CN5 89:438 HTEN,CNL 97~.500 8 7 ILMDTE 8.5~3 SGR.bDT 88.8,5 MRES.LDT 4? 0~8 TNR[.CNL 553i463 CNTC.CNL 51 598 CALI.C~L 88 875 WTEN.CNL 4:~0 POTA.NGT 80.645 W3NG.NGT 2690. 000 MTEM. NOT I006.500 4~.943 .049 5.269 1457.948 9.477 1031.000 1.416 23.121 90.125 5.367 5.625 168.375 175.250 89 438 5~979 0.004 508.500 ~18.000 2.068 79.101 2.080 3.747 1847.539 8.883 978.500 38.194 89.438 6.730 7.086 144.750 140 125 88~875 8.023 0.006 495.250 21~.625 .072 68.002 .219 .504 2058.550 8.563 1006.500 1..747 35.484 88.875 CGR bDT HTEN[bDT NPOR.CNL CFTC.CML TENS.CML SG~,MGT U~A~,NGT W4NG.NGT ~RE$.NGT ILD.DTE IFRE.DTE CI~P.DTE SGR.DTE MRE$.DTE IDVR.PH$ PEF.LDT LU.LDT SS2.[,DT LSR~.LDT CGR.LDT HT~iW.LDT NPOR.CNL C~TC.CN[, TEP~$.,CNL SGR,NGT URAN.NGT w4NG.NGT ~RES.NGT ILD.DTE IFRE.DTE C!MP.DT£ SGR.DTE ~RES.DTE IDVR.PHS PEF.LDT LU.LDT SS~.LDT LSRg. LDT CGR.LDT HTEM.bDT NPOR.CML CFTC.CML ~ENS.CNL SGR.~GT U~AN.NGT w4NG.NGT MRES.MGT PAGE= 42.901 1031.000 92.052 293.334 9760.000 47.090 -0.718 3.468 2.049 5.844 20.000 177.625 79.101. 2.080 6.217 2.451 473.000 31.4,250 2.0~4 56 143 97s15oo 45 151 4841662 2730.000 76.345 2,463 !,!.574 2.080 6.793 20,000 141.000 68.002 2.2~9 9.178 2,6a5 453.750 312.750 2.098 51.598 1006.500 39.0~4 5~5 545 70.205 3.403 4.301 2.219 IS Ta~e verification !,istin~ .~!umber'qer ~l~sKa ¢o~utino Center !-)~pT. 1000.000 S~LU.D?E SP.DTF -59.688 ~DPH.DTE IIR~.nTF 145,750 IIXD.DTE CGU.DTM 58.563 TENS.DTE HTEW.DTE !0~3.500 !DPH.PH$ DPqI.!..DT 30,686 RPOB,LDT OLS.~,DT -0,Olg OSS.LDT LL.LDT 248.625 LITH.LDT LSHV.LDT 1243.000 $S~4V.LDT bUR~.LDT 2.135 CALI.LDT T~NS.[,DT 2685.009 MT~M.LDT NPHI,CML 47.004 TNPH,CNL RCN~.CNL 1959,70a RCFT,CNL SGP.CML 79.764 CG~.CNL MRE~.CNL ~.275 MTFM.CNL CG~.~G? 55.3g~ T~{OR.NGT W1MG.NGT 238.710 W2NG.MGT w~MC.NGT ~.607 TEWS.NGT CS.NG? !980.000 HTEN.NGT PMPT. ~900.000 SFLU.DTE S~.DTE -80.3~3 ID~.DTE X'~QF DTE 0.000 I~QF DTE CGP.DT~ 32,534 TE~$,DTE HTE~,~TF 977,500 IDPH,PPS Doq{,[.DT 36,05~ ~HOB,[,DT CbS.LOT 0. 026 OSS.LDT Lb. [.,DT 2R3,750 LITH t,DT I,SbV. bDT 1243. 000 sSHV :bDT LIJ~. bDT 2,092 CALl. LDT T~N~. L[)T 2465.000 MT~M. bg!,.f NgH?.CNI, 40.554 TNPW.CNL ~NT.CNL ~56~.()55 ~CFT.CNb SGD.CNL 47..~47 CGR.CNL CG~.~GT 31 5~0 TNOR.NGT W1MG.NGT 148]069 W~NG.NGT WLN~ MGT ~ 146 TEI$ NGT CS.MGT ~014.000 HTEN.NGT DEPT. ~800.000 SFLU.~TE SP.DTF -70.875 IDPH.DTE !DO~.DTF 0.000 I~QF.,DTE ITRD.DTE ~4.188 IIXD.DTE CG~.DTE ]7.670 TEMS.DTE HTE~' . DTE I 042,000 IDPH, PHS DPHT.LDT 34.395 RHOR.LDT OLS.LDT -0.009 QSS.LDT !.L.LDT 27~.~50 LITH.bDT ~V I, DT ~24.3:000 SSHV LOT L~IPH,i,D? 2.092 CALl.bDT TwN~.LDT 2545.00(1 MTEM.LDT 9-MAR-~993 09:01 5.]0~ IL~.DTE 5.824 0.000 ClDP.DTE 21.125 IIR~.DTE' 26~5.000 ~TEM.DTE 5,827 IDER.PHS 2.144 DRHO.bDT 0,025 LS,DDT !~$.000 S$1,bDT 1310,000 $1R~,bDT 9.609 SGR.LDT 87.438 ~RES.bDT 43.383 TNRA..CML 493.064 CNTC.CNL 58.56~ CALI.CWb 87.438 MTEN.CNb 7.020 POTA.NGT 125,806 W3NG.MGT 2685.000 1023.500 11,914 ]LM.DTE 13,305 IMPH,DTE 0.000 CIDP.DTE 4.746 IiRM.DTE 2465.000 ~T~M,DTE 13,314 IDER.PHS 2.055 DRHO.GDT LOT 0.005 LS. 174.500 ss1.L[r 1311..000 S1RH,bDT 8.328 SGR.LDT 73 . 97 CNTC.CNb 32,534 CALI,C~L 742 W3NG,NGT 2465,000 PTE~,NGT 977,500 ~.92~ IL{,DTE 11,008 I~PH.DTE 0.000 CIDP.DTE 5,984 II~M.DTE 2545,000 MTEM,DTE 11,017 IDER.PHS 2,08~ DRHO.LDT 0 015 tS LOT 7 15oo o.0oo 8.531 SGR.LDT 85 438 ~RES.LDT 38]266 TNRA.CNb 5.414 5,871 171.625 1.73.750 87,438 6.495 0,008 464,000 218.000 2,102 79.764 2,275 3.798 1795.311 9.609 1023,500 !.763 48.38? 87.438 12.367 12,641 75.125 76.625 86 250 -0.023 516.000 203~25 47.147 2,285 3 34.1 ~,328 977.500 I 486 zo:o 86.250 10.703 10547 90:750 88.438 85.438 0.676 ~0.0o8 04500 o:soo 2.123 55.258 2.232 3,451 ILD.DTE IFRE.DTE CI~P.DTE SGR.DTE MRES.DTE IDVR.PHS PEF.LDT LU.LDT SS2.LDT LSRN.bDT CGR.bDT HTEN.!,DT NPOR.CNL CWTC.CNL TENS.CML SGR.MGT URAN.NGT W4NG.~GT ~.ES.NGT !LD.DTE IF~E.DTE CIMP.DTE SGR.DTE ~RES.DTE IDVR.PHS PEF.LDT bU.t, DT SS2.LDT LSRH.LDT CGR.LDT HTE~.LDT NPOR.CNL CFTC.CNL TENS.CML SGR.NGT URAN.NGT W4MG.NGT ~RES.NGT ILD.DTE IFRE,.DTM CI~P.DTE SG~,DTE ~RES,DTE IDYR.PH~ PEr. LDT bU.LDT SS~.LDT LSRH.LDT CGR.LDT HTEN.LDT NPOP.CNL PA~E: 5.977 20.000 170.250 79.764 2.275 6.121 2.404 430.750 310.000 2,135 58.563 1023.500 ~2.272 500.594 2685.000 78.001 ~.954 13.978 2.275 12.859 20,000 79,063 47.147 2.285 1.3,433 2,2~5 464.50O 300.50O 2.078 32,534 977.500 38,734 7!.~.649 2465.000 47.456 2.173 1.,073 2.285 10,766 20.000 94.750 55.258 3.~32 10.322 2.201 464.250 306.500 2.090 37,670 10~2.000 40.43~. IS Ta~e verification btstlng ch].l~mbef~er AlasKa ComPutf,.o Center Rr~!T.CNL 2226,7~9 RCFT,CN[. SGD. CU!.: 55,2.~P CGR,CNL CGR.NGT 36.7!4 THn~.NGT W~NC.MGT 1~1.503 W2NG.NGT ~,SN~. ~'GT 6.936 CS, ~'C7' ~012,000 HTEN,~CT DFPT, ~700,009 SFLU,DTE SD,DTE -71,188 IDPH,DTE IDQF,DTE O,00O !~F,DTE I1PD.nTF 120.438 I!XD.DTE CGm. OTt? 51.576 TENS.bTE HTE~ .DTE 969.000 IDPH.PHS DPHI .LDT 43.957 ~HOB.LDT Ob~. bDT 0.0~6 QSS. bDT ~,[~.LDT 359.000 LITH.LDT I SHV.LDT 1243 000 SMNV.bDT ~URw.bP~ m~. :954, CAt, I. bDT TFNS.LDT 2540.000 MTEM bDT NPgI.CNI., 67.704 TNPH:CML ~C~':T. CNL 1498.6~9 ~CFT.CNL ~GR. CNL 76. 992 CGR. CNL ~'~ES. Cub 2 229 CG~.NGT 50:953 THOR,NGT W~NC NGT 240,8~0 7.5 7 DPPT. 2600.000 SFLU.DTE SP.DTE -79.43~ IDP~,DTE IDQF.DT~ 0.000 !~OF.DTE I. T~. ~E 56,906 IIXD. DTE HTEM. DT~ ! 0 ]. 5. 000 . DP DPHT.LDT 40.~27 RHOB.LDT Ot.,S.bDT 0.0~ 9 OSS.LDT L,L. LD~ 336.250 UITH.L, DT L.%NV .I,PT ~ 246.000 SSHV. LOT [,[.J~,g. bUT 1.989 CALI.bDT ~DH~'.CWL 45.350 T~Pg. CML RC~T,Ch'L 1776,740 RCFT.CNL SG~. CNL 33. gOO CGR. MP~.CNL 2.209 MTE~.C~L CGm. ~GT ! 3.614 THO~. w I ~,IC. ~G'.r 111.240 W~NG.NGT wSNG. NGT i. 159 TENS. NGT CS. a)GT ~058. 000 ~TEM. NGT DFPT, 2493.500 SFLU DTE SP.DTE '46,563 IOPH~OTE 0.000 9-MAR-1993 Oq:01 587.614 CNTC.CNL 37.670 CALI.CNL 85.438 HTEN.CNL 4.536 POTA.NGT 95.954 W3NG.NGT 2545.000 1042.000 7.582 ILM.DTE 7.07P IHPH.DTE 0.000 CIDP.DTE 12.992 II~.DTE 2540.000 MTEM.DTE 7.081 IDER.PH$ 1.92~ DRHO.~DT O.0!8 b$.hDT 209.375 SSi.hOT 1310.000 S1RH.L, DT 9.328 S~R.~DT 85.375 MRES,SDT 77.65] TNRA.CNL ]06.099 CNTC.CNL 51.576 CALI.CN5 85.375 gTEN.CNL 6.004 POTA.N~T 11.828 W3NG NGT 2 40.000 MTEM:NGT 969.000 14 891 Xb~.DTE 16:500 XMPH,DTg 0 0~0 CIDP.DTE Oi~ 4 IIR~.DTE 2500 000 MTE~.DTE 16.506 IDER.PHS 1.976 DRHD.SDT 0.016 bS.bDT 207 000 $St.LDT 1313~000 S1RH.LDT 9.633 SGR.LDT 85 000 ~RE$..bDT 43i990 TNR,A..CNb 446 868 CNTC.CNL 27.584 CALI.C~b 85.000 HT~N..CML 1 2~3 POT~,MGT 47:5 9 W3NG.NGT 2500'000 ~T~.NGT 101.5.000 2189 341. ~i531 1042 000 1.197 25.434 85.43~ 6.676 6.914 141.~5 14~.250 85.375 7.449 -0.012 655.500 215.500 1.985 76.992 ~,229 4.906 2.725 1619.328 969.000 1.732 44.086 85.375 14.563 14.227 60.563 65.125 85.000 14.909 0.000 615.000 220,875 1,976 3.890 32.299 3.709 1695.837 9.633 1015.0O0 0.539 19.699 85.000 1950.000 1950 00O 79:563 -408.500 84.68~ CFTC.CN{. TENS.CNL SGR.WGT LIRAN.NGT W4NG.WGT ~RES.WGT TbD.DTE IFRE.DTE CI~P.DTE SGP.DTE MRFS.DTE IDVP.PHS PEF.LDT LU.[,DT SS~.LDT LSRH.LDT CGR,LDT HTEN.LDT NPO~.CNL CFTC.CNL TEN$.CNL SGR.NGT UR~N.NGT 'W4NG.NGT MRES.MGT II,.D.DTE IFRE.DTE CI~P.DTE SGm.DTM MRE$.DTE I~VR.PH$ PEF,LDT LU.LDT SS2.LDT LSRN.LDT CGR.LDT HTE~.LDT CFTC:CUL T~N$.CUL SGR.~GT [JP~N.~GT W4NG.NGT ~RE$,NGT ILD.DTE IFRE.DTE SG~.DTE MRES.DTE P AGE: 13 679.90O 2545.000 54.7~6 2.3R9 2.312 2.232 7.047 20.000 144.500 76.992 2.229 7.749 2.996 593.500 321.500 1.937 51.576 969.000 ~8,8~6 333 023 25~0:000 77.172 3,735 9,677 2.229 15.758 20.000 70.250 33.890 2.299 13,631 2.270 557.000 328,000 1,976 27.584 1015.000 44.884 467.~2 2500.000 32.711 2.607 3'476 2.299 12.148 20,000 -446.750 4~.322 2,246 Verification Ltstinq chl. U~he~o_er Alaska Computlno Center 9-~AP-!993 09:01 ~tTK%~.I~T~ t. 013.~00 IbPq. P9$ l)Pt{r.t. OT 45.071 OIlS.Lb? 0.078 QS$.bDT L*,.[,i>· 111.313 LS~V.{.D~ ~2d6o000 S~HV.LDT b!!~U.[,D? 2.611 CALI.LDT T;i~$.LFT 2440.000 ETEM.[,DT a'~.CNL 59.599 T~PH.CNL RC~T.CPL ~4~5.679 ~CFT.C~L SG~.CN~, 43.3~ CGR.CNL ~ES.CNb 2,246 MTEM..CNL C(;P.N(;T -999.~50 TMOR.NGT W1N~.NGT -999.250 W2NG.NGT wSN~.NGT -999.250 TEN$..NGT C~.NGT -999.250 HTEN.NGT 12.962 IDER.PgS 1.g06 DRHO.LDT -0.096 LS.bDT 22.578 $$1.LDT 1313.000 S1RH.LDT 8.766 SG~.~DT 84.688 ~RES.LDT 60.173 TN~A.CNL 250.06! CNTC.CNL 33.847 CALI.CN5 84.68~ ~T~N.C~L -999,250 POTA.'NGT -999.~50 W3NG.NGT ~999.~50 MTF~.~GT 999.250 *' 14.071 -0.651 216.000 79.188 3.953 43.322 2.246 4.417 129~.888 B 766 1013:500 -999.250 -999.~50 -999.250 IDV~.PHS PEF.!,DT bU.LDT S$2.L~T LSRH.LDT CGR.LDT NTEN.LDT NPOP.CNL CFTC.C~L TENS.CNL SG~.NGT URAN.NGT W4NG.NG~ MPES.NGT 14.106 20.51,6 209.250 126.688 2.557 33.847 1013.500 58.992 293.975 2440.000 -999.250 -999.~50 -999.250 -999.250 END OF DAT~ **** FILE TR~II,E~ **** FILE NAaE : EDIT .001 SERVICE : ~bIC V~RSIf)N : DO!AD6 D~Tm : °1103117 FTL~ TYPE **** 'rAPE 'TRAIt, ER **** OP!G!N ! F!,,IC ,r~pF ~a~E ~ 74~5~ P~EvIOUS TAPE C0~uEMT : COMOCO, $CMRADER BLUFF,~ILNE POINT UNIT H-4, 50-020-22064 **** REEL SMRVICE NA~E : EDIT O~ : OllO]117 O~IC!N : FLiC R~Et., ~IA~E ~ 74!,51 P~EViOU$ REEL : Cn~E~{T : CONOCF}, SCHRADER BLUFF, ~I{-,NE POINT I.I~!!IT H-4, 50-029-22064
