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194-118
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: MPJ-12 (PTD# 194-118) Missed AOGCC Witnessed MIT-IA Date:Tuesday, August 1, 2023 11:11:20 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, July 27, 2023 2:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPJ-12 (PTD# 194-118) Missed AOGCC Witnessed MIT-IA Mr. Wallace – PWI well MPJ-12 (PTD# 194-118) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA due this month. The well will now be 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 Regg p P.I. Supervisor [:>��` 1 /it It 1 DATE: Wednesday, July 10, 2019 SUBJECT: Mechanical Integrity Tests / Hiloo p Alaska LLC J-12 FROM: Matt Herrera MILNE PT UNIT J-12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT I-12 API Well Number 50-029-22506-00-00 Inspector Name: Mau Herrera Permit Number: 194-118-0 Inspection Date: 7/1/2019 Insp Num: mitMFH 190701170333 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well J-12 -iType Inj W TVD 3985 Tubing 839 840 839 - 838 PTD 1941180 Type Testi SPT Test psi Isoo IA 1023 1721 -� 1676 1663 - BBL Pumped: 0.5 BBL Returned 06 OA I I I Interval4YRTST P/F P —--- J— ---- —— Notes: IA Pressure tested to 1700 PSI Per Operator Wednesday, July 10, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: P.I.Supervisor DATE: Thursday,July 23,2015 Jim Regg �P( ` v'I 115 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC J-I2 FROM: Bob Noble MILNE PT UNIT KR J-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv3l& — NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR J-12 API Well Number 50-029-22506-00-00 Inspector Name: Bob Noble Permit Number: 194-118-0 Inspection Date: 7/20/2015 Insp Num: mitRCN150723120329 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well J-12 ;Type Inj W -TVD 3985 Tubing 1140 • 1140 - 1140 •1 1143 PTD[ 1941180 Type Test SPT Test psi 1500 -1 IA 1170 1910 1870 I 1867 ' IntervalINITAL PAF P ✓1 OA 0 0 I 0 0 1..--- --- -- 1 —-- — — -� Notes: post workover EC1Yl/ 'J iau+o Thursday,July 23,2015 Page 1 of 1 STATE OF ALASKA RECEIVED • t. 3KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUL 16 2015 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ $ `OGCC Plug Back U Performed: Suspend ❑ Perforate D Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Convert to WINJ Q 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development Q Exploratory ❑ 194-118 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22506-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0315848,25906 MILNE PT UNIT SB J-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF PA 11.Present Well Condition Summary: Total Depth measured 8,320 feet Plugs measured 4,595&8,213 feet true vertical 7,462 feet Junk measured 4,157 feet 4,395,4,482& Effective Depth measured 4,595 feet Packer measured 7,738 feet 3,985,4,060& true vertical 4,157 feet true vertical 6,909 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 13-3/8" 112' 112' 2,730psi 1,130psi Surface 2,565' 9-5/8" 2,565' 2,413' 5,120psi 2,370psi Production 8,299' 7" 8,299' 7,440' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet SCANNED AUG 1 0 2415 Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 4537' 4,108' 7"x 3-1/2" 4,395/3,985 7"x 3-1/2" 4,482/4,060 Packers and SSSV(type,measured and true vertical depth) FB-1 N/A 7,738/6,909 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 0 750 0 Subsequent to operation: 0 0 400 10 950 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development❑ Service ❑� Stratigraphic ❑ 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: 315-350 Contact Paul Chan fl(P Email pchan@hilcorp.com Printed Nain ul Chan Title Senior Operations Engineer Signature /r,t ------ Phone 777-8333 Date 7/16/2015 ..., RBDMk1V JUL 1 7 2015 Form 10-404 Revised 5/2015 ` 7 '�N—1 S Submit Original Only Milne Point Unit • II Well: MPU J-12 SCHEMATIC Last Completed: 7/2/2015 Eiilcorp.Alaska,LLCPTD: 194-118 CASING DETAIL RKB Elev.:65'/GL Elev.:35'(Nabors 22E) Size Type Wt/Grade/Conn ID Top Btm j '-''.iE .1'4 ' 13-3/8" Conductor 54.5/K-55/N/A 12.615 Surface 112' �t t: 9-5/8" Surface 36/L-80/Btrs 8.921 Surface 2,565' �.r 13-3/8' . 7" Production 26/L-80/NSCC 6.276 Surface 8,299' i Y ;+ TUBING DETAIL • v 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surface 4,537 °7 9-5/8" 1 i i JEWELRY DETAIL + z a No Depth Item t $ 1 4,395' 7"x 3-1/2"Packer ,e 1 2 4,423' 2-7/8"GLM w/Dummy Valve __ 3 4,452' 2-7/8"Waterflood Mandrel w/Dummy Valve 4 4,482' 7"x 3-1/2"Packer _ '` 3'}OA Sand 5 4,509' 2-7/8"WFM w/Dummy Valve t 6 4,529' 2-7/8"XN-Nipple :ID=2.205 ie � 4 " 7 4,536' 2-7/8"WLEG-Bottom @ 4,537' %. i, 5 8 7,734' CAMCO LLC Valve w/Baker seal Assy.&R.Latch LLCV Said set to open @ 2,500psi,Res Pressure @ 3,500psi v 6 }� 9 7,738' Baker FB-1 Packer 7,738' 1 10 7,741' Baker 4"Wire Wrap Screen,20'long: Bottom @ 7,761' 7 11 7,762' 3-1/2"SWN Nipple:ID=2.76"-PXN Plug Installed 11, 12 7,763' WLEG: Bottom @ 7,764' CIBPg4,635' w,1/4. , - TOC @4,595' PERFORATION DETAIL 7'ESCementer Fish©4,637 SCHRDR/KUP Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status @±4,861'SMO 0"' (Consists of PPP= - 2,460 at CT,ESP OA 4,436' 4,472' 4,021' 4,052' 21 7/1/2015 Open Cade and ESP OB 4,515' 4,535' 4,089' 4,106' 20 6/30/2015 Open OS kk Assembly) B-Silt Sands 7,826' 7,832' 6,992' 6,998' 6 11/2/1994 Isolated A3/A4 Sands 7,900' 7,922' 7,062' 7,083' 22 11/2/1994 Isolated WELL INCLINATION DETAIL KOP @ 550 20 Marker Jt Max Hole Dev=32 deg.@ 3,289'MD to 6,259'MD @7,575 OPEN HOLE/CEMENT DETAIL 13-3/8" Cmt w/250 sks of Arcticset in 24"Hole V. 9-5/8" Cmt w/504 sks PF"E",250 sx Class"G"in 12-1/4"Hole 11 7" Cmt w/349 sks Class"G"in 8-1/2"Hole i" TREE&WELLHEAD w Tree 2-9/16"/5,000psi/SSV Actuator ' Wellhead 7-1/16"/5,000psi FMC Adaptor/11"WKM Thru-Bore is 4, y GENERAL WELL INFO t'3 .A 1 8&9 API:50-029-22506-00-00 ,i ,� Drilled and Cased by Nabors 22E 9/27/1994 hiCompleted with ESP 11/11/1994 R, 10 $. Perf&Install Tubing 7/2/2015 Fu Y 0. 11 d/ r+ a. 12 e 4' o, a }KUP B-Silt Sands g1 +ter}KUPA3/A4Sands P 7 °, r TD=8,320'(MD)/TD=7,462'(TVD) PBTD=8,213'(MD)/PBTD=7,359'(TVD) Revised By:TDF 7/15/2015 Hilcorp Alaska, LLC Ililc,,n,Alaska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPJ-12 50-029-22506-00-00 194-118 6/21/2015 7/2/2015 D�i��r�3p�r�tio.6g,. me4 ", 6/17/15 Wednesday No operations to report. 6/18/15-Thursday No operations to report. 6/19/15-Friday No operations to report. 6/20/15-Saturday No operations to report. 6/21/15-Sunday Accepted Rig. MIRU Nordic 3 and associated equipment. Pulled BPV,spot kill tank RU lines and prepped rig for kill operation. Loaded pits with 500 bbls of hot 9.0#brine,tested lines 3,000psi-test ok.SITP 0 SICP 800/60. Bled pressure off both. Circulated well with 300 bbls of 9#brine and SD pump closed choke and monitored well.SITP 250psi,confirmed Camco valve was opened. 140bbls in pit weighted up to 9.7#brine. Kill weight fluid arrived on location, loaded pit with 290bbls and weighed 9.6.#,dusted to 9.7#.SITP Opsi and SICP 580psi started circulating 3bpm at report time 6/22/15-Monday Continued to circulate a well volume of KWF 9.7#Brine.SD pumped and monitored well-static.300bbls pumped, 270bbls returned 10%oil.Set BPV and ND tree, identified lifting treads and packed hanger seal with fiberglass. NU 11" BOP's. 2 d, Pulled BPV set TWC and shell tested BOP's(250psi-3,000psi).AOGCC Inspector Chuck Scheve witness.Tested BOPE as_ followed: Rams 250-3,000psi,Valves 250-3,000psi,Annular 250-3,000psi,charted for 5 mins performed gas detection and k kommey drawdown-1 failure recorded HCR kill valve, replaced valve and tested ok. Pulled TWC, PU/MU landing jt to hanger. Backed out lock down screws, pulled 55k to unseat hanger and pulled to rig floor.The ESP cable is parted 6' below the tbg hanger. Drained and looked down the BOP stack and could not see cable. 6/23/15-Tuesday PU on CT string,55k up with 10k drag and looked down stack no sign of parted end of ESP cable.Slacked off CT and started taking weight.Tried working CT but could not go down. RU clamps,cutters and elevators. Prepped to pull CT. POH w/CT, made(2) 10'cuts and worked up to 15' cuts.Averaging 10'cut per hr. No issues cutting and LD 15'section. Continued TOH gaining pipe weight 92K. Pipe showing rub marks.Continue POH 1,500', cutting 15'sections, no clamps or cable recovered, pulling 92k up with a lot of drag. Continued POOH pulling 120k a lot of drag, parted end of ESP cable at surface. Ran ESP cable across floor down beaver slide to the spooler.Spooled slack.TOH w/ESP Completion Pulling 23k up,spooling a lot of slack, recovering cable clamps, 2,800'of CT pulled at report time. Hilcorp Alaska, LLC Ii,,,,,r,,:,,:, >;,,,,,,,�; Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPJ-12 50-029-22506-00-00 194-118 6/21/2015 7/2/2015 Daily Oaerations: 6/24/15-Wednesday Held PJSM.Contiued to POOH at 4,500'w/ESP completion cutting 15'sections and spooling cable. PU/MU CT connector and TIW,circulated 1 tbg volume(26bbls)to clean string. BO/LD CT connector and TIW.Continued to POOH w/CT ESP cable @ 4,200'.Continued POH w/CT, cable quit moving up hole @ 4,300'.Steadly losing pipe weight. POOH with parted end of CT, last 30' had 3 cracks/breaks in the CT. No sign of corrsion around break.Total of^'5,300' of CT POOH. PJSM, RU 2 tugger lines to ESP cable and POH w/cable while reeling in with the spooler. 1,900' recovered. Estimated total of —5,300'of cable OOH.Cleaned rig floor, loaded pipe shed with 3-1/2" DP and tallied. PU/MU 6-1/8"flat bottom mill and TIH w/same 4,200'. 6/25/15-Thursday Held PJSM. Continued TIH w/6-1/8"flat bottom mill tagged TOF at 4,610',attemped to push on fish with string weight no luck, broke circulation 6bpm and started rotating 80 RPM with 4-9k down on mill, unable to mill off junk. POH w/flat bottom mill and L/D same called Baker fish to bring out milling BHA. PU/MU BHA and tallied, 6-1/8" bladed junk mill,two 4-3/4" boot baskets,4-3/4"double box sub,4-3/4" bumper jar,4-3/4"oil jar and 6 4-3/4" drill collars,TIH w/same, DP to surface.Tagged TOF @ 4,620',closed bag,started pumping 6 bpm and broke circulation. POH w/milling BHA, L/D same, boot basket was full of metal (5 pounds), mostly stainless bands and a few small pieces of wire. PU/MU 6-1/8"Shoe, 10' ext, bumper jar, oil jars, 6 DC,TIH w/same,DP to surface.Tagged TOF and started washing over fish @ 4,620'4k down washed down to 4,630' and pushing fish down hole to 4,653', pumped sweep,continued pushing on fish waiting on sweep to come around.TOH w/milling BHA,30' of cable and some stainless steel bands inside shoe.TIH w/Shoe and ext. 6/26/15 Friday Held PJSM.TIH w/6-1/8"shoe and washpipe ext,jars and DP to surface.Tagged TOF @ 4,653'and started washing over fish 4k down washed down to 4,671' pumped sweep,continued trying to pushing on fish 4-9k down. No go. POH w/50k drag, pumped 20bbls sweep and drag went away. POH BO shoe and recovered cable and SS bands.TIH w/BHA#4 6-1/8" Shoe and washpipe ext,tagged TOF @ 4,671' and started washing over fish 4k down washed down to 4,709' pumped sweep,continued trying to pushing on fish 4-9k down waiting on sweep to come around. POH and pipe stuck @ 4,675', unable to circulate or rotate,started jarring trying to free pipe,jarred up hole to 4,652'. 6/27/15-Saturday Held PJSM.Continued jarring on fish 100k over(225k) pulling to 300k,can not circulate either direction or rotate pipe. BHA Stuck at 4,660'.Call EL pipe recoverey,first available truck will be sent out.SD jarring operation to inspected derick, found 1 turnbuckel broke and some nuts and bolts backed out.Continued jarring on fish 100k over(225k) pulling to 300k, can not circulate either direction or rotate pipe. BHA stuck at 4,660'.SD jarring and cut slip drill line. Continued jarring on fish 100k over(225k) pulling to 300k, can't circulate either direction or rotate Pipe. BHA stuck at 4,660'. 6/28/15 Sunday Held PJSM.Continued jarring on fish 100k over(225k) pulling to 300k, can not circulate either direction or rotate pipe. BHA stuck at 4,660'. No movement.SD jarring operation to inspected derick. Rotated pipe 5 turns to left and worked torque down to bottom,set slips, MIRU EL, reheaded. MU CCL and 5'String shot, RIH w/same to 4,628' (bushing between jars and washpipe)fired string shot and POOH RD EL. Latched pipe and PU to string weight 107k,turned pipe to the left and backed off BHA between the jars and washpipe, PU 10'to ensure pipe was free, closed the pipe rams started pumping 5bpm, circulated a 20bbls sweep around,with returns clean SD pump. POH standing back DP, L/D 6 DC,jars and bushing connection.Wash pipe and burn shoe left in hole. RU EL, MU 6" GR/JB CCL/GR and TIH,correlated depth,tagged TOF @ 4,637'. POOH. 6/29/15 Monday Held JSA. POOH L/D 6" GR/GB, MU Baker#20 setting tool and 7' 26#CIBP,TIH and tagged TOF @ 4,637', PU full tension and set CIBP @ 4,635'top of CIBP @ 4,634'. POOH L/D setting tool. MU 20'cement dump bailer(8 gal volume). Made 8 trips and dumped 50 gals of 15.8 class G cement.Tested casing to 1,750psi and charted for 30mins-test OK.TIH w/6"flat bottom mill,jars and 6 DC and 18 jts of 3-1/2" DP, PU/MU 7"Storm Packer TIH w/same and set @ 106'tested packer 1,500psi-test OK. Cleared rig floor, Nk. OP's, I'. 7-1/16"wellhead adapter and faults bowl. NU BOP's to 11'wellhead. 6/30/15-Tuesday Held PJSM. Filled BOPE and shell tested. AOGCC witness waived by Bob Noble. Performed BOPE test as following: Annular 250psi/2,500psi,Valves 250psi/3,000psi, Rams 250psi/3,000psi, held and charted 5 mpt,gas detection and kommey drawdown-no failures recorded. PU 1 stand and TIH latched storm packer @ 100', released packer and TOH L/D same.TIH w/mill and tagged TOC @ 4,595'.39'of cement on top of CIBP. POH L/D DP, DC,jars and mill. RU Dutch riser, MIRU EL,tested Lubicator. PU/MU 20'3-3/8" 6spf 25 gram perf gun, RIH with same, made correlation pass and sent to engineer,with approval and gun on depth perforated 4,515-35'well on vac, POOH L/D gun. PU/MU 21'3-3/8" 6spf 25 gram Perf Gun, RIH with same, made correlation pass and sent to engineer,with approval shifted 1',with gun on depth perforated 4,451'-4,472' POOH L/D gun. Hilcorp Alaska, LLC ,,,,,or,,Alaska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP 1-12 50-029-22506-00-00 194-118 6/21/2015 7/2/2015 Daily Operations: 7/1/15-Wednesday Held PJSM. PU/MU 21' 3-3/8" 6spf 25 gram perf gun, RIH with same, Made correlation pass and sent to engineer,with approval and gun on depth perforated 4,436-51' POOH L/D gun. POOH, RD WL BOP's and lubricator. Held Dog House PJSM,tallied completion jewlery, prep rig to run completion string. PU/MU 2-7/8" WINJ completion and TIH w/same and landed hanger. RU EL, PU/MU CCL/GR and TIH. Made corelation pass across RA marker.Sent Log to Anchorage for approval to land completion. POOH RDMO EL.With completion on depth ran in lock down screws. Completion as follows; WLEG @ 4,542',XN-Nipple @4,533'w/ball catcher,WFM @ 4,514', FH Packer @ 4,487',WFM @ 4,457', GLM @ 4,428', FH Packer @ 4,400', 2-7/8" 6.5#EUE 8rd to surface. Set TWC and NU BOP's NU tree and tested to 5,000psi-test good, pulled TWC. Pumped 72 bbls of corrosion inhibitor and 61 bbls of diesel for freeze protection down casing. 7/2/15-Thursday p( Held PISA. Pumped 15 bbls of diesel down tubing for freeze protection. Dropped ball & rod pressured up on tbg packers v\� set @ 2,000psi. Pressured to 2,500psi held for 30mins and charted-test ok. Bled off tbg. Pressured up on casing to 1,750psi charted and held for 30mins-Test ok. Bled off pressure. RDMO Nordic 3 and associated equipment. Rig released @ 11:00hrs. 7/3/15- Friday No operations to report. 7/4/15-Saturday No operations to report. 7/5/15-Sunday No operations to report. 7/6/15- Monday No operations to report. 7/7/15-Tuesday No operations to report. Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, July 14, 2015 3:50 PM To: Wallace, Chris D (DOA); Regg, James B (DOA) Cc: Alaska NS - Milne - Field Foreman; Alaska NS - Milne - Wellsite Supervisors; Stan Porhola Subject: MPJ-12 (PTD # 1941180) Ready For Injection Attachments: image002jpg All, MPJ-12 (PTD# 1941180)was recently converted from an ESP producer to a produced water injector. A passing pre MIT- IA was completed on the rig to 1750psi on 7/3/15. Well is ready to put on injection for stabilization and compliance testing. Plan Forward—Operations 1) Place well on injection. Use caution, annuli are fluid packed. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED JUL 1 6 2015 Hikorp '11.4,..I iA Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Sunday, June 28, 2015 12:59 PM To: 'Paul Chan' Cc: Chris Kanyer;Wade Hudgens - (C) Subject: RE: MPJ-12 (PTD 194-118/Sundry 315-350)/ 28 June 2015 Paul, Per our phone conversation you have approval to set CIBP above your fish at approx.4675 ft MD and cap with min of 30 ft of cement. Casing must be pressure tested to 1750 psi per step 10 of the procedure. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office SCANNED JUL 0 2 2015 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Paul Chan [mailto:pchan@hilcorp.com] Sent: Sunday, June 28, 2015 11:51 AM To: Schwartz, Guy L (DOA) Cc: Chris Kanyer; Wade Hudgens - (C) Subject: MPJ-12 (PTD 194-118/ Sundry 315-350) / 28 June 2015 Guy Saturday operations-Washed over the fish at 4,709' and began POOH to 4,675' MD when the BHA became stuck. Begin jarring on fish. No movement. Saturday afternoon, the decision was made to call out e-line to backoff the fishing assembly as deep as possible. Call out e-line unit. Sunday operations—Waiting on availability of e-line unit. Continue jarring operations while waiting. Forward plan— back off as deep as possible. Tag top of fish and determine if there is still enough room to set the cement plug and perforate the bottom interval (4515'—4535' MD). If we can recover the fish down to—4675' MD,that would give"'140' between the TOF and the bottom perforation at 4535' MD. Hilcorp Alaska proposes to set the CIBP as deep as possible (TOF) and cap with 25'—50' of cement(either spotted with a work string or dump bailed with e-line) to allow the well objective to still be met. Can you let us know if the proposed plan is ok? Thanks Paul chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907) 777—8333 (w) (907)444—2881 (c) 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday,June 25, 2015 8:52 AM To: 'Paul Chan' Cc: Wade Hudgens - (C) Subject: RE: MPJ-12 (PTD 194-118/Sundry 315-350) Paul, The changes as stated below are approved for sundry 315-350 . Will file this email as documentation in our files. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Paul Chan [mailto:pchan@hilcorp.com] Sent: Wednesday, June 24, 2015 5:13 PM To: Schwartz, Guy L(DOA) Cc: Wade Hudgens - (C) Subject: MPJ-12 (PTD 194-118/ Sundry 315-350) Guy We are currently POOH with the coiled tubing deployed ESP and cable. We are currently circulating over the top of the stack with the charge pump to keep the hole full, but we are losing 1 BPH. Additionally,the tubing spool needs to be changed out. I propose to make the following changes(highlighted in red)to the approved sundry: 10. Continue POOH until reaching ESP completion at 7,602'. Lay down all jewelry and ESP equipment for disposal. Record number of lost bands. 11. RIH with bit/ to top of Camco LLCV at 7734' MD. Circulate well clean. Set down 10K over and confirm location of the Baker FB-1 packer/Camco LLCV. POOH. 12. PU CIBP anu Ku -i. JUL l,ibI- 'SU" above Lag aepth in step 11. H I casing to 1750 psi 10 confirm CIBP is 13. 41kl-and spet Spot 100' balanced 15.8 ppg Class G cement plug on top of CIPB.LCV/packer{20 AAC 25.112 (c) (1) (C)}to plug the Kuparuk sands. 14. PU 500' and circulate well clean. 15. PU RTTS and set two stands below RKB. PT to 1750 psi for 5 minutes to confirm the RTTS is set. Release from the RTTS and stand back two stands. 16. ND BOPE. The two tested barriers to the reservoir is the tested CIBP and RTTS. 17. ND 7-1/16" tubing spool. NU 11" tubing spool. NU BOPE. Test all breaks. 1 18. RIH with RTTS setting tool and screw into RTTS. Check for pressure. Unseat RTTS. POOH and LD same. 19. RBIH and tag top of cement. 20. POOH. PT plug to 1750 psi for 30 charted minutes. 21. RIH with bit/scraper to —5000'. Scran' oarker setting arpa with chnrt tripe Cirri!late well rlean at maximum rate. 22. RU e-line and perforate the OB sand from 4515' —4535' MD and the OA sand from 4436'—4472' MD. Details to follow on gun size and charge. POOH. 23. Continue with program Please affirm if the changes are acceptable. Thanks Paul Chan Senior Operations Engineer Alaska North Slope Team Hilcorp Alaska LLC (907)777—8333 (w) (907)444—2881 (c) 2 BHTA, Otis, 2 9/16 5M MPJ 12 li 11" X 2 7/8 WKM hanger 2 7/8 EUE 8rd Threads T& B s.• �•� 2 1/2" BPV profile/W 2' pup 1- 3/8 CL Prep Imo`; PIII Valve, Swab, WKM 4I 0 0J 0( .039 2 9/16 5M FE, HWO, WO 0 e SS ��cte DD trim 000 J'Z''' G eAS\V- • \ tc las ,_ Co_ I o `II a �0 O, 0 •' p �f _ O` l ir. p mpg. i 0-4 Valve, SSV, WKM-M, 2 9/16 5M FE, Baker oper, •O f D EE trim 4100 Valve, Master, WKM-M, 2 9/16 5M FE, HWO, DD �' � -t, 0 trim 000 oatlila, , 111 ,0,c)\z's:::cico 1 0 ESQ il 111111311 ,11" 5M WKM tubing 1111 11 - lie spool =�. iiiiiIi NF1 I- ' '''' 'IC. -11 . RIM IP' IP. . 0 II ' 'ill I j: ,pis, All casing valves2 1/16 5M OCT-20 _� MI * I Fel 11111 _ c-. 1al 11,,P o ' I re l� m =�'1II9 - rs.• F TyI77,cs• THE STATE Alaska Oil and Gas • ��.='� ALA SI�:A Conservation Commission - i'itt2 333 West Seventh Avenue \Th GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Q Main: 907 279.1433 pFALAS/CP" ���L 0U 2.V Fax: 907.276.7542 www.aogcc alaska.gov Paul Chan Senior Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR J-12 Sundry Number: 315-350 Dear Mr. Chan: 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, Daniel T. Seamount, Jr. Commissioner DATED this I'day of June, 2015 Encl. RECEIVED STATE OF ALASKA JUN 0 5 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION '°W' APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations [I( Fracture Stimulate 0 Pull Tubing Q Plug Back Suspend❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redril❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other. Convert to WINJ ❑., 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC - Exploratory ❑ Development ❑✓ 194-118 • 3.Address. Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22506-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? (Schrader)C.O.477.05 Will planned perforations require a spacing exception? Yes 0 No Q ✓ MILNE PT UNIT KR J-12 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0315848 ,"c;25�f 04o MILNE POINT/KUPARUK RIVER 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): 8,320 - 7,462 - 8,213 - 7,359- N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 13-3/8" 112' 112' 2,730psi 1,130psi Surface 2,565' 9-5/8" 2,565' 2,413' 5,120psi 2,370psi Intermediate Production 8,299' 7" 8,299' 7,440' 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" HS-70/5.4# 7,650' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): FB-1 Packer and LLCV . 7,738(MD)/6,909(TVD)and 7,734'(MD)/6,905'(TVD) 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work. Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development 9 Service 0 14.Estimated Date for 15.Well Status after proposed work. 6/18/2015 Commencing Operations: OIL 9 WINJ 9 WDSPL 0 Suspended 0 16 Verbal Approval. Date. N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG El Commission Representative. N/A GINJ ❑ Op Shutdown 9 Abandoned 9 17. I hereby certify that the foregoing is tr and correct to the best of my knowledge Contact Paul Chan Email pchan(cr�hilcorp.com Printed Na e Pau ha Title Senior Operations Engineer Signature Phone 777-8333 Date 6/4/2015 COMMISSION USE ONLY Conditions of approval:\Ntify Commission so that a representative may witness Sundry Number: 3kG-3So Plug Integrity 9 BOP Test Er Mechanical Integrity Test V Location Clearance 9 Other: A 3600/4" A_,- 60 r,/� . 1 t s �- nv.,4s e= / 1167 0 `.s,--) ,t_ /A. ( -R--a-- Dr ef.,4-,-...-... ‘1,_ A.:,1^—(2 u( Spacing Exception Required? Yes 0 No Subsequent Form Required: /0 I QLI �\ APPROVED BY Approved by.j/ J COMMISSIONER THE COMMISSION Date• /H // 5 . '\ _...41----‘771 ��� ��L I� Submit Form and Form 10-403 Revised 5/2 15 a I�tlbn lid for 12 months from the date of approval. Attachments in Duplicate RBDMS�� JUN 24 2015 101 I N , O0f G-`i—r 5' Well Prognosis Well: MPJ-12 Iliicoru Alaska,LL' Date: 06/04/2015 Well Name: MPJ-12 API Number: 50-029-22506-00-00 Current Status: SI Producer Pad: J Pad Estimated Start Date: June 18, 2015 Rig: Nordic 3 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 194-118 First Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881 (M) Second Call Engineer: Chris Kanyer (907) 777-8377 (0) (907) 250-0374 (M) AFE Number: Current Bottom Hole Pressure: - 3,518 psi @ 7,000' TVD (SBHPS 11/2/1994) Maximum Expected BHP: - 3,518 psi @ 7,000' TVD (SBHPS 11/2/1994) Max. Anticipated Surface Pressure: -0 psi (Camco LLCV set in Baker FB-1 packer hydraulically isolates the wellbore from the reservoir) - N° C. Brief Well Summary: dye � , The Milne Point J-12 well was drilled as a Kuparuk producer in September 1994 and completed with a coiled tubing deployed ESP in November 1994. The water cut rapidly increased within one year and the well was shut-in when the ESP failed in July 1998. A casing pressure test will be performed as part of the pre-rig preparation and during the workover with the newly ins all d packer. D p �y / rp 20� /v ao/ , l✓� 4 G �9 w(1. c646vf. p ,'( e.re d /- *v (oma rs RWO Objective: qko( y40.-ed (/rf/e ,� a.7 i CA4iie wAe4 Cyc./e ,4i4n�a��'^y �/ cG l<v�s/v fo r4 / well coa be C0M,kie� 4 u ffhale� vr' Convert well from SI Kuparuk producer to Schrader Bluff injector. / i',inicefor apv/d //a,,, 1 'ererov' re co..erfront j ¢ f i.e Ia' ��,i, / Pull ESP, run casing scraper, & run 2-7/8"water injection completion with packef se +200 ft from perfs. ��,�h Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issues suspected. AOR(status of wells within 1/4 mile radius of injection zone): API Well No Permit Well Current Zonal isolation (method) Status CBL run on 14 Oct 1994 indicates TOC at 50-029-22064-00-00 190-089 MPJ-12 S/I -4,324'MD, -110' above Schrader OA sand. 50-029-22070-00-01 199-111 MPJ-01A/ Producer TOC at 3,512'MD (4-1/2" cemented liner), 50-029-22070-00-60 201-021 MPJ-01AL1 -1,180' above Schrader OA sand 50-029-22070-00-00 190-095 MPJ-01 P&A Estimated TOC (calculated) at 3,375'MD 50-029-22196-00-00 191-095 MPJ 05 S/I Producer -1,500' above Schrader OA sand - Schrader Note: Temperature log ran 11/20/1991 to determine TOC was inconclusive 50-029-22493-00-00 194-095 MPJ-06 Producer Estimated TOC (calculated) at 3,650'MD -790' above Schrader OA sand Active Estimated TOC (calculated) at 4,098'MD 50-029-22500-00-00 194-110 MPJ-10 Producer- -550' above Schrader OA sand Kuparuk Well Prognosis Well: MPJ-12 • Hilcurp Alaska,LL Date: 06/04/2015 Active Segmented Bond Log run on 10/15/1994 50-029-22508-00-00 194-126 MPJ-13 Injector- indicates TOC at 4,764'MD, —410' above Kuparuk Schrader OA sand Active Monobore well cemented to surface, full 50-029-23031-00-00 201-133 MPG-14 Producer- returns with 300bbl cement to surface Schrader noted in reports. 6,500' above Schrader OA sand SCMT run on 12 Feb 2004 indicates TOC 50-029-23192-00-00 204-013 MPG-17 Injector at—4,990'MD, —1350' above Schrader OA sand. Rig Workover Outline: 1. MIRU Nordic #3 Rig. 2. Circulate well with 9.0 ppg brine and monitor well to confirm that the Camco LLCV is closed and that the wellbore is hydraulically isolated from Kuparuk reservoir. If during the course of the RWO, the Camco LLCV should open, the well will be circulated to the appropriate KWF. 3. ND tree. NU 11" BOPE and test to 250 psi low/3,000 psi high, annular to 250 psi low/2,500 psi high. Notify AOGCC 24hrs in advance to witness test. 4. 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 the test. \ 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. 5. Spot scrap metal dumpster. RU ESP spooler. RU coiled tubing cutter. Well Prognosis Well: MPJ-12 Icon) Ua.ka.I.I, Date:06/04/2015 6. Unseat hanger and POOH with coiled tubing deployed ESP. Cut 2-7/8" coiled tubing into 17' - 18' sections and dispose of same into metal dumpster. 7. Continue POOH until reaching ESP completion at 7,602'. Lay down all jewelry and ESP equipment for disposal. 8. RIH with cleanout BHA to top of Camco LLCV at 7734' MD. Circulate well clean. Set down 10K over and confirm location of the Baker FB-1 packer/Camco LLCV. POOH. 9. RIH and spot a 100' balanced 15.8 ppg Class G cement plug on top of LLCV/packer {20 AAC 25.112 (c) (1) (C)}to plug the Kuparuk sands. A(-, TC U 10. PU 500' and circulate well clean. POOH. }'T plug to_1750psi for 30 charted minutes. 11. RU e-line and perforate the OB sand from 4515' —4535' MD and the OA sand from 4436' —4472' MD. POOH. 12. PU —6" gauge ring/junk basket and RIH to 4550' MD. Make multiple passes across perforated interval to remove perf burrs. POOH and RD e-line. 13. MU and RIH with completion: • 2-%8" WLEG • 2-%8" "XN" nipple with RHC ball catcher • 2-%8" GLM with dummy valve • 7" x 3-%" Packer w/ 10' handling pups set at—4485' MD • 2-%8" Waterflood mandrel with dummy valve • 2-%8" GLM with dummy valve • 7" x 3-Y" Packer w/ 10' handling pups set at"'4400' MD • 2-/8" tubing to surface • Tubing Hanger 14. RU e-line and run GR/CCL correlation log. 15. Space out and make up the tubing hanger. Land tubing hanger. RD e-line. 16. Drop ball/rod. Pressure up on tubing and set the packers. Test the tubing to 2500 psi for 30 minutes. 17. Test the annulus to 1,750psi for 30 min. 18. ND BOPE. NU tree. 19. RDMO workover rig and equipment. 20. Turn well over to production. 21. Fish ball/rod from LXN nipple. /� 1/� ((// /� tie�'1 ilk 14 Well Prognosis Well: MP1-12 flilcorp Alaska,LL Date:06/04/2015 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Schematic 4. Western Atlas CBL dated 14 Oct 94 n Well:Mile MPUPoint J-12Unit 14 SCHEMATIC Last Completed: 11/11/1994 Etileorp Alaska,LLC PTD: 194-118 1 CASING DETAIL RKB Elev.:65'/GL Elev.:35'(Nabors 22E) Size Type Wt/Grade/Conn ID Top Btm t.- I` .; 13-3/8" Conductor 54.5/K-55/N/A 12.615 Surface 112' e .: 9-5/8" Surface 36/L-80/Btrs 8.921 Surface 2,565' 13-3/8” *: ,'. 7" Production 26/L-80/NSCC 6.276 Surface 8,299' COIL TUBING DETAIL w 61 wi a w 2-7/8" Coil Tubing 5.46/HS-70CM 2.44 Surface 7,650' r FJEWELRY DETAIL V, V° M .t No Depth Item ;a la , J 4 1 7,575' CAMCO KBMG Gas Lift Mandrel w/1"Pocket:ID=2.44" ', 2 7,602' Centri-Lift Check Valve 95/8 ° 3 7,605' ESP Pump Intake Section a' 4" 4 7,624' ESP Seal Section T ES Cementer5 7,637' ESP Motor Section @x,861'--@x,861'---j6 7,648' ESP Pressure Gauge:Bottom @ 7,650' 7 7,734' CAMCO LLC Valve w/Baker seal Assy.&R.Latch LLCV set to open @ 2,500psi,Res Pressure @ 3,500psi 8 7,738' Baker FB-1 Packer 7,738' 9 7,741' Baker 4"Wire Wrap Screen,20'long: Bottom @ 7,761' n 10 7,762' 3-1/2"SWN Nipple:ID=2.76"-PXN Plug Installed 1V 11 7,763' WLEG: Bottom @ 7,764' v PERFORATION DETAIL � �y1�� KUPARUK Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Qs B-Silt Sands 7,826' 7,832' 6,992' 6,998' 6 11/2/1994 Open A3/A4 Sands 7,900' 7,922' 7,062' 7,083' 22 11/2/1994 Open WELL INCLINATION DETAIL KOP @ 550 Max Hole Dev=32 deg.@ 3,289'MD to 6,259'MD OPEN HOLE/CEMENT DETAIL 20'Marker Jt 13-3/8" Cmt w/250 sks of Arcticset in 24"Hole @7,575',01 9-5/8" Cmt w/504 sks PF"E",250 sx Class"G"in 12-1/4"Hole IC 2 7" Cmt w/349 sks Class"G"in 8-1/2"Hole ",a TREE&WELLHEAD Tree 2-9/16"/5,000psi/SSV Actuator s Wellhead 7-1/16"/5,000psi FMC Adaptor/11"WKM Thru-Bore - 4 GENERAL WELL INFO w- v I 5 4"' API:50-029-22506-00-00 tw 1EJ Drilled and Cased by Nabors 22E 9/27/1994 6 1,, Completed with ESP 11/11/1994 '.►_A� ►_ t.'8 - 9 1 110 2 4r 11 };r r.. 1, �. M IP} o P B-Sin Saws }KUP A3/A4 Sands kl la P 7'4 tit- TD=8,320'(MD)/TD=7,462'(TVD) PBTD=8,213'(MD)/PBTD=7,359'(TVD) Created By:TDF 6/2/2015 n • WellMile: MPUPoint J-12Unit • 14 PROPOSED Last Completed: 11/11/1994 flacon)Alaska,LLC PTD: 194-118 CASING DETAIL RKB Elev.:65'/GL Elev.:35'(Nabors 22E) Size Type Wt/Grade/Conn ID Top Btm ° CI E. 13-3/8" Conductor 54.5/K-55/N/A 12.615 Surface 112' aal Q� V' 9-5/8" Surface 36/L-80/Btrs 8.921 Surface 2,565' 13-3/8' «_ i. 7" Production 26/L-80/NSCC 6.276 Surface 8,299' t TUBING DETAIL 4, 2-7/8" Tubing 6.4/L-80/EUE 8rd 2.441 Surface 7,650' V, r V vV ' • JEWELRY DETAIL 9-50 4 i V l a No Depth Item 7.1 1 ±4,400' 7"x 3-1/2"Packer w/10'handling pups 1:2:k.'1 2 2-7/8"GLM w/Dummy Valve 2 3 2-7/8"Waterflood Mandrel w/Dummy Valve G 4 ±4,485' 7"x 3-1/2"Packer w/10'handling pups 3 fs }OA Sand 5 2-7/8"GLM w/Dummy Valve x 6 2-7/8"XN-Nipple w/RHC Ball Catcher 4. csi 4 t. 7 2-7/8"WLEG Y 5 CAMCO LLC Valve w/Baker seal Assy.&R.Latch LLCV i. 8 7,734' "vr ti. set to open @ 2,S00psi,Res Pressure @ 3,500psi 1 9 7,738' Baker FB-1 Packer 7,738' 4 3 6 10 7,741' Baker 4"Wire Wrap Screen,20'long: Bottom @ 7,761' i"4i� 11 7,762' 3-1/2"SWN Nipple:ID=2.76"-PXN Plug Installed t 7 } 12 7,763' WLEG: Bottom @ 7,764' }OB Sand t PERFORATION DETAIL •7'ESCementer , SCHRDR/KUP Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status @±4,861'x+0 O` OA ±4,436' ±4,472' ±4,021' ±4,052' ±36 Pending Pending 08 ±4,515' ±4,535' ±4,089' ±4,106' ±20 Pending Pending B-Silt Sands _ 7,826' 7,832' 6,992' 6,998' 6 11/2/1994 Isolated A3/A4 Sands 7,900' 7,922' 7,062' 7,083' 22 11/2/1994 Isolated WELL INCLINATION DETAIL KOP @ 550 20 Marker Jt Max Hole Dev=32 deg.@ 3,289'MDto 6,259'MD ©7,575'-...-..44 OPEN HOLE/CEMENT DETAIL ;.".. 13-3/8" Cmt w/250 sks of Arcticset in 24"Hole" t 9-5/8" Cmt w/504 sks PF"E",250 sx Class"G"in 12-1/4"Hole 7" Cmt w/349 sks Class"G"in 8-1/2"Hole TREE&WELLHEAD 4: Tree 2-9/16"/5,000psi/SSV Actuator TCC @±7,634' Wellhead 7-1/16"/5,000psi FMC Adaptor/11"WKM Thru-Bore 100 Above LLCV ' �, 1 GENERAL WELL INFO �r " 8&9 1 /3'1 API:50-029-22506-00-00 xt aDrilled and Cased by Nabors 22E 9/27/1994 0 111 10 Completed with ESP 11/11/1994 P 11 12 %,X }KUP B-Silt Sands ' A}KUP A3/A4 Sands 4 P ler TD=8,320'(MD)/TD=7,462'(TVD) PBTD=8,213'(MD)/PBTD=7,359'(TVD) Created By:TDF 6/4/2015 • TIE-1N LOG IIIIIIIIIIII1Nlll1 1111111 HEC00473323 III T IW SEGMENTED BOND LOG 6 El w WESTERN � Wo ATLAS GAMMA RAY -- CCL . n ( Tubing Toil Log ) Atlas Wireline Services FILE ND. 6288.00 COMPANY BP EXPLORATION (ALASKA) , INC. a WI CO q WELL MPJ - 12 '0 A & W ¢ API NO. FIELD MILNE POINT W ft 50-029-22506-00 • 5 73 COUNTY NORTH SLOPE STATE ALASKA z W LOCATION: OTHER SERVICES gl 5 cc IL SURFACE: 3 3/8" PERF - .i/1 Ill 2374' NSL & 3202' WEL U LT., o -J HNAI PRINT L' m a SEC 28 TWP 13N RGE 10L g 2:,' M 11 Cr CO O PERMANENT DATUMMSL ELEVATION 0.0 FT. ELEVATIONS 4[ y to LOG MEASURED FROM RKB 64.65FT. ABOVE PERMANENT DATUM KB 6 4.65' 4 B DRILL. MEAS. FROM RKB OF 64. GL 35.0' -o 0, J DATE 14 OCT 94 __ w 1 R GI RUN ONE _ Z a z is SERVICE ORDER 152507 :#2 4- DEPTH-DRILLER 8213' BPTD tr, g_ g _ DEPTH-LOGGER 8213' TD TAGGED DUp i ATE E,BOTTOM LOGGED INTERVAL 8206' `'��-�' '1111�C W a h- • TOP LOGGED INTERVAL 3950' z a; • 3 TYPE FLUID IN HOLE BRINE " I . _ SALINITY PPM CL. N/A J `�' s Ir W DENSITY LB/GAL._ _ N/A CO• "' "MC ¢ o LEVEL FULL __ x 0 w MAX REC. TEMP. DEG. F NOT MEASURED W = a- z OPR. RIG TIME CRANE --____ ._____ a = o H w _I cr.. EQUIP. NO. / LOCATION HL-6531 ITIORTH SLOPE I il x a RECORDED BY L. KOENN 2 o z WITNESSED BY J. 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V i gi a— �....., Optional valve port cip !, !1 ic,,,, ,, :!, '� is , 4.:. , ,,,,,, ,r4, . , ,„ 1_ , , IiOiI \ .i Schwartz, Guy L (DOA) From: Paul Chan <pchan@hilcorp.com> Sent: Tuesday, June 09, 2015 2:06 PM To: Schwartz, Guy L(DOA) Cc: Bettis, Patricia K(DOA) Subject: RE: MPJ-12 Convert to WINJ (PTD 194-118) Attachments: MPJ-12 7 inch Cementing Report.pdf Guy Attached is the 7" Casing Cementing Summary for the well along with details from the daily drilling report. After the well reached TD, a 50 bbl pill (15 ppb Barafibre and 15 ppb Baracarb) was spotted at 4840'. The 7" casing was RIH slowly with only partial returns after the 7" casing shoe passed 4300' MD. A total of 170 bbls of mud was lost while running the casing to 8299'. Attempted to establish circulation and lost 50 bbls of mud with no returns to surface. The first stage cement job of 42 bbls was then pumped with no returns to surface. The plug bumped and the floats held. The casing was pressured up to 3200 psi and opened the ES cementer. Pumped 25 bbls to establish circulation with no returns to surface. The second stage cement job of 30 bbls (with 30%excess cement) was then pumped with no returns. The plug bumped and the floats held. The cement job was designed to place 500' of cement above the top of the Schrader Bluff NA sands (but not to surface) as per the drilling program. 416, --.J ' /id ,..17..,_- _ 0.4 The MASP for the Schrader Bluff 0 sand is 1460 psi (1860 psi reservoir pressure at 4000'TVD datum with 0.1 psi/ft gas gradient). I will include both MASP calculations on future programs as needed. Thanks Paul Chan Senior Operations Engineer. Alaska North Slope Team Hilcorp Alaska LLC (907) 777—8333 (w) (907)444—2881 (c) From: Schwartz, Guy L (DOA) [nailto:guv.schwartz@alaska.gov] Sent: Tuesday, June 09, 2015 1:02 PM To: Paul Chan Cc: Bettis, Patricia K (DOA) Subject: RE: MPJ-12 Convert to WINJ (PTD 194-118) Paul, Can you also revisit the MASP calculation. You will be perfing the OA and OB with Eline so will not be isolated during the completion phase. Guy Schwartz 1 Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.gov). From: Schwartz, Guy l (DOA) Sent: Tuesday, June 09, 2015 11:13 AM To: Paul Chan (pchan@hilcorp.com) Cc: Bettis, Patricia K(DOA) Subject: MPJ-12 Convert to WIN.] (PTD 194-118) Paul, Can you provide the raw data for the cement job on J-12? le... Volume pumped and what happened during the cement job for the 2"d stage? The CBL log attached looks pretty solid for the 100 ft above the OA zone. Weren't these 2"d stage cement jobs supposed to go back to surface? Per 20 AAC 25.030(d)(5)the cement should have went 500' above the SB. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or( _tz@alaska.gov). 2 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. i(~ I"! "/~,~0 File Number of Well History File PAGES TO DELETE Complete 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 COMMENTS: Scanned by; Bevedy~Vincent ~ J TO RE-SCAN Nathan Lowell ' Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si ON OR BEFORE C :l.,ORlXt,~ iluM .l::)OC AOGCC Ind'fv~du,ai \,,/el i Geo'iog'¥caJ Na~er"i'aJ s Invert?or",/ F'ERklIT DATA T DATA .... PLU:3 9L~,--11E: v6/301 T 3950-~8176 CH/GR/'CCL 94---'! i8 1~.32,~ T 2552-'-.83-3 I OH/CDR/'CI3N 9L~ .... i18 v~CDN/"DC L ~200~-8300 9/:.-'-118 ~C~DN/DC TVD L 6000-'-7~00 (TD) 9/~- I '18 ~¢SDR/DC L, 2600-~-83 O0 9z,~ 118 C~DR/'DC TVD L 2~00---?z~-O0 (TD) 98---- I I 8 ¢~,~ R/" C L L 3950~--8206 9a-'118 ,-~Fc,--.FC/GR L 7575 .... 7700 9~--118 ~'¢:C/"GR L 7715-~7960 9/:----118 vP/-'FC/GR/'CCL L 7700--,8100 9~-,-'118 f~E.T L 3950~8206 E,,-z~-t:e.; 06/ i8/96 F.-iUN DATK ...... RECVD i c 0 rtl p 1 C: O frl p '1 c o ffl p '1 1 '1 '1 1 Ar'e dr'y d-i' tch samp'i es r'equ:'i' r'ed"? yes ~!,s s -ts lq e w e 'i i c o r' e d ? y e s it~ A n a '1 y s 'i' s Iqd r"ece 'i' ve(a' ''~ ''~., &. descr"i'pt"ion r"ec~ ye'.!z; Iq 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WI=LL COMPLETION OR Ri:COMP L£TION RI:PORT AND LOG I1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] :2. Name of Operator 7. Permit Number BP Exp/oration (A/aska) /nc. 94-118 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-22506 4. Location of well at surface ;, ................... 9. Unit or Lease Name At Total Depth ......... 458' NSL, 2593' WEL, SEC. 21, T13N, RIOE 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 65' I ADL 315848 12. Date Spuddedg/17/94 13. Date T.D. Reachedg/23/94 14' Date C°mp" Susp' °r Aband' J15' Water Depth' if °lfsh°re 116' N°' °f C°mpleli°ns10/26/94 N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 8320' MD/7462' TVD 8212' MD/7358' TVD YES [] t,~ [] I LLC @ 7734' feet MD I 1800' (Approx.) 22. Type Electric or Other Logs Run GR/RES/DEN/ NEU 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SiZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 54.5# K-55 32' 112' 24" 250 sx Arcticset (Approx.) 9-5/8" 36# K-55 31' 2565' 12-1/4" 504 sx PF "E"/250 sx "G" 7" 26# L-80 29' 8299' 8-1/2" 349 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and ~5. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MD) Gun Diameter 3-3/8" 6 spf 2-7/8", HS-7OCM 7650' 7738' MD TVD 7826 '- 7832' 6992'-6998' w~ ESP 7900'-7922' 7062'-7083' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 11/13/94 ESP Date of Test Hours Tested PRODUCTION FOR OIL-BBL 3AS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED DEC 1 4 1994 k~s~ Oit.& Gas Cons. Commission Anchora Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit in duplicate 30. GEOLOC.-,tC MARKEF~ FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea ZONE A3 7884' 6982' ZONE A2 7927' 7023' ZONE A 1 7999' 7091' RECEIVED DEC 1 4 1994 Aiaska 0il & Gas Cons. Commission Anch0ra 6. 31. LIST OF ATTACHMENTS 32. I hereby certify/l~at the foregoing is true and correct to the best of my knowledge // Signed ' l/ ..... Title Drilling Enaineer Suoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 TO: PHILLIPS FROM: Melvan/Hinkel WELL: MPJ-12 MAIN CATAGORY: DRLG SUB CATAGORY: FILL CLEANOUT LOCATION' ANCHORAGE DATE' 10/20/94 OPERATION: Post Frac Fill Cleanout II Initial Well I SIWHP I lAP I 0AP I GLP I FLP I FLT Status (psi) (psi) (psi) (psi} (psi) (o F) II 400 I NA I lOO I NA I NA I NA TM I OPERATION 16.00 MI/RU NOWCAM 4905. Thaw inj hd pan. RU tanks, manifold, hardline, etc. PU 3.4" Rev. Nzl 18.30 P-test. ~ I' ~ !" 1% # r' r~, 18.47 Retrieve 30 bbl MEOH j~ i[-_ ~ I- 19.30 Opwn swab 19.32 Start RIH with 3.4" nozzle. DEC ~chora .~ ITIME DEPTH IRATE IWHP ISTG BPM I CTP VOL'I REMARKS 19.32 Surf 0 0 400 Start in hole. 19.37 450 500 Crack choke. Maint WHP. 19.53 1900 19.59 2100 1.5 1275 550 Bring pump on line. Start to circulate out diesel and frac gel. 21.00 4000 575 125 Continue RIH. 21.38 5050 180 Weight check, 11,000 lbs. Cont RIH. 22.10 6000 550 230 Continue RIH. 23.02 7525 306 Park nozzle. SD pump. 23.04 600 Weight check, 15,000 lbs. RIH for dr), tag. 23.10 7555 Tag sand. Pick up and re-tagged at same place. 23.12 PUH. Switch to reverse. 23.17 7500 1.3 0 1100 307 Full returns. 8.3 lb/gal. 23.21 314 Continue RIH. 23.38 7560 335 Fell thru bridge. 23.43 7600 Into sand. 10/21/94 00.06 7690 1700 372 Returns 9.1 lbs/gal. 01.12 7892 1.2 1300 455 Nzl at top perf. Loosing 30% returns. 01.24 7925 1100 470 Loosing 60% returns. 01.29 473 Pull up hole to clear coil. Weight check 14,800 lbs. 01.44 6000 1.3 1000 495 Park nzl. 9.3 lbs/gal, returns. 02.00 1.5 515 Incr pump rate. 02.12 536 Head back to btm and continue to "bail" out carb from sump. 02.15 6300 541 8.4 lbs/gal. Ooil clear. 02.30 7929 900 560 Digging sand. 02.55 8030 1300 595 Coil loading up. Loosing 60%. Pull up hole. 03.14 6000 1000 626 Park nzl. Clear coil. SENT VIA MAC MAIL PAGE -1- 03.20 634 9.5 lb/gal returns. 03.30 650 Head back to btm. 03.37 6700 660 Coil clear. 03.48 8030 678 Dicjc,,ling sand. 04.12 8130 1250 715 Coil loaded up. Loosing 65% returns. Pull up hole. 04.31 6000 742 Park nzl. Clear coil. 04.44 762 Head back to btm. 05.05 8130 794 Dig~in~ sand. 05.13 8175 807 End sump clean out. Pull up hole. 05.20 8000 810 Lost prime. (Not enough fluid in up right tank to keep prime. Next peak truck 45 min away). 05.23 7700 1.3 2950 500 Park nzI.Freeze protect top coil wraps and clear coil. 05.37 830 Freeze protect manifold, choke, and surface lines. WO water. 05.50 7675 Move coil. 06.18 7665 Move coil. 06.30 Sea water arrives. 06.40 Line manifold back up to reverse. 06.41 1.5 0 900 840 Run back to btm. 06.47 8130 Dic, lgin~ sand. 06.59 8175 865 End sump clean out. Pull up hole to clear coil. 07.14 7000 880 Park nzl til coil cleaned up then run back to btm. Decision made to pump hi-vis sweep. Call out materials. 07.56 8175 1.24 0 600 954 Back to btm. Circ another coil volume while short trip 08.30 7000 Shut dwn- wait on pill. 12.50 7000 1.5 0 690 1048/0 Begin Hi-vis pill 13.07 " 2.5 0 620 21/0 Switch to filtered sea wtr. Run bk to btm. 13.53 7890 " 0 750 100 14.55 " 2.5 0 700 257 Pill @ nzl. Reverse dwn. Returns 1.97 bpm. 15.06 8175 " 0 680 288 Polymer in coil (and formation). 15.24 " " 720 330 Start out of hole. Do signs of density increase on meter. Continue reversing. 15.59 4000 " 0 1240 417 Swap to MEOH dwn coil. 16.57 0 1.5/0 At surface. RD/Secure well. 18.30 Leave Location. Final Well Status DATE WHP (psi) lAP (psi) 0AP (psi) GLP (psi) FLT (o F) 10/21/94 620 NA 200 NA NA SUMMARY Run in hole with a 3.4" nozzle. Circulate out diesel and frac gel down to 7500 ft. Shut down pump. Continue in hole to tag top of carb-o-lite. Found TOC at 7555 ft CTD. Switch to reverse and continue running in hole washing out carb-o-lite. Reveresed out down to perforations. Started loosing returns across perforations. Had to "bail" out sump with coil, taking small bites of sand and reversing them out. Cleaned out down to 8175 ft CTD. Short trip and reversed btms up again. Decision was made to pump a hi-vis pill around the wellbore. Pump 21 bbl vis pill dwn 7" csg. at 2.5 bpm and reversed out up coil. Returns rate was 1.95 bpm, loosing .55 bpm to the formation. No detectable sand came back from densiometer readings. Reverse out back up to 4000 ft. Swap to MEOH and frz protect well to 2200 ft while holding backpressure on well. SENT VIA MAC MAIL RECEIVED DEC I 4 ]994 Alaska. Oil & Gas Cons. Commission Anchom ~- PAGE -2- FLUIDS PUMPED L S. DESCRIPTION 486 SEAWATER, FILTERED TO 3 MICRONS. (Friction reducer added). 52 MEOH 538 TOTAL BOTTOM-HOLE ASSEMBLY #1 Tool String Descriptions I O.D. I I.D. ~ Length I Comments FN 2.75 12" DUAL CHECKS 2.45 11" JET NZL 2.5 2" TOTAL 25" RECEIVED DEC i 4 199~; A!a$~ ~)iJ & (}as Cons. CornrnissJon Anchor~: , ~ SENT VIA MAC MAIL PAGE -3- To: ROSSBERG From: WHITLOW / DUNHAM / FOX Location: ANCHORAGE Date: 11/08/94 Well: MP J-12 Operation: 2 7/8" COILED TUBING ESP COMPLETION I Main Category: DRLG- AFE330077 I Sub Category: CTU COMPLETION I I Well Status: Shut In I WHP (psiI' 0 I lAP (psiI· o I eLP(psiI NA I OAP (psi): 0 I AMB=-20F I I ..... I NI- ! I 'il d' I ~1 d' a ,I I . I'nME I OPERATION 11/08 MIRU CTU 4907. R/U WELLHOUSE, 7" DSR BOPS, WORK WINDOW, 4- DEADMEN AND GUY WIRES, DSR SKID, MPU 08.00 GENERATOR AND OPEN TOP PESO 500 BBL TANK, USING 90 TON SPURT BOOM CRANE AND 688 FORK LIFT. 19.00 TEST ROPE USING PBU TRIPLEX. TEST PiPE RAMS, BLIND/SHEAR RAMS, BLIND RAMS TO 300 PSI AND 3000 PSI. TEST HYDRIL TO 1500 PSI. SPOT ESP REEL HOUSE AND PUMP SHACK. LOAD PUMP CABLE SPOOL. 20.30 PREP CENTRILIFT PUMP AND MOTOR. CHECK PUMP OIL. 21.00 PICK UP P-GAUGE / UTE/INTAKE. FILL MOTOR AND PERFORM ALL MOTOR Q/A ON FLOOR. PU PUMP SECTION & BOLT ON SAME. FILL MOTOR SEALS WITH OIL. 11/09 00.05 ATTACH CABLE AND BAND 35' OF FLAT CABLE TO PUMP WITH 7 FLAT GUARDS HELD BY 40 FLAT BANDS. 00.30 PU GLM ASSEMBLY WITH PUMP HEAD AND CHECK VALVE WITH PICKER, LOWER IN WELL WITH PICKER. WIND BLOWING INTO FRONT OF WORK WINDOW AT 20 MPH. TARP FRONT OF WORK WINDOW. 02.50 ATTEMPT TO PU INJECTOR HEAD. GENERATOR ENGINE STALLED AND WON'T START, CALL MECHANIC. FOULD LOOSE WIRE ON ENGINE. ENGINE RUNNING. 05.30 PICK UP HEAD, FOUND GRIPPER BLOCK ROTATED AND DAMAGED CT, REMOVED BLOCK AND CUT OUT 5 FT OF DAMAGED CT. RUBBER CT GUIDE AT BASE OF INJECTOR HEAD FAILED WHEN WE TRIED TO RESTAB THE CT THRU THE GUIDE. REPLACED 2 7/8" GUIDE WITH 3.5" GUIDE [ONLY AVAILABLE GUIDE]. 08.30 PICK UP INJ HEAD WITH CRANE. MAKE-UP TO WINDOW. INSTALL CT CONN. W/1502, MU HARDLINE TO TANK. 10.16 FILL CT W/48 BBLS, USING LITTLE RED AND PURGE WITH 20 EXTRA BBLS OF MEOH TO TANK. PUMP AT 2.5 BPM AT 1200 PSI. PRESS TEST CT WITH 2000 PSI. STAB LOWER COIL CONNECTOR, PULL TEST WITH 30 K & PT WITH 2000 PSI. OK. RELEASE LITTLE RED. WIND AT 20 -25 MPH INTO WORK WINDOW, WIND CHILL = -50 F. 13.10 RIH WITH 2 7/8" CT, [ REEL NO. 2165 [ 8289 FT OF CT]] . ZEROED COUNTER WITH CT ATTHE WORK WINDOW HAND SLIPS FOR REFERENCE. BAND ESP CABLE EVERY 20'. 14.04 1000 FT OF CT IN HOLE, DWNWT=BK. AVEROP=18FPM. BAND EACH 20 FT, CT LOOKS GOOD, NOMARKS. 14.50 2000 FT OF CT IN HOLE, TEST ESP CABLE RESITIVITY - OK. 6 BBLS MEOH RETURNS TO TANK. 15.35 3000 FTOF CT IN HOLE, DWN WT = 16 K, UP WT =23K, 22 FPM AVE HOP. 16.20 4000 FT. OF COIL IN HOLE, DOWN WT. = 21 K UP T. =28K, 12 BBL IN MEOH. TANK 17.27 5300 FT. OF COIIL IN HOLE , DOWN. WT. = 32 K UP WT= 52 K, 27 BBL IN MEOH TANK 18.01 6000 FT OF COl L IN HOLE, DOWN WT. = 32K , UP WT = 56K, 29 BBL IN MEOH TANK, SWITCH RETURNS TO OPEN TOP TANK. 20.30 7570 FT OF CT IN HOLE, DID NOT TAG LLCV. PICK UP TO 7535 FT CTMD. UP WT = 64,000 LBS. 21.00 CT IN HOLE = 7535 FT. CT LEFT ON REEL INDICATES 7581 FT OF CT RAN. DIFFERENCE BETWEEN COUNTER DEPTH AND CT LEFT ON REEL OF 46 FT. [ LANDED CTMD = 7650 FT BKB BASED ON COUNTER AND 7696 FT BKB BASED ON LENGTH OF CT LEFT ON REEL. JOB WAS BASED ON CTMD OF 7650 FT BKB FOR BTM OF PRESS. GAUGE. WHEN LANDED. 21.20 LET FLUIDS IN WELL EQUALIZE. MU SAFETY CLAMP. 22.00 DRILL HOLE AND CUT CT AT 7535 FT CTD [CT LENGTH ONLY]. DRESS BOTH ENDS OF CT. 23.00 MAKE UP TBG HANGER, PUP JT AND CT CONN. MAKE UP LANDING JT TO TOP OF TBG HGR [LEFT HAND ACME THREADS, 10 THREADS]. M/U UPPER CT CONN. 23.50 PULL TEST WITH 70 K - OK. PRESS TEST WITH 2200 PSI - 10 MIN. OK. 11/10 00.50 MAKE CENTRILIFT SPLICE. QC ESP CABLE. 02.44 RIH AND LAND TBG HANGER. RUN IN TBG HANGER LOCK DOWN SCREWS. 03.10 PRESS TEST TBG HANGER, TRIPLEX DID NOT HAVE ENOUGH FLUID TO FILL BOPS, HAUL DIESEL, PRESS TEST SEALS TO 2000 PSI FOR 20 MIN. - OK. 05.40 DRIILL HOLE IN CT AND DRAIN FLUID, CUT CT. 06.20 BACK OUT LANDING JOINT. [12 TURNS TO RIGHT] AND PULL OUT LANDING ASSEM. WITH CHAIN HOIST. 07.00 START RIG DOWN. PICK UP INJ HEAD AND SET ON FLOAT. 08.10 DISCONNECT GUY WIRES, PICK UP WORK WINDOW AND SETON TRAILER. 10.00 PICK UP BOP STACK AND SETON SKID. 11.00 MOVE 4907 FLOAT TO END OF PAD. MOVE ALL EQUIP. AWAY FROM J-12 AND J-06 WELLHOUSES. 11.30 INSTALL 2 WAY CHECK VALVE. TO N/U ADAPTOR SPOOL AND 2 9/16" TREE. 13.00 RELEASED 90 TON CRANE, LIGHT PLANT, 2 HEATERS AND MAN LIFT. CTU PORTION OF J-12 COMPLETION DONE. MPU J-12, ESP 2 7/8" CT COMPLETION DEC 1 4 1994 Alaska Oil & Gas Cons. Commission Anchor[~..~ PAGE 1 OPERATIONS SUMMARY 1. Ran Centrilift type 146 stage GC-1200 Series 513, MODEL GPMT pump w/tandem seals and Model KME1, Series 562, 100 h.p. motor section, and CentriLift Check Valve. Ran Camco type KBMG Gas Lift Mandrel w/l" pocket, and DCK gas lift valve with DCK latch in place. Mandrel run 23 ft. above Check Valve. Ran 7535 ft OF 2 7/8" 5.468 HS-70 Coil Tubing (2.495" I.D.) Hung string off in FMC 7 1/16" X 2 7/8" Tubing Hanger. BOTTOM OF PUMP ASSEMBLY AT 7650 FT BKB. [BASED ON CTMD]. THE LLCV IS AT 7734 FT BKB. CTMD HAS BEEN SHALLOW [40 - 140 FT] ON ESP JOBS DUE TO NUMEROUS STOPS FOR CABLE BANDING [EVERY 20 F'1-J. BASED ON MEASUREMENT OF CT LEFT ON REEL, THE CTMD ON J-12 WAS 46 FT SHALLOW, SO THE BOTTOM OF THE PUMP WOULD BE AT 7696 FT USING THE LENGTH OF CT LEFT ON THE REEL. 2. Ran 7 flat cable guards with 40 flat guard bands. Ran 456 preformed bands to fasten cable to coiled tubing. 3. Inner annulus and tubing filled with10.1 ppg brine to surface. 4. KBMG mandrel run w/DCK valve and BK5 latch set for 3500 psi tbg to casing shear. 5. Tree nippled up with 2 way check in hanger. 2.5" H BPV profile. 2 7/8" FMC tubing hanger with 2 7/8" ACME LEFT HAND threads on top and 8 rd on bottom. CENTRILIFT ESP BOTTOM HOLE ASSEMBLY AND 2 7/8" CT STRING ! MAX O.D. I.D. LENGTH ITEM (InchesI (Inchesll (Feet) P- Gauge 4.50 NA 1.98 Motor 5.62 NA 11.00 Seal Section & Gas Separator 5.13 NA 12.61 Pump and Discharge head. 5.13 NA 19.66 2 7/8" 6.5# L-80 EUE 8 RD. Tubing Pup 3.67 2.441 2.20 Centdlift Check Valve 3.7 NA 0.41 Pup 2 7/8" 6.5# L-80 8 Rd. Tubing 3.67 2.441 10.23 XO Pup 2 7/8" 6.5# L-80 8 Rd. Tubing 3.67 2.441 10.01 GLM 4.7 2.347 6.47 XO Pup 2 7/8" 6.,5N L-80 8 Rd. Tubing 3.67 2.441 3.71 Coiled Tbg Conn. 4.25 2.38 1.92 TOTAL LENGTH OF CENTRILIFT ESP BHA = 80.20 FT 2-7/8" Coiled tbcj. [ REEL NO. 2165~ 8289 FT]. 2.875 2.495 7534.72 Coiled Tbcj Conn. 4.25 2.495 1.92 Pup 2 7/8" 6.5# L-80 8 Rd. Tubing 3.67 2.441 4.08 Hanger (to lock dwn screws) 6.95 2.441 0.66 RKB to hanger lock dwn screws [ RKB = 30.00 FT ABOVE GL~ 65 FT AMSL] 28.42 TOTAL MEASURED DEPTH BELOW ORIGINAL RKB 7650.00 MPU J-12, ESP 2 7/8" CT COMPLETION RECEIVED DEC I 4 1994 0il & Gas Cons. Commission Anchor~ ' PAGE 2 MPU J-12 JOB NOTES 1. NEED A 4 MAN CREW FOR CT COMPLETION UNIT, THE RIG UP AND RIG DOWN REQUIRES A LOT OF MAN HOURS AND THE ADDITIONAL COST FOR ONE MORE MAN WOULD BE COST EFFECTIVE AND LESS FATIGUING FOR PERSONNEL. 2. FOR BETTER DEPTH CONTROL, WE SHOULD CONSIDER TAGGING THE LLCV WITH THE MOTOR. THE LLCV IS A VERY HEAVILY BUILT TOOL, AS IS THE MOTOR. WE SHOULD DETERMINE WHETHER A LIGHT TAG TO DETERMINE FINAL DEPTH CONTROL IS OK. THIS WOULD SAVE SOME COMPLETION TIME AND POSSIBLY SOME CONFUSION IN THE FUTURE BY KNOWING THE ACTUAL DEPTH OF THE MOTOR AND GLM. 3. CELLULAR PHONE WORKED WELL AND EASILY SAVED 2 HRS OF OPERATION TIME. CLEAR SIGNAL. 4. RIGGING UP ON WELLHOUSE AT A 30 TO 45 DEGREE ANGLE WORKS BEST, ALLOWS FOR BETTER PLACEMENT OF OPERATIONS CAB AND PROVIDES MORE ROOM DIRECTLY IN FRONT OF WELLHOUSE. 5. JOB WENT WELL OVERALL. 2.5 DAYS TOTAL TIME, INCLUDING 8 HRS OF EQUIP. DOWNTIME. USING THE SMALL TRIPLEX WORKED OK FOR PRESS TESTIING AFTER ORIGINAL PURGE OF CT, BUT DAY TANK IS ONLY 3 BBLS AND WE LOST ONE HOUR GETTING IT FILLED. WE SHOULD HAVE THE DIESEL FUELER FILL IT WHEN HE IS ON LOCATION, TO SAVE CTU TIME. 6. HALF OF THIS JOB WAS PERFORMED WITH WIND CHILL OF -40 TO -50 F. WE NEED TO REMEMBER THAT THE CT COMPLETIONS REQUIRE A LOT OF TIME IN THE WEATHER AND OPERATIONS WILL GET MUCH SLOWER WITH WIND CHILL BELOW -40 DEG F. CREW DID VERY WELL ON THIS JOB. RECEIVED DEC 1 4 i99q Al~sk~ Oil & Gas Cons. Commission Anchor~ - MPU J-12, ESP 2 7/8" CT COMPLETION PAGE 3 MP J-12 09/18/94 2,253' FINISH BUILDING BERMS. NIPPLE UP 20" DIVERTER SYSTEM. RU FLOOR. MU BHA. FUNCTION TEST DIVERTER SYSTEM. DRLG F/112-291'. POH. FINISH MU BHA. DRLG AND MWD SURVEY F/291-2253'. 09/19/94 2,586' DRLG AND MWD SURVEY 12 1/4" HOLE F/2253-2586'. CBU. SHORT TRIP TO JARS. SLM. NO CORRECTIONS. NO PROBLEMS. CIRC AND CONDITION MUD F/CSG. POH. LD BHA. RU TO RUN CSG. RIH W/CSG TO 2566'. WASHED 45' TO BOTTOM. CIRC 1 1/2 ANNULAR VOLUMES. TEST LINES. RD CEMENT HEAD AND LANDING JT. RU AND PUMP TOP JOB. RD HALLIBURTON. CLEAR FLOOR. ND DIVERTER SYSTEM. INSTALL SPEED HEAD. NU BOPE EQUIP. INSTALL TEST PLUG. 09/20/94 4,441' TEST BOPE W/ANNULAR. PULL TEST PLUG. INSTALL LONG WEAR BUSHING. SERVICE TOP DRIVE. MU BHA. TEST MWD. RIH TO 2482'. BREAK CIRC. TEST 9 5/8" CSG. DRILL OUT FE AND CEMENT + 10' NEW HOLE TO 2596'. CIRC AND CONDITION MUD. PERFORM FIT. DRLG 8 1/2" HOLE AND MWD SURVEY F/2596-3637'. PUMP SWEEP. SHORT TRIP TO SHOE. HOLE TIGHT. REAM SEVERAL PLACES F/2650-3630'. DRLG 8 1/2" HOLE AND MWD SURVEY F/3637-4441' 09/21/94 5,252' DRLG AND MWD SURVEY F/4441-4676'. PUMP LO/HI ViS SWEEP. POH W/ 9 STDS. HOLE SWABBING. RIH. PUMP SWEEP. SHORT TRIP TO SHOE. NO PROBLEMS. DRLG AND MWD SURVEY F/4676-4878'. PUMP SWEEP. DROP EMS PILL. POH. SLM. NO CORRECTION. NO HOLE PROBLEMS. CHANGE BHA. DOWNLOAD MWD. MU TURBINE, CDN AND CDR. LOAD SOURCE. ORIENT TOOLS. TEST MWD TOOLS. SLIP AND CUT DRLG LINE. SERVICE TOP DRIVE. RIH 'FO 4258'. LOG F/4258-4758'. BENCHMARK SURVEY @4798'. DRLG AND MWD SURVEY F/4878-5252'. 09/22/94 7,260' DRILL F/5252-6004'. CIRC BOTTOMS UP. POH TO 4710'. MAKE LOGGING PASS FROM 4710-4520'. RIH. REAM LAST STAND TO BOTTOM. NO PROBLEMS, NO FILL. DRILL 8 1/2" HOLE F/6004-7260'. 09/23/94 8,250' RECEIVED DEC 1 4 1994 Alaska rJil & Gas Cons. Commission Anchor[ DRILL F/7260-7391'. CIRC BOTTOMS UP. SHORT TRIP - 15 STANDS. NO PROBLEMS. DRILL F/7391-8250'. 09/24/94 8,320' DRILL FROM 8250-8320'. FINISH CIRC HI-VIS SWEEP AROUND. SHORT TRIP 5 STANDS. IMPROPER FILL. WELL FLOWING SLIGHTLY. RIH. SHUT INN-NO PRESSURE. CIRC AFTER 800 STROKES GAS TO SURFACE, MUD OVER TABLE. SHUT WELL IN-NO PRESSURE. CIRC THROUGH OPEN CHOKE AND WEIGHT UP TO 10.6 PPG. OPEN BAG. WELL STATIC. CIRC BO']-FOMS UP. PUMP 20 STANDS OUT OF HOLE. RIH SLOWLY. CIRC AND COND MUD. PUMP 20 STANDS OUT. CONTINUE RIH TO 4840'. SPOT 50 BBL LCM PILL. POH TO CASING SHOE. CHANGE TOP RAMS TO 7". FINISH POH. LD BHA AND SOURCE. PULL WEAR RING. TEST SEALS AND RU TO RUN 7" CASING. 09/25/94 8,320' FINISH RU TO TUN CASING. RIH WITH 7" CASING SLOWLY. ONLY PARTIAL RETURNS BELOW 4300'. LOST A TOTAL OF 170 BBL'S WHILE RUNNING CASING. SHOE @8299'. ATTEMPT TO CIRC AND WORK PIPE. RU HOWCO AND TEST LINES. DISPLACE W/RIG PUMPS AND BUMP PLUG. FLOATS HELD. PRESSURE UP AND OPEN ES CEMENTER. ATTEMPT TO CIRC. PUMPED 25 BBL'S WITH NO RETURNS. PUMP 75 BBL'S WATER, 70 BBL'S SPACER AND 146 SXS "G" @15.8 PPG. DISPLACE WITH RIG. BUMP PLUG. FLATS HELD. NO RETURNS DURING 2CD STAGE. CLEAR RIG FLOOR. BACK OUT LANDING JT AND CHANGE BAILS. INSTALL PACK-OFF AND TEST SAME. INSTALL WEAR RING. LD 5" DP FROM DERRICK IN MOUSE HOLE. 09/26/94 8,320' TEST SEAL. INSTALL WEAR RING. CHANGE TOP DRIVE OVER TO 3 1/2". RACK 5 STANDS HWDP ON LEFT SIDE OF DERRICK. LOAD AND STRAP BHA AND 3 1/2" DP. PU BIT, SCRAPER, 6-DC, AND 3 1/2" DP AND RIH. TAG CEMENT @4845'. DRILL CEMENT AND "ES" CEMENTER FROM 4845-4865'. FINISH PU 3 1/2" DP AND RIH TO LANDING COLLAR @8212'. TEST CASING, OK. CIRC BOTTOMS UP. PUMP 30 BBL'S HI-VIS SWEEP, 50 BBL'S DIRT MAGNET, 30 BBL'S HI-VIS SWEEP. FILTERED SOURCE WATER 5NTU IN; 35 NTU OUT. ADDED CORREXlT LAST CIRC. POH. LD 3 1/2" DP. FREEZE PROTECT TOP 2000' WITH DIESEL. PULL WEAR RING AND CHANGE TOP RAMS TO 5". ND 13 5/8" BOPE AND CHANGE TOP DRIVE TO 5". 09/27/94 8,320' FINISH CHANGING OUT TOP DRIVE TO 5". ATTEMPT TO INSTALL FMC FALSE BOWL IN WKM TUBING HEAD - TOO LONG. HAD TO BE MACHINED OFF. INSTALLED ADDITIONAL SEAL AND INSTALLED FALSE BOWL AGAIN RECEIVED DEC 1 4 1994 0it i Gas CoDs, Commission Anchor~ AND RE-TORQUE. N/U ADAPTER FLANGE WITH FMC BIG BORE VALVE. TEST SAME. RELEASE RIG @1500 HR'S ON 09/26/94. DEC 1 4 1994 Aiaska Oil & Gas Cons. Commission ,~nchor~ ~ ~EPANY BP ~ i,~ MBJ-12 LOC~TI~ 1 MIIfl, E POINT LOCATION 2 AIASIKA MAGN~IC DECLINATION GRID ~~I~_.E ANGLE 21-S~-94 WELL HEAD LOCATION: LAT(N/-S) AZIMUTH FROM ROTARY TABLE TO TA~;ET IS TIE IN POINT(TIP) MTA~ DE~q~H 116,04 TRUE VERT DEPTH 116,00 INCLINATION 0,00 AZIMUTH LATITUDE(N/-S) D~'~TdRE(E/-W) MICROFILMED DEP(E/-W) 0,00 RECEIVED DEC 1 4 1994 Alaska Oil & Gas Cons. Commission Anchor~. , PAG£ NO. 2 mPJ-12 ~qSUR~ IKIl~ VERTICAL DIiPTH DEPTH ft ft. ft 116,00 0.0 116,00 180,88 64,9 160,86 265.50 84.6 265,S0 359,90 94,5 359,98 451.1I 91.1 451,10 TARG~"I STATION AZIMUTH LATITUDE SECTION IHCLN. N/-S ft deq deq ft 0,00 0,00 0,00 0.00 0.08 0,23 319.72 0,10 0.47 0.50 327.~ 0,54 1,02 0.48 515,52 1,17 1,35 0,59 291.78 1.62 DEF'ARTlJR~ DISPLACBIEN? ~t AZII~JTH E/-W ft ft dea 0,00 0,® -0,08 0,13 319.72 -0,39 0,67 323,95 -0,89 1,47 3~,64 -1,60 2,27 315,34 DLS tOOft 0,00 0,35 0,.33 O,lt 0,27 543,57 92.5 543,55 636.56 ~,0 636.45 795,18 158,6 794,52 913,28 118,1 911,54 1006.07 92,8 1002,76 2,67 1,53 18,06 2,97 -1,66 3,40 330.86 1,74 6.24 3.15 .32.88 6,30 0,12 6.30 1.06 1,84 18,69 6,28 21,66 18.02 5,69 18,90 17.52 34,30 9,19 18,21 32,98 11,02 34,77 18.46 2.50 50,89 11.84 21,80 46.86 16.87 51,69 19.05 2,94 1099,34 1194.02 12.70 1382,97 1478,46 ?3,3 1073.59 94,7 1184,70 96.0 1275..A0 93,0 136.1,86 95,5 1449,59 71.57 14,44 21,66 ..58,55 24,72 72,87 19,63 2.78 96.67 17.06 21,25 ?2,48 34,11 96,57 20,25 2,76 127.08 20,39 14.51 121.80 43,41 129,30 19,61 4,13 161,59 23,37 13,51 155,41 51,77 163.81 18.42 3,23 199,23 23,17 11,75 192.21 60,09 201,38 17,~ 0,68 1571,17 1667,91 1762,19 1857 1953,27 '~,7 1534,41 96,7 1622,50 94,3 1708,13 ?575,4 t773,63 95,7 1678,56 ~..~.,56 24.41 13,23 228.71 276,46. 24,42 12,46 267,70 315,75 25,06 15,64 305.96 357,30 26,?5 15,22 346.27 401,68 28,51 11,~ 389,56 68,25 238.66 16.62 1.45 77,15 278,59 16,08 0.32 86.,75 318,02 15,83 1,56. 97,~ 359,63 15,78 1,99 108,26 404,32 15,53 2,29 2048.01 2142,~ 2237,71 2332,32 2427.57 94,7 1961,63 94.0 2044,36 95.7 2128.20 94,6 2210,92 95.2 22F3,92 446,85 28,48 9,46 433.96 491,8.5 28,76 11,92 478,21 537,86 28.68 13,63 523.17 583,73 29,22 7,84 568,26 630,45 29.54 8,03 614,54 116,63 449,.36 15,04 1,22 124,99 494,27 14,65 1.29 135,19 540.~ 14,47 0.87 143,73 5&6.,16 14.19 150,18 632.63 13,73 0,36_ 2507,06 2625,25 2721,49 2814.60 2910.89 79.5 2363,02 118,2 2465,92 96,2 2549.47 93,1 2630.07 96,3 2712,92 669.73 29,69 8,20 653,43 727,89 29,27 10.65 710.81 775.62 ,30,22 10,04 757.78 822,19 29.89 13,47 803,42 871.14 31,36 ll,2'y 851,32 155,73 671,73 15,40 0,22 165,25 729,76 13.09 1.08 173,82 777,46 12,92 183,31 824.07 12,85 1,88 173,80 873,11 12,~2 t,91 3003,~ 3098,69 3194,95 3289,34 3383,77 92,5 2791,79 ~,3 2872,&6 96,3 2954,75 94,4 ,30034,91 94,4 3114,98 919,38 31,66 13,62 898.52 969,31 31,76 14,09 947,16 1019,85 31,69 8,58 996,76 I069,66 32,04 7,31 1046,11 1119,70 31,98 6,?3 1(F/5,78 204,23 721,44 12.81 1.35 216,23 971,53 12,.~ 0,29 226,18 1022,10 12,78 3.01 233,06. 1071,75 12.56 239,26 1121,.~, 12,32 0,22 3476,47 3570.~ 3670,89 3764,63 -~58.10 94,7 3195,78 92.4 3275,11 tO0.O 3360.&3 93.9 3441.09 93.3 3521.25 1169,07 30,?3 12,~ !144.49 1216,44 ,30,84 12,45 1190,85 1267.62 31,11 11,99 1241,14 1316.55 31,52 12,96 1288.81 1.364,15 29.97 10.80 1335.~ 247,38 1170,92 12.20 3.04 257,45 1218,36 12,20 0.23 268,34 1269.62 12,20 0,36. 278,88 1318.64 12.21 0,69 288.72 13_56.31 12.20 2.03 P~£ ~. r~J-12 II~SL~B) I~ VBr(TICAL D~TH ft ft ft ~3,~ ~7 ~.~ ~,2 ~.62 4143.60 94.6 3768,58 4~7,~ ~,9 ~9.74 4~.91 94,4 TARGET S%ATION AZIMUTH LATIll]~£ S]~C?ION INCIJh N/-S ft deg d~ ft 1411,94 29,98 12,31 1382,32 1459,39. 29,95 12,26 1428,76 150_6,55 29,99 13,18 1474,86 1553,76 30,48 11,65 1521,06 1.~1,65 3030,58 11,31 1568,03 DI~ARTUR£ glSPLAC~7 at AZIMUTH it it deg _~8,30 1414,14 12,18 3008,42 1461,67 12,18 3!8.82 1508.93 12.20 ~8,99 1556.23 12.20 ~8,52 1604,16 12,18 de~/ lOOft 0,79 0,04 0,49 0,97 0,21 4424,17 4515,04 4609,15 4708,64 4607.22 9'2,3 4010.45 90.9 4066..54 94,1 4169,6.0 ?9.5 4255,19 96,6 4339,92 1648,56 30,60 11,24 1614,08 1694.&0 30.66 12,12 1659.41 1742,73 30,65 11.32 1706.39 1793,39 30,67 12,93 1755.99 1843,65 :30.80 12,66. 1805.12 347,70 1651,10 12.16 0,04 · 357.08 1697,39 12.14 366,82 1745,38 12.13 0.43 377.48 1796,10 12,13 0,63 368,64 1646,48 12,15 0,20 4840,09 4~J3.~ 5029,01 5122,55 5215,76 · 32,9 4366,17 93,5 4448.50 95.5 4530,36 ?3,5 4610,36. 93,2 4/)69,84 1860,40 30,65 13,76 1821,47 1908.03 30,86 13.68 1867,90 1956.99 31,05 13.18 1915,./6 2005,~ 31,37 12,29 1962,94 2053,94 31,61 12,98 2010,44 392,48 1863,27 12,16 1.78 40.3,81 1911,05 12,20 0,23 415.21 1960.14 12,23 0,34 425,90 2(X)8,61 12,24 0.60 436,55 2057,29 12,25 0,46 5308,20 5401,84 5497,10 5590,82 5666,34 92,4 4768,50 '~,6 4848.03 95,3 4928,84 93,7 5008.42 f5.5 5069,49 2102,40 31,77 12.28 2057.~ 215t,77. 31,95 11.16 21Q6,~ 2202,18 31,98 10.29 2155.77 2251.69 31,~ 9,43 2204,55 2302,20 32,06 7,72 2254,50 447,16 2105.85 12,26 0,44 457,20 2155,28 12,25 0.66 466,59 2205,69 12,21 0.48 475,07 2255,16 12,16 0.52 482,60 2305,56 12.08 0,~ 5780,33 5675.26 5967,90 ./'.067,54 6165.76 94,0 5169.19 94,9 52~.16 92.6 5329.48 99,6 5414,5.6 98,2 5498,19 2352.02 31,96 9,38 2303,77 2.401.57 30.97 8.54 2352,71 2'.44.9,43 31,25 7,95 2400,08 2501,2_7 31,46 9,17 2451,35 2552,78 31.60 8,28 2502,27 490.01 2355,30 12,01 0,94 497,73 2404,79 11,95 1,15 504,59 2452.55 11.67 0.45 512,31 2504.31 11,80 0.67 520.12 2555.75 11,74 0,59 6258.,69 6252,65 6448,71 6542,29 6636,53 92,9 5577,04 94.0 5656,73 96,1 5738,93 ~,6 5819.55 94,2 551q4),79 2601,~ ~,10 7,57 2550,97 2651.73 31,90 8,64 2600,27 2701,44 30,43 8,07 2649,45 2748,94 30,59 7,22 2696,54 2796,66. 30,28 7,96 2743.66 526,90 2~4,62 11.67 0.52 533,92 2654.51 11,60 0.64 541,15 2704,15 11,54 1,56 547.47 2/-51,55 11,48 0,49 553,77 2779,18 11,41 0.51 6731,24 6826,15 6920,06 7012,93 7107,78 94,7 5982,95 94,9 6065,79 9'3,9 6148.62 .'-72,9 6231,97 94,9 6318,17 2843,77 29,37 8,64 27?0,46 2890,11 29,08 9,13 2836,23 2934,34 27,14 6,83 2880,03 2975,25 25,18 6,83 2920,68 3014,~ 24,17 5,65 2960,04 S60,65 2846,22 11,36 1,07 567,89 2692,53 11,32 0.34 574,06 2936,69 11,27 2,37 578,93 2977,51 11,21 2,11 583,24 .3016.96 11,15 1,19 7202.69 7294,47 7392.21 7406,65 758,2.26 95.1 6405,53 91,6 6490,76 97,7 6562,61 94,4 6671,65 95,6 6761.79 -~52,32 22,37 6.26 L~7.41 3065,76 20.53 6.03 3030,71 3119,14 19,46 5,04 2063,?'7 3150,54 19,44 5,94 .9~5,30 3182.36 19,50 5,91 3127,00 567,13 3054.37 11,08 1,91 5?0,72 3087.74 11.03 2,01 593,95 3121.03 10.97 1.13 596,96 3152,34 10.92 0,32 600,25 3184,09 10,87 i:'AGE NO. 4 ~PJ-12 ************* ANAI)RILL SU~'~ CAIDJb~TIONS *******~ CIRCLF~AR ARC DEPTH DI~PTH ft ft ft 7679,33 97,1 6653,37 7772,70 93,4 6941,60 7873,66 101,2 7037,31 79./95,86 95,0 7127,20 8063.89 95.0 7217,23 TARGET ~A?ION AZI~dTH SECTION IHCLN. ft de9 de9 ~14.49 19.~ ~,~ 18,93 3,~ 3~7.~ t~.~ 359,56 ~7,~ 18,49 1.~ LATITUDE I)~ARlqJRZ OlSPLACBIENT ~t AZI~TH OLS it ft ft deq kQOft 3159,06 603,17 ~1.A,13 10,81 0,55 3189,53 605,19 3246,44 10,74 0,59 3222,27 606,60 327B,87 10,.~. 0,40 3252,99 6~.?B 3309,13 10,57 0,78 -3263.41 607,20 3339.09. 10.48 0.70 0159.35 95.5 727.81 &230,07 70,7 7374,?8 PR[kI£CTED TO TI) 8322.00 91,9 7462.32 3367.81 18,31 1,30 3389,75 lB,16 1,~ · 3313,54 ,.q)7,87 3368,84 10,40 0,16 3.335,67 606,39 3390,70 10,34 0,21 3418.17 18.20 1.30 .3364.35 3419.03 10,26 0,04 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 December 19, 1994 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD DEPTH CORRECTED CDR & CDN TVD for well MPJ-12, Job # 94386 was sent to' BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 3 Bluelines 1 Film State of Alas a~'~'~ Alaska Oil &lGas Conservation Comm. Attn: Larry G~nt 3001 Po rcu pin e"Bd.V_~ Anchorage, Alaska I Bluelir~'~ ?' OXY USA, Inc 1 Blueline Attn: Erma Galindo 1 RFolded Sepia P.O. Box 50250 Midland, Texas 79710 Sent Certifj,ed Mail P~7~4,1 382 PLEASE ACKNOWLEDGE RECEIPT~Y/SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 Schlumberger Courier: Date Delivered: Received By: 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 November 14, 1994 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-$ 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the LWD DEPTH CORRECTED CDR & CDN for well ~, Job# 94828 was sent to: BP Exploration (Alaska) Inc. State of Alaska Alaska Oil & Gas Conservation Comm. Attn: Larry Grant "'--~001 Porcupine Drive A-h'cbe~_~ a ska 99501 1 OH LIS Tape 1 Depth Shift Monitor Plot 3 Bluelines 1 Film Returning ~CDN, CDR & CDN - TVD ~~Fihn -~----__._~.... OXY USA, Inc Attn: Erma Galindo P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape I Blueline 1 RFolded Sepia Sent Certified Mail P 676 541 365 NOV g SIGNING AND RETURNIN,~at:;;:~ I~.COPY EAOR;YF¢): BP EXPLORATION (ALAS~) INC. SCHLUMBERGER GEOQ~T '" PETROTECHNICAL DATA CENTER, MB3-3 500 WEST INTERNAflONAL AIRPORT ROAD 900 EAST BENSON BLVD. ANCHORAGE, ALAS~ 99518-1199 ANCHORAGE, ALAS~ 99519-6612 Schlumberger Courier: Date Delivered: Received By: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 18 October 1994 Transmittal of Data ECC #: 6288.00 Sent by: U.S. MAIL Data: LDWG Dear Sir/Madam, Reference: BP MPJ-12 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 SBT/GR/CCL FINAL BL Run # 1 1 PFC/PERF/GR FINAL BL Run # 1 1 GR/COLLAR FINAL BL Run # 1 1 SBT/GR/CCL RF SEPIA Run # 1 1 PFC/PERF/GR RF SEPIA Run # 1 ! GR/COL!AR RF SEPIA Run # 1 P~e~--~lgn an~ return to: Atlas W~rellne Services Received by: 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Or FAX ~o (907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 2 November 1994 Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PFC/PACKER FINAL BL 1 PFC/PERF FINAL BL 1 PFC/PACKER RF SEPIA 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PACKER FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PACKER RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 6279.01 6288.01 Please si~n nnd ~*-'~n t~- A~las W~rmlinc Se=vlc=o 5600 B Street Suite 201 Anchorage, AK 99518 eceive by:~/~/~~4~ //'///~ Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 28 October 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL /~ # DESCRIPTION }K/~-ll (08-11-13) 1 PDK/GR LDWG TAPE+LST MPJ-13 1 GR/CCL LDWG TAPE+LST ECC No. Run # 1 954.04 Run ~ 1 3043.04 Run # 1 6279.00 Run # 1 6280.01 Run # 1 6285.00 Run # 1 6286.00 Run # 1 6288.00 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney O~ E~X ~o (907) 563-7803 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR · 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 13, 1994 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 19662 Anchorage, AK 99519-6612 Re: Milne Point Unit MPJ-12 BP Exploration (Alaska), Inc. Permit No: 94-118 Sur. Loc. 2374'NSL, 3202'WEL, Sec. 28, T13N, R10E, UM Btmhole Loc. 457'NSL, 2574'WEL, Sec. 21, T13N, R10E, UM Dear Mr. Clark: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David BY ORDER OF THE iSSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. '--" STATE OF ALASKA ALASKA OiL. AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type' of work Drill [] Redriill"lIlb. Type of well. Exploratoryl-'l Stratigraphic Testl-1 Development Oill~ Re-Entry [] DeepenI'-11 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator ~5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (AJaska) /nc. KBE = 65' feet Mi/ne Point Unit - Kuparuk 3. Address 6. Property Designation Sands P. O. Box 196612. Anchorage. Alaska 99519-6612 ADL 315848 4. Location of well at surface 7. Unit or property Name 11. Type Bond(~,o 2o 2374'NSL, 3202' WEL, SEC. 28, T13N, R10E Milne Point Unit At top of productive interval 8. Well number Number 319'NS1_, 2600' WEL, SEC. 21, T13N, RIOE MPJ-12 2S100302630-277 At total depth 9. Approximate spud date Amount 457' NSL, 2574' WEL, SEC. 21, T13N, RIOE 9/14/94 $200,000.00 , 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(MDa~dWD) property line ADL 25906-457' feet No close approach feet 2560 8391' MD/7366' TVD feet 16. To be completed for deviated wells 17. 'Anticipated pressure (see 20 ^^c 25.035 Kickoff depth . ~soo feet Maximum hole anc.:jle 37 o Maximum surface 2850 psig At total depth (TVD) 7000/3550 pslg 18. Casing Program ' ' Settin~ Depth raze Specifications Top Bottom' Quantity of cement Hole CaSing WeigJ3t Grade Coupling Length M D TVD MD TVD (include stage data) 24" 13-3/8" 54.5# K-55 .... Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 36#~,]~O>~ BTRC 2469' 31' 31' 2500' 2469' 504 sx PF'E'/250 sx"G"/250 sx 'E" , 8-1/2" 7" 26~ L-80 NSCC 8361' 30' 30' 8391' 7366' 203 sx "G"/146 sx "G" 1~. 1o be completed for Redrill, Re-entry, and Deopen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor u, co RECEIVED Intermediate Production SEP - 9 1994 Liner Perforation depth: measured Alr~ska 0il & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee [] Property plat Fl' BOP Sketch [] Diverter Sketch [] Drilling program[] 'Drilling fluid program [] Time vs depth plot [] Refraction analysis I-! Seabed reportl-'l 20 AAC 25.050 requirementsr-I 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~6¢,., ~)c~,,,-~~('~'~-v- ~ . Title Dr#1in~l Engineer Supervisor Date ' '" Commission Use Only "Pe[-'mit Nur~ber JAPl'number IApproval date _ JSee cover letter ~¢¢ - ,/./~:' . J50: <m.2.. ¢- 2'- .2-- .5"¢ ~/ J ~'-'-/r,,,¢ --~'~-~ Jfor other, requirements Conditions of approval Samples required [] Yes ~ No Mud log required []Yes J~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No Required working pressure for BOPE []2M; 1-13M; ,I~5M; I-I10M; I-I15M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner me commission Form 10-401 Rev. 12-1-85 Submit in tff Well Name: ] MPJ-12 Well Plan Summary Type of Well (producer or injector): l Kuparuk Producer I Surface LoCation: Target LocatiOn: Bottom Hole Location: 2374 NSL 3202 WEL Sec 28 T13N R10E UM., AK. 0319 NSL 2600 WEL Sec 21 T13N R10E UM., AK. 0457 NSL 2574 WEL Sec'21 T13N R10E UM., AK. [ AFE' Number: ! 330077 ] I Estimated Start Date: ! 9/14/94 MD: !8391' I Well Design (conventional, slimhole, etc.): [ Rig: ! Nabors 22-E [ [ Operating days to complete: [ 8 ["~I'VD: 17366' bkb I iKBE: [ Milne Point Ultra Slimhole 7LS 165' Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1816 1815 NA 4321 . 3945 Top of Schrader Bluff (West Sak) Sands,. OA 4522 4105 Seabee Shale 4837 4355 Base of tile Schrader Bluff (West Sak) Sands HRZ 7464 6495 High Resistivity Streak Top Kup 7635 6655 Kuparuk Cap Rock Top C Sand 7832 6840 Target 7981 6980 Kuparuk A Sand Total Depth 8391 7366 Casing/Tubin ram: Hole Size Csg/T Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 13 3/8" 54.5# K-55 Weld 80 32/32 112/112 12 1/4" 9 5/8" ~ '-5~ L-80 btrc 2469 31/31 2500/246c~ 8 1/2" 7" 26# L-80 Nscc 8361 30/30 8391/736{ Internal yield pressure of the 7" 26g casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7100 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3550 psi is 2850 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: I Open Hole Logs: Surface Intermediate Final ICased Hole Logs: MWD Directional Only N/A 1. Insert Bit to Seabee Base w/MWD Dir/GR (DLS). 2. PDC Bit f/Seabee to TD w/MWD Dir/GR/CDR/CDN. GR/CCL will be run in 7" casing to coincide with Wireline Perforating Operations without a Rig on the well. CBL run only if necessary. RECEIVED S EP - 9 1594 Alaska Oil & Gas Cons. Commission Anchora~e A GR/CCL Log will be obtained in the 7" casing in conjunction with WL Perforating. Mud Logging is not required. Mud Program: I Special design considerations I None- SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PP G) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.6 90 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: ] None- LSND freshwater mud Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.2 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: I1500 IMaximum Hole Angle: Close Approach Well: 37 degrees (No Shut Ins) Disposal'. Cuttings Handling' CC2A Fluid Handling: All drilling and completion fluids can be annular injected. Otherwise, Haul to CC2A. Annular Injection: The MPJ-12 annulus is permitted for drilling & completion fluid injection. DO NOT EXCEED 35,000 BBL$ IN ANY ANNULUS. AREA WELL PREY VOL PERMITTED PERMITTED I INJECTED VOL (aBES) (aBES) Milne Point MPJ-12 0 35,000 5/3/94 thru Milne Point MPJ-06 6500 35,000 5/3/94 thru Milne Point MPJ-09 3900 35,000 5/3/94 thru FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annulus was injected into to avoid freezing. R£EEIVED Gas Cons. Commission Anch0ra0e I · 2. 3. 4. 5. . . . 10. 11. 12. 13. 14. 15. MPJ-12 Proposed Summary of Operations Ddll and Set 13-3/8" Conductor. Weld a starting head on conductor. Prepare location for dg move. MIRU Nabors 22E drilling dg. NU and test 20" Diverter system. Build Spud Mud. Ddll a 12-1/4" sudace hole and run and cement 9-5/8" casing. Run only Dir MWD (No LWD Required). ND 20" Diverter, NU and Test 13-5/8" BOPE. RIH w/Insert bit on Low Speed/High Torque Motor, and Directional MWD/GR (DLS). Test 9-5/8" casing to 3000 psig, Ddll out float equipment and 10 feet of new formation, Pedorm a LOT (Do not exceed 12.5 ppg). Ddll ahead to the base of the Schrader Bluff (West Sack) into the Seabee Shale and POOH. LD the Insert Bit and Motor. MU a Hughes R417G PDC bit on a turbine, with Directional/Gamma Ray, Resistivity/Neutron/Density (Triple Combo) MWD/LWD tools. RIH. Drill 8.5" hole to TD and Run and Cement 7" casing (2 Stage Cement Job to cover the Schrader Bluff). This hole section will be logged LWD with Triple Combo (G R/Res/Neu/Dens). RIH while PU 3-1/2" drill pipe with 7" 26# bit and scraper. Ddll out ES Cementer, RIH to PBTD, displace the ddlling mud out of the hole with source water, while performing a casing wash, filter source water to 2 micron absolute. POOH L/D 3-1/2" ddll pipe. Freeze protect the well. ND BOPE, NU the False Bowl and Dry Hole Tree to Prepare Well for Pedoration and Frac Work. RDMO Nabors 22E ddlling dg to ddll MPJ-13. Well will be completed with Coil Tubing deployed ESP. RECEIVED SEP-9 1994 Alaska 0il & Gas Cons. Commission Anchoracje MPJ-12 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE' 9-5/8" CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE' ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 504 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost E ADDITIVES: Retarder WEIGHT: 15.6 ppg APPROX NO SACKS: 250 YIELD: 0.96 cu ft/sk. MIX WATER: 3.7 gal/sk CENTRALIZER PLACEMENT: 1. I Bowspring centralizer per joint of 9-5/8" casing on bottom 10 joints of casing (10 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program an, ensure compatibility pdor to pumping job. Ensure thickening times are adequate relative to purr requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30% 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with excess and from 1500' md to sudace with 100% excess. 4. 80'rnd 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. RECEIVED S EP '" 9 199 , Gas Cons. Commission Anch0rau~, MPJ-12 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT ,,lOB A(;RO$$ THE KUPARUK INTERVAL: CIRC. TEMP: 140° F BHST 170 deg Fat 7040'TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 203 FLUID LOSS: < 50cc/30 min @ 140° F MIX WATER: 5.0 gal/sk THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE I! CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS CIRC. TEMP: 60° F BHST 80 deg F at 7040' TVDSS. SPACER: 75 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344, 2.0% CaCI2 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 146 THICKENING TIME: 4 hours @ 50 FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 21 joints of 7" Cas total). This will cover 300' above the C Sand. 2. 7" x 8-1/4"Straight'Blade Rigid Centralizers-- one per joint from 4800' - 4000' to cover the S¢ Bluffs Sands (20 Total). 3. Run one 7"x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4"Straight Blade Rigid Centralizers needed is 63. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud progra ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to p~ job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 750' rnd above the C Sand with 30% excess. 2. Stage 2 cement volume is calculated to coverfrom the OG base to the to.[0~~~/~ Top with 30% excess. Rl:t /vcu SEP -'9 1994 0ii & Gas Cons. Commission Anch0ra¢ .J. ~ · Imj"N~l ! 1%1.--]1 I I II 11 I&W'[ % .k ~-- ' PRUDHO'E ..... BAY Marker !d~fiEstion MO BKB SE~TN iNCLN A). KB ! 0 0 0 O. O0 B) KOP BUILO 2.5/100 ~500 1500 0 0.00 C) END OF 2,5/100 BUILO 8995 2892 472 37.38 D)-START 2/~00 DROP 67¢J 5844 2727 37.38 E) END OF 2/JO0 DROP 7582 6604 3ta3 20,00 F)'---- fARBgT .... 798~ 6980 3~79 20.00 DR:[ ;'L'T'NG GROU¢ ........... MPJ-]2 (PO2) VERTICAL SECTION VIEW !Section at' :J0,43 TVD Scale.' ~. ~.ncn = 1000 feel TO B39~_ 7366 34,?.0 .~0.00 Oep Scale · ~. ;inch = ]000 feet · ] I I )5 ............ ' j i-~- ~---q~ ' ........... ~ r ~'. ...... ---m ..... ., , .... , , ~. ..,, · ,, , ,., .... - RE6EIIIED . ....... ............... _, . . ... , ._Ai ka 0il & Gas Cnn~ J ~ ~nchor~' - ........ " "~" '" . ~[~- ~ ..... r .... ~ ........... ~i~- ~- ..... ~'- - - - ~-- - ~- - ' ~ ~ ~ ~ ~ , -.- ,- - T -- ~[ r - ~ ~ ~ .......... : .................. / I ; : ! ....... .... , -. . ...... ..... ~ .... ,, ~ j- · ...... ~ ....... = .......... -iooo -5o0, 0 500 looo ~500 ~000 2500 3000 3~0o 4000 4500 5000 5500 6000 sec(ion Departure .._ I ..... II .... Ill J mill ,. I 15RUDHOI~' ...... -BAY DR'T _LIN"~- GROUP ............. I --' I .... , , ~ ................ i, . . iii i ii i i 7 ~- iiiill . i i . ................ · II ii .,l i H~rk~r Identifioa~ion ND N/~ ~, ~ o o o MPJ- ::t2 PO2 O)'. START 2/~00 OflOP 67~_~ ~68~ 494~ .......... EJ ENO OF 2/4_00 DROP 758~_ 309! 569 CLOSURE ' 3420 feet at AZimuth ~0 43 ' Fl: TARGET .... 798~ 3225 594 · Gl' TO 839~ 236~ 619 DECL];NAT];ON,' 30.000 E SCALE ' ~ inch = BO0 feet. DRA~IN ' O9/Og/g4 ii Ansdri ]] Schlumberger mi .i mill t ~ i .-.O00-. ,,,. I · ' rAgGET 30oo-;: 'i" i ........ ; ' 2700 .... I 2400 .... ' 2JO0 .... , ......... i ....... . ~oo .................... I~. ! ...... I .................. . ' , ~00- - ---- ! . ~oo . , ~ & 6as ~ 300 .... ! t AI~ ~k~ Oil , Cons .Commj ,ssion__ .... F=:=: ..... I '" i ......... ¢ nchora,~ __ 0 i' ~' · ; .... ~ :- _ ' U') i ~' ~oo-i' i I"' I I ' I .... 300 O' 300 600 gO0 1200' i500 ~800 ~iO0 2400 2700 3000 3300 3600 3900 F' k'EST .... iii i [~a~r~]~ fC):93 NPJJ2PO~ ~:1.5£ tO~ 3~ ,~ ~;, ...... TOTAL P.05 WELL PERMIT CHECKLIST PROGRAM: exp [] dev~ redrll [] serv [] ~/EL o loFF .C ADMINISTRATION 2. 3. 4. 5. 6. 7o 8. 9. 10. 11. 12. 13. Permit fee attached .................. ?YiY Lease number appropriate ............... Unique well name and number ............... Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wetlbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force .......... Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... ENGINEERING ~ N N N N N N N N N N N N N APPR 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ............... Y~ N Surface casing protects all known USDWs ........ ~ N CMT vol adequate to circulate on conductor & surf ecg.. N CMT vol adequate to tie-in long string to surf csg . . CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. ~ N If a re-drill, has a 10-403 for abndnmnt been approved.4 Adequate wellbore separation proposed ......... .~ N If diverter required, is it adequate .......... ~ N Drilling fluid program schematic & equip list adequate .~ N BOPEs adequate ............. ~_ ...... .~ N BOPE press rating adequate; test to ~~ psig.~ N Choke manifold complies w/API RP-53 (May 84) ....... Work will occur without operation shutdown ....... ~ N Is presence of E2S gas probable ............. Y GEOLOGY APPR D TE / 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y /~N~ 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-s~ore) ........ /Y N 34. Contact name/phone for weekly progress reports . . . / . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: ~w~ C~mments/Instructions: HOW~o - A:~=ORMS~cheklist rev 03/94 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 simp!ify finding information, informati;3n of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category'of information. MPJ- 12 MILNE POINT OCT } 1 ~994 Run 1: 14 - October - 1994 GPJCCL Cased Hole 76 HIC..ROFI .... l/$/~,/-- AILAS Atlas Wireline Services Tape Subfile 2 is type: L~ TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPJ - 12 500292250600 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 19-OCT-94 6288.00 L. KOENN J. FOX 28 13N 10E 2374 3202 64.65 64.65 35.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 2566.0 40.00 PRODUCTION STRING 7.000 8299.0 26.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS ATLAS WIRELINE SERVICES PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ GR/CCL Cased Hole. EQUIVALENT UNSHIFTED DEPTH REMARKS: *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (UPPER MAIN) & PASS 2 (LOWER MAIN) WERE NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG TIED TO MAGNETIC MARKS. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY MPU TOOL CODE START DEPTH STOP DEPTH GRCH 3928.0 4866.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS MPU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (UPPER MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN WN FN COUN STAT * FORMAT RECORD : BP EXPLORATION (ALASKA) : MPJ- 12 : MILNE POINT : NORTH SLOPE : ALASKA (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRcH SBT 68 1 GAPI 2 TENS SBT 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 21 532 20 0 4 4 32 943 39 5 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 24 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 4905.000000 3913.000000 0.500000 Tape File Depth Unit~ = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5956 datums Tape Subfile: 2 115 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY MPU TOOL CODE START DEPTH STOP DEPTH GRCH 6915.0 8176.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS MPU CURVE CODE GRCH PASS NUMBER: 2 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 2 (LOWER MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERNCE. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPJ- 12 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH SBT 68 1 GAPI 2 TENS SBT 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 21 532 20 0 4 4 32 943 39 5 * DATA RECORD (TYPE# 0) Total Data Records: 32 1014 BYTES * Tape File Start Depth = 8223.000000 Tape File End Depth = 6903.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7924 datums Tape Subfile: 3 64 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes : S~AInD E VHSV%~ : ~dO%S HA~ON : ANIO~ ~N%I~ : E1 - £~ : (~XSVq~) NOIA~f~OqdX~ dS : Ano': HD~L~4g ~. / N~OD N~ NM ND 'HD%tD H,I, IM GI,T,.~IHS S~fM '(SS~a mv,~a,~) C SSVa : SH%I%IN~H ~ '0918 0 '0918 0'~£I8 §'££18 0'6II8 0'6II8 ~'~018 ~'~018 0'E608 0'E608 §'££08 §'L£08 §'E908 5'E908 §'I~08 0'1§08 0'Ig08 0'Ig08 §'6008 0'6008 0'§66£ 0'§66£ 0'£86£ 0'L86£ 5'896£ §'896£ HDHD Ht~Q ~NI%~S~S E :H~8N/1N SS~d HDHD ~QOD ~AH~D SA~IHS HO~ ~AH~D ~NI%~S~8 0'9£I8 0'§96L HD~D X~4~IS ~I~ 0005' :~N~N~HDNI ~ :~N/1N SS~ · s~Iy~ s$~dss uy ss~d qo~ ao~ SsA~nD p~ddyID pu~ p~$~!qs SIT :odX% sT ~ oIT~qns od~L Name Tool Code Samples Units 1 GRCH SBT 68 1 GAPI 2 TENS SBT 68 1 LB * DATA RECORD (TYPE# Total Data Records: ~og Crv Crv Size Length Typ Typ Cls Mod 4 4 85 180 13 1 4 4 85 180 13 1 0) 1014 BYTES * Tape File Start Depth = 8223.000000 Tape File End Depth = 7951.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7592 datums Tape Subfile: 4 53 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3927.5 $ LOG HEADER DATA STOP DEPTH 4866.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACC SBT VDL CENT $ CASING COLLAR LOC. GAF[MA RAY ACOUSTIC COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 14-OCT-94 FSYS REV. J001 VER. 1.1 2213 14-OCT-94 8213.0 8213.0 3950.0 8206.0 1500.0 YES TOOL NUMBER 2330XA 1309XA 1633EA 1424XA 1424PA .000 8299.0 .0 BRINE .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 s~n~ep 6gLI£ 89 :apoo de~ :X~mmns 6u~pooap apoo uo~$uasaadai SI7 ~aa~ = s~TuQ gsdaG aTT~ ad~A 0000§E'0 = 6uTo~ds I~A~ ~IT~ ~d~i 000000'~I6[ = q~daq pu~ ~ITt ~d~A 000000'S06P = qsd~G $~$S ~IT~ ~d~A §6 :spaoosE w~G I~$ol 0E 89 609 ££ ~ 6g £0~ £9 P 6g £~6 g£ ~ 65 £~6 gC ~ 0E g£§ Ig ~ ~ I 89 ~S ~OO P NN/~ I 89 ~S G~S ~ ~ I 89 ~S N~ P ~ I 89 ~S N~ ~ I~O I 89 ~S ~D I A~D A~D ssTuQ seIdmws ~poo IOOA e~wN :SeA-nD § ~ :GI q~dep edwA · WXSW~V : ~dO~S HAHON : ANIO~ ~X~IX : EI - £dX : (~Q{SW~V) NOIAh%IO~dX~ d~ : NQOD N~ NM ND · : (NI) .~.~OGN%f,T,S : (~) MOGXIM ONIZI~4~ON : (i~) MOGNIM ONIZI~-~ON ~0~ Maximum record length: ~014 bytes 000 ' 00' . 000' 000' 000' O' 0 O' O' 00' MNIM~ O. 0'66E8 000' VX60£I ~Z~Wi1N ~OOA SlX 0'00§I 0'90E8 0'0§6£ 0'£IE8 0 ' £IE8 ~6-~DO-~I IOIg I'I 'H~A I00£ 'AMH ~6-~DO-~I :(NI) NOI~DMHHOD M~OH :X~ISN~ XIHAtflJ :XIMitfI4 :(~tfI4~H~ ~0 ~tffC~HAI~) ~X~ ~OOA ~OOA NO~AQ~N :(NI)MZIS AI~ M~OH NMdO ~A~G DNIS~D GN~ ~OH~HO~ ~iGA OOtf qlOO ~dXA ~00~ ~GO3 ~00~ ~OGN~A (NOAAO~ OA ~0~) 9NI~AS qOOl §'~818 :(~H4~) G~dS DNIDDO~ :(~) ~A~ZANI 90~ ~0~0~ : (~) %~A~NI DO% ~0~ :(ma) ~sso~ mm : (ga) ~m~x~m mm :~OIAO~ NO HIDDO% ~IA :NOIS~A ~H~M$gOS ~AVG H~G~IH DO% § ' ~I69 ~D # '~I!~ ~s~I u! ss~d punoaB~o~q ~a !saII~ a~das uT ss~d qo~a ~o~ ~$~p ~ep~aq BoI pu~ SaA~nO S~A~R3 MIr~ :~PiQN ~I~ H~G~H ~I~ SI% :adK$ sT 9 eIT~qns ed~A BLUELINE COUNT RATE ~ORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (LOWER MAIN PASS) . $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPJ - 12 : MILNE POINT : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 2 TTEN SBT 68 3 TEN SBT 68 4 SPD SBT 68 5 CCL SBT 68 1 GAPI 4 1 LB 4 1 LB 4 1 F/MN 4 1 4 4 21 532 20 0 4 32 943 39 5 4 32 943 39 5 4 67 407 39 5 4 77 609 68 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 126 Tape File Start Depth = 8223.000000 Tape File End Depth = 6903.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 39279 datums Tape Subfile: 6 202 records... Minimum record length: 62 bytes Maximum record length: zO14 bytes 000 ' 00' Oe 000' 000' 000 ' O' 0 O' O' 00' MMIM~ Oe 0'66~8 000' ~X60£I ~X0££E 0'00§I 0'90E8 0'0S6£ 0'£IE8 0'gig8 ~6-~OO-~I I'I 'MMA I00£ 'A~M ~6-~OO-~I :(~) HL6ZG ONIS~D :(NI)ZZIS LIS Z~OH ~G DMIS~D GN~f ~qOHZHO~ ~flS qGA qO0,1, GNO~ GZLNHI4OZS NOI4~OO 0 I,l, SOOO%f · OO~1%t~fTIOO DNIS~fD qGA DOff qOO ZdAL qOOL ZGOD qOOL HOGMZA (~OLLOS OL 60L) ONIH~S ~OOL §'9818 HAd~G dOIS : (L~) ~A~Z~MI DOq :NOIS~A ~E~MIIOS :Q~DDOq ~L~G ~G~ZH DOq 0'G96£ 00GE' :ANIHIHONI C :H~8PlQN SS~d 'aI~ SsPI u~ ssPd punoaBMo~q ~a !SaITg a~aedas uT ssed qo~a aog ~%~p aapeaq BoI pue SaAanO SZA~QO 9 :~flN Z~I~ H~G~ZH SI% :adA% sT £ eITgqns BLUELINE COUNT RATE ~'ORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 3 (REPEAT PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPJ - 12 : MILNE POINT : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TaPe depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 2 TTEN SBT 68 3 TEN SBT 68 4 SPD SBT 68 5 CCL SBT 68 1 GAPI 4 1 LB 4 1 LB 4 1 F/MN 4 1 4 4 21 532 20 0 4 32 943 39 5 4 32 943 39 5 4 67 407 39 5 4 77 609 68 6 20 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 26 Tape File Start Depth = 8223.000000 Tape File End Depth = 7951.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 38274 datums Tape Subfile: 7 102 records... Minimum record length: 62 bytes Maximum record length: xO14 bytes Tape Subfile 8 is type: LIS 94/10/19 01 **** REEL TRAILER **** 94/10/20 01 Tape Subfile: 8 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 20 OCT 94 8:14a Elapsed execution time = 7.30 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 6 is type: LIS 94/10/21 01 **** REEL TRAILER **** 94/10/24 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 24 OCT 94 8:13a Elapsed execution time = 4.51 seconds. SYSTEM RETURN CODE = 0 RECEIVED NOV 1 5 1994, ~aska 011 & Gas Cons. ~chorag. e [$ ~aoe Veri'[lcat:ion r~lstiD,q ;hlumberqer ./{!aska Coa~putinn Center tl-NOV-!994 10:51 MPJ-12 500292~50600 BP EXPLORATInN SCHLI!aBERGER ~ELL SERVICES BI'~ RI)~ i ~IT PUN ? BIT RUN 3 iiImmimmI ImIImmIII ImmmImmII 94328 q432~ ~iTCO~S ~ICOLS I0£ 237z~ 64.65 35.00 OPE'"; :quL~ CAS!hC DPILLERS ~TT STZE (,[,N) SIZE (i~!) DEPTH PAGE: :bl, U~berger ~%].asKa Computinc Center i0:51 :-" '":: .......... ~" "~ ~IT ~t~ T~O ~$ CDR ~ND CDN, S LIS F~AT b~TA LIS Ff~R~AT DATA SERVICE : mLTC MaX R~C SIZE FIhE TYPE EDIWEO ~E~(;~D Pe~th shifted a~ clipped curves; ~11 bit runs meroed. D~PTH iNCPE'~E!~T: 0.5000 .......... F~I!IVALE~-,1T UN6HIFTED DFPTH .......... ~97o~ 0 8142,5 8!42.5 795~.5 "/~50.~ 7~2~,n 7~29.0 7733.g 7733.5 769~.5 769~.5 7~6~.0 7661.0 7~20.0 '7620.n 750°.~ 750g.5 7370.5 7379.5 777~.~ 7~7P,5 79~0.a 7760.0 7!04.5 7~04.5 IS Tane v'eri~!~ca..tion Listinn .~hl~.~ber~ger ~%].asKa Coca, ut. in~, Center i ~ -~,~(3V-I994 10:51 6~40, r~ 0r.;~4:7.0 6q47,0 4933,5 4a4'~. 5 .1~40.5 470~n.~ 4707.0 ~707,0 4605.g 4612,5 4612.5 452~,5 4529,5 4529'5 .445~. 5 4464,0 4464.0 ~432,5 ~43q,0 4439,0 ~417.5 44~.~. 0 4423,0 4337.5 4346,0 %346,0 4313.0 4323,5 4323,5 428&.C~ 4294,0 .4~94.0 4!40,n 4!~45.5 4145,5 4~ 22,5 4!27,5 4!.27.5 404;~,0 ~047.5 4047,5 4019.o 4025,0 ~025,0 3q8~,5 3994,0 3994,0 git PU{I t'~O. ~ERGE TOP ~ERGE BASE ~ 4826.0 8274.0 1 2552.0 4~93.0 CASEL~ };to.b~ GR i. ISEU ~S B.AS~ SHIF? CURVE. CAGED NOI,,E I~!TE~VAL ~l~O-6q!O A!~)D 4867-3925. THE SHIFTED CURV~ wAS I';~E ?;!~D G~, Abed T~E CD~ AND CDN W~RE CARRIED. jLOCK S~iFT t3F +7.0 FT wAS APPLIED WRO~ 6910-4867, AND A uL,~,, 8glr'r o? 5.5 f'T ~AS ,APPLIED PROa 3925-2552. O!~,~LY T~-~ ~.,~ CR ~A$ ~!~ O~ BIT RU~,I ONE. BIT RUN TWO CO~.,glS? UF CD~ ~i~D $ ! 65 0 3 73 60 5 66 IS ~ave veriflcati,,o~ r,istf.~ -hlUm+~e~c, er AlasKa ~'oa]D'~Jt.i['t,,'l center 11-~,~CtV-19q4 10:51, 8 68 0,5 17 68 i'~ 66 0 66 0 ..... I ........ I ...... ~ILE ~0 REP P~OC~S$ ,~ P I ~ P I :,~ ........ p i ~ P I ~ [] ~ B ~ B S I Z E R LOG ~YP .... CLASS ~OD ~3U~B SA~P E~E~ CODE (HEX) ~"T 0 OOn O0 0 I !. 4 0000000 G~P? O0 o00 O0 0 1 1 1 4 68 0000000000 Fpar~ O0 OOO O0 O I l, I 4 68 0000000000 i'{~ O0 000 O0 0 I 1 1 4 68 0000000000 OH~:~ 00 000 O0 0 1 1 J. 4 68 0000000000 OH~ O0 000 O0 0 1 ! i: 4 68 0000000000 o~:: on ooo oo o 1 1 1 4 68 o0ooo0oooo GH~u O0 OOO O0 0 i 1 I 4 68 0000000000 O.~!~ On 000 O0 0 I 1, 1 4 68 0000000000 G/CS On O0n O0 0 I 1 1 4 68 0000000000 G/C3 O0 000 O0 0 1 1 1. 4 68 0000000000 a~l~ O~ 00o O0 0 1 I 1 4 68 0000000000 !~ On OOO oO 0 1 1 1 4 68 00o0000000 PU-$ On OOO O0 0 1 1 1 4 68 0000000000 GnPI on ~OO OO 0 1 1 1 4 68 0000000000 * * E) h T ,~ * * OEPT. ~5~2.uc,9 Ga.t~iWD 32.300 ROP.~WO -999.250 R~.~:.~r: -9o9.2~:.: ~P.~WD -q99.25~ IPER,~WD -999.250 VRA.~D IlRD.~ -gqg.2qt~ ~-!O~.>i~"b -99q.250 DRgO.~WD -999.250 PEF.~D -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 [$ Tane Vert. ftcat.l, on '!,istJ. ng .~blumber~r Alaska Co~put!r~.~ Center 8ERVIC~ LAST FILE. SW,'v · : baTM : 9~/1!/.1.1 MAX R~TC $IZ~ : 19~4 FIL~ T~Pg ~ E D I · E ~ ~ F P G ~7 D ~,~ a D Depth s~lfte~ arid cliP?ed curves~ DFP~H I~;C~E~E~T: 0.5000 F~LF S U ~ ~,i 5. RY I. DWG TOO[., C('J~5 STAR~ DE~'!'H r~ A s ~,f f._, I ~ g DEPTd 8!3~.5 7951 .~ 7r421.0 77~5.R 76~1.~ 7651,0 76 1 o. ~ 7~7! .n 777~,~ 7n97.~ 6940, C all bit runs merged. STnP DEPT~{ · 7 7 7 7 7 7 7379.5 727~.5 7~6~).0 7104.5 ........ FOIIIVALE~T UNSMIFTMD . .0 ~8897 0 ~59.~ 7~5~.5 829.0 782~.0 V3~.5 7733.5 59~.5 799~,.5 6b!,n 7601.0 6~f'~oO 7620.0 50q.5 750q.5 717a.5 777~.5 7104.5 494n,5 DEPTH- ......... IS Tace '¥er~.f~cat!on List~n~ .-blUmber~.~er Alaska Co~utin~ Center i ~ -NUV-,~1904 !0:51 4700°5 g707,0 4.707,0 4522,5 452~,5 .~529,5 4~5g,5 4464,0 4454,0 4432,5 443q,0 443g,0 44.1 ~, ~{ 4423,0 4423.0 4337,5 4346,0 4346,0 4313,~ ~23,5 4286.0 4~94,0 4~94,0 ~!~2,0 4186.0 4166,0 4~22,5 ~ 27,5 4127,5 4043,0 4047,5 4047,5 401q,O ~025,0 4025,0 3~8~, 5 3~94,0 3994,0 10~.0 105~5 105.5 ~'O'~G 'i~O0~, CODE ~IT RU~,~ NO, ~ERGE TOP MERGE SASE ~180-bqlO {~D 4867-3925, T~E SHIFTED CURVE AND TNE CDR AND CPM WERE CARRIED, bT$ FrlP.~'~AT DATA ** nATA b'~'~:'~A"' MP~CT?'!C~TIt. IN PECORD ** TYPE RrP~ CODE VALUE lI-MOV-1994 10151 ~D ORD~ # bOG TYPE CLASS ~09 ~U~B. SA~P EbE~ CODE (HEX) '"""'"D~,~ ...... ~'~ ' ............ o0""~"o .... O0"'"''"'"'"''""''"'"'"'''''''''''"'"0 ~. ~ ~ 6~ 000 00000 G~ ~An G~PI O0 000 O0 0 2 1 ~ 4 68 0000000000 ROP ~AD FPHR O0 000 O0 0 2 1 I 4 68 0000000000 Ra ~A~ O[,!~ O0 000 O0 0 2 1 1 4 68 0000000000 R~ ~&a ©H~ O0 000 O0 0 2 1 I 4 68 0000000000 DER ~:~A~ Oai~~ O0 000 O0 0 2 ! 1 4 68 0000000000 V~A ~ OHa~ O0 000 O0 0 2 1 1 4 68 0000000000 VWP ~A9 0~" O0 OOO O0 0 2 1 1 4 68 0000000000 DFPW 4884 t~O~'~ GR..¢~D -990 250 ROP.,'.qAD 72~. 855 RA MAD D~PT 4202.009 OR ~qAt3 71.!97 ROP.MAO -999.250 RA.~AD RP:~A9 6.637 L)ER:?~AO 6.790 VRA.~4AD -999.250 VRP.~AD **** FT[,~ T~,~ ILE FIL, F ;,~ A" E SFRV lcd: : FblC VFRSIO,~ D~T~ : Oil 1 ~X ~FC SIZW F!b~ TY~E : L~.S~ VILE :.9999 250 . 6. 677 999.250 [~ ~aPe Ver~icat:io~ ~isti.~ :~lUm~e~c~.r i~s~a ~omputln~ , ...... nter ii-NOV-1994 10151 ~ent~ sn~fte~ ~nd cli~ed curves~ .... :la ....... 8133.~ 7~51,~ 7921,0 7795.5 76~1 .S 7~7!. ,0 7~7~.5 795~,S 7~97,5 4700,5 4529,5 4458.5 4a17,5 .... · 4"/2 CDN 814~.5 8142.5 7~5q.5 7959.5 7829,0 782g,0 7733,5 7~33.5 769~.5 769~.5 766!.0 7661.0 7620.~ 7620 0 7509.5 7509:5 7379.5 7379.5 777P.5 7278.5 7260.0 7~60.0 71.0a.5 7~0~.5 6947°9 ~947,0 494n. K 4840,5 4707.0 461~.5 4612,5 -,~529,5 452g,g ~4~.0 4464.0 44~9.n 443~.0 g423.0 4423.0 ~346.0 ~346.0 4323.5 432~.5 4~9~.~ 41~6o0 ali.. bit runs merged. STOP DEPTt,{ DEPTH--=------- IS ~ape ~r~fic~ti:on .hltr~her~er /~!asKa Co~]t~.n.~ Center 4~45.5 4!45.5 ~t27.5 4~27'5 40'47.5 4047.5 4~025.0 4()25.0 3994.0 3994.0 3~5~.5 3~53.5 3~37.0 3937.0 ~ 0:5.5 ~,05.5 8I. aO-6qlO at~D a867-3925. THE SHIFTED CU~¥E ?iWD GR, AN'D THE CDR AN~ CD~ WERE CARRIED. PASS ~!S ONLY THE CDN ~ND WAS ~ADE ON A 1 66 o 2 66 0 5 60 (~ 73 7 65 6 68 0,5 1! 66 36 13 60 n 6 66 1. :hlU~er,~er A,las~a Co~'~:~ut, in~ Center PAGg: ~ S'~Pv i $~j~'[C? A bP! hPI ~P'r FILE NLi~B N NB SIZE RE ............... .,.i .... NUmB SA~4P gEES CODE (HEX) .... ..... . .................. : ........... .... D~PT FT 0 000 O0 0 3 1 4 68 000000000 ROP '~Ar~ FP~ 00 000 00 0 3 1, ~ 4 68 0000000000 RROD ~AD G/C3 O0 0uO 00 0 3 1 1 4 68 0000000000 D~Ho ~A9 G/C3 O0 000 O0 0 3 1 ! 4 68 0000000000 P~F ~AP ~tE O0 000 O0 0 3 1 1 4 68 0000000000 CASN ~AD I~,~ O0 O00 O0 0 3 1 1 4 68 0000000000 NPMI ~AD PI,!-S O0 000 O0 O 3 !. I 4 68 0000000000 10 D~p~. ~720.000 ROP.i~AD -999.~50 PE~.~A,D -999.250 CA[,N.MAD '999.250 NPHI',~AD DEPT 44a~,uO0 ROP.MAO -999,~50 ~HOB,~AD PEF:~AO -999.250 CAL~J.MAD -999.~50 NPHI,MAD -999.~50 O~HO,~AD -999..250 -.999.250 D~HO.~AD 999.~50 '-999.250 -999:.250 **** FT[,? TRait,ER **** FIL~ ~:iA~E : EDIT .0o3 $~RVICE : VE~$IO:.~ ~ n0!C~i DATF : ~4!11/11 FTLF TYPE : bO FTb~ uAuZ : MOIl 8~RVlCE : V~RSI~< : nOt. CO1 D~T~ : 94/1~/11 ~X R~C SlZ~ : FTL~ wypE : Lo Curves and lou h~ader data for eacn blt run in separate BIT R":;,,~,""~,~AifjP: ' files. :hlumberaer AlasKa Computinm Center 11.-~0V-!994 i0:51 .il START PATA TYPE (ME~qORY or REAL-TIME): TOP LOG TNTERVAS DOTTO~q LnG ~NT~CRVAT,~ (FT): HOLi~; I~C[,I~:ATIO~,~ (DE'C) ;:4 ~ X ~ M T:i M A'N (,; L E ~ TOOL STRI~.]G (TOP TO 'VE?,}ngR 'rOOb CO0~ 'i'OOL ~YDE :q;,,D-G S WHILE ORIbLING GR OPEU HO[~E bJ!T SIZE DRTbLERS CAST~,;C DE~TH (FI): Fg~UIO bOS~ (C3): [.,in, Xl;~!~,,~ RFC~R~EO TE~!PERATi!R~ (0EGF) RFS!STIWlTY (nH~a) ~:r f~I,IPERAT'URE (DEar'): ~-'{jP AT ;',%~ASU~ED :~;jn l'.i' :-~tX CTRCLIT, ATI~,~G T~MPERATURE : U{jD F!biPAT~. AT (r4T) 24-$EP-94 LOGOS 20,4 FAS'r 2,5 ~E~ORY 8320,0 2530,~ 8~74, 29.3 31,8 TOOb NUMBER NG$OOV 8.500 2565.0 140.0 2.300 2.080 O.UO0 SANDSTONE 2.65 8.5o0 1.OOO 74.0 74.0 0,0 :blu[~'~herc~er A!.aSKo Co~putJ. n~] Center i ~-~[)v-1994 10:5.1 CDR RFAF~Ui'~T PON· TO BIT:61,~,6 FT TO BIT:!.20.87 FT ~EUT lO BiT:127.85 FT CDR ~na~aOOW~ P~Oa 4~00 FT fO 4700 FT CD,'~ ~,~S~,lbP ~R~?~ 4580 FT TO 4~00 FT PAGE: TYP~ ~P.R CODE V~LI.,iE ! 66 0 2 66 o 5 66 7 65 I~ 66 t. 28 19 6~ %~ 66 o 14 65 FT 1~ 66 68 0 66 1 ~, tl'.'I~'.. , SE~vF~ Ami ~P I bPI ~It, ~O~O u SIZE R PROCES T~~ q"DEP~ ......... ~ bt)G TYP~ CLASS ~[;D ~UU8 SA"P gbE~ CODE (HEX) D~(:>~ F? O0 O0 . 0 4 1 ! 4 . 000000 GR I.~,! (;afl O0 Oon O0 0 4 ! 1 4 68 nO00000000 10:51 DEPT. 4ta~,(,i~o GR,Lwi 35.~u0 D~PT. ~530.<>O0 GR,Lw1 -999,250 S~RvIC~ : FIL~ TY~E : LO FiLE ~A~E S~RVIC~: : ~LIC VER~I©~':,i : 0~)lC01 D~T~ : q4/1!t!,1 ~aX ~C ,S~Zm : !o74 FILF TYPE : F!L~ HE~DF~ Curves a~d loq hea~er data ~or each bit run In separate D~PTM f ~CP E'-,E~i': 0.SOn0 LDWG !!'nOt, CODE STAk7 CD~ 4. .. bOG Hw:%r~ ~A~A SIOP DEPTH 8322.0 24-5EP-94 LOOPS 20,4 FAST 2.5 MEMORY 8~20.0 2530.n 8274,0 files. L$ ~.ame Veri, f~catJ~on ;hlumber..4er A!as~a Co~p:,,~tJ.n~ ~e~ter 994 10: ~ 1 PAGE: I¸4 ~4UL) CHibOR~DF8 (PP~,~): ~,~,~XI/4U;,:i I~FCORDED tE~PER~T~RE (DMGF): RESISTivITY (.O',.{~ih) AT TE~,~iPE~ATURE (DECF); '~UQ ~?f fv~EASiJRED TE~'pERATI.IRE '~tjr'~ AT r,-,!~X CI~CUI,~ATI~G TE~qPERATURE : hnhw CO~RECmlO~ CTI'~l: Toni, STAtqDOF~ CI~,~) ~ 2 ~ 0 ~0,60 !40.0 2,300 2.080 0,000 SANDSTON~ 2.65 8,500 1,000 ************ PUb! 1 ************* CD~ RFADLJlYT PORT TO B~T:61,16 FT RF6 TO ~Im;57,90 FT GP TO BIT:6S.41 O=~! RFADOUT PORT TO BIT:IXg,56 PT [)~ TO ~lTI120.g7 FT ~EtJT TO RIT:127.~5 FT Do1T,bFD I~'TFRVAL 4875 FT mO 8320 VT CnR :..~$Hi)D;.:!,: FRO~: ~200 FT 10 4700 FT C~a xAS!~iiP FRU;4 45b0 wi' T~ 4400 FT 74.0 74,0 0o0 [$ ~ar, e verification List,ina ;hlUn'~bero~r alasKo Comput!~%~ Center P~E~ 2 6 5 6 6 7 7 6 6 0 6 6 5 65 66 21 66 0 6,5 FT 66 68 66 1 ** SE* TYPE - CffAN N~M~ SMRV UN1T SMRVIC~ AP ID ORDCP # bO GP L~? G~PI O0 ROPF L~ F/MC 00 TaB 1,~? m~ O0 DPH~ L~? G/CB 00 P~F Lw? B~/~ OO TNPI~ [,~2 pU ** mmmmmmmmmmmmmmmmmmmmm~immm~mm~mm~mmmlm'mm~~m~m~mmmmm I AP1 APl AP1 FiLE NUMB NUmB 8IZ~ REPR PROCE$~ G TYPE CL.aSS ~OD NUmB SA~P. EbMM CODE (HEX) DOD O0 O 5 1 ! 4 68 0000000000 OOO O0 0 5 l 1 4 68 0000000000 00o O0 0 5 1 1 4 68 0000000000 000 O0 0 5 ! 1. 4 68 0000000000 OOO O0 0 5 !. 1. 4 68 0000000000 000 OD 0 5 I 1 4 68 0000000000 OOO O0 0 5 1 1 4 68 0000000000 0()0 O0 0 5 1 I 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 I 1 4 68 0000000000 000 O0 0 5 1 1 4 68 00o0000000 00o O0 0 5 ! 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm 15 D~p?. ;~ 3:22. OOu GR. ~TP. b,.';'? -999.2~:: PSR. bW2 D~ i-l~. L ,4 P ','9 q 9. 259 P w i,". bt, i2 DEPT. d7~4.L;O0 CR.bt,~2 DRHO.L~2 -~99.ZSu P~F.L~2 -99q.250 ROPE.hW2 43.063 -999.25a DER.aW2 -999.250 -O90.~bO DCAL.LW2 -99g.250 TNPH.LW2 -999.25n eOPE.bW2 -999.250 ?IR.LW2 -qgo.?50 DER.LW2 -999.250 DEP.L~2 -999.~50 DCAL.~w2 -q99.250 T~PN.LW~ -999.250 -999.250 -999.250 -999.250 -999.250 40.600 :blU~.nberGer AlasK~ Co~,~::utinO center t6 FILE NA~g : EDI% ,006 $~RVICE : VERSI~:~ : OO~C~X D~TF : 9~ti,!,!1! ~X RFC SiZE : F?L~ TyDE Curves c~nd l.-q nearer data for each bit. rum Xn seoarate STOP DEPTH 48 5 0 74-$~-P-94 DOGOS 20,4 FAST 2,5 ~EmORY 8320.0 2530.0 8274.0 18.? 32.1 Tare Ver.i~Icat~on t.isting l~-NOV-1994 10:51 17 P~? SEA,, ,g, A?,IP,, REc'TSTIVITYo . f~FiI!,~LE~$ C~6~i~C; 9EPTH ~ST~IX ~E~SITY: 8.500 2565.0 10,60 140.0 2.300 2,080 0.000 SANDSTONE ~.65 8,500 1.000 ************ P~ 1 ************ PU~? 2 CDR R~Ar~O~!T PORT TO BIT:61,16 FT R~$ TO ~Ir157,w9 FT GR TO BII:O~.41 F? ~'~ RFADOI{T PORT TO BIT:II9.56 FT DEi~ T[~ alT:~20.87 F? gE~T TO ~IT:~27.85 FT D?I~LEO I~TERV~L 4875 FT TO 8]20 FT CO~ ,~5~!~)o9~ VRO^~ 4200 FT TO 4700 VT $ 74.0 74 0 o.'o IS Ta~e "v'erificat, iom ;~istJ.,n~ rhlum~er~er A!as.<.a Com~t~t~,nq Center PAGE~ 2 66 0 3 73 24 5 66 7 65 9 65 FT 1~ 66 42 13 66 o 14 65 ~T 15 66 68 },6 66 1 O 66 ~. ,~ SEw ~YmE - CgA~; ** DEPT FT O0 000 O0 0 6 1 I 4 68 0000000000 G~ ~1)2 Ga. PT O0 000 O0 O 6 I l 4 68 0000000000 ROP~ uO~ F/?~ OO 000 O0 0 6 1 i 4 68 0000000000 A~R ?D? [)~;';~ O0 000 O0 0 6 1 1 4 68 OOO0000000 PSR ~'~ ~ 2 uF~ r,~ ~.~ O0 000 O0 0 6 1 1, 4 68 0000000000 DFR ~b2. OH~,~ O0 000 O0 0 6 1 1 4 68 0000000000 IiII~iillIi~ i~It~ ~II~i~Ii~I~I~iiiiiII~I IIIIlIIIIIIIIIIIIIIiIIII~IIII~IIIIII~IIIIII DEpW. 4675.0aC, GR. Y~D2 -999.250 ROPE.~qD2 ~!98.119 ATR.~D2 PS~. . ~,'.02 -qog. 25~) 0tR. ~v~D2. -999. 250 -999.250 -999.250 ,;hlumbe~ger ',~!as~a Co~"~,uti. r~o ~enter t 1. ,,-~,~!Ov-1994 ! 0; 5 t PAng: 19 Curves and 1. o<~ ~ea~er data for each bit run in separate DEPTH I~.!CPE.',.~E~:T: O. 5000 . POT.~a;',~ bag l~'i:~/Rva[ (FT) STOP OgPTH 43~o 24-$~P'94 LOGOS 20.4 FAST 2,5 MEMORY 8320.0 8274.0 1~.2 ND$O~2 files. .hl~mberGer ~.~]as~:a Cor,~)t~tinq Center RFb~RKS: 8.50 0 25 6:5.0 2,0,60 140.o 2.300 2,080 0,000 SANDSTONE 2.65 8,500 1.0o0 CDR N~i~nO~T PORT ~O B!T:61.16 FT gE6 To 4I~:57.g9 FT GR TO BI~::68.41 FT DE;:,; ~F&F~Oi~T PORT TO B!T:ll9 56 ~T OE:,,; Tr"~ RIT:~'~0.87 FT NEUT T~ BIT:127.85 FT DRI~,L~7~ iI'.~TERVAL 4875 FT TO 8~20 FT Cf:R ~;~.a,SHDr]~,~r{~ .rROr.~ G200 FT TO 4700 FT bT6 F'n R,~,~ A 1'' 74°0 74 0 0[ 0 20 P~GE~ ~ 6~ 0.5 9 65 i~ 6~) 36 1~ 66 0 !a ¢5 FT i5 66 6~ 16 ~5 DEPT PFF DCA! ID ORgEJ~:~ # LOG TYPE CLASS ~()D NUmB SA~P ELEM CODE (HEX) FT O0 000 O0 0 7 I 160004 8 000 0000 ~0) F/H~ O0 000 O0 0 7 ~ 1 4 68 0000000000 ~[)P G/C3 oo 000 On 0 7 1 ~ 4 68 0000000000 ~i>? G/C3 O0 000 O0 0 7 I I 4 68 0000000000 ~D2 Br:~/E OO OOO O0 0 7 I I 4 68 0000000000 ~2 I~ O0 000 O0 0 7 1 I 4 68 0000000000 DFPm. DF, PT 47!4 00~ mOPE.6iD2 78.946 RHOB ,n . · MD2 .... ~, 2 999 250 DRHO. -909.2~c: DC~L.~P2 -099.~50 TNPH.MD2 -g99.~50 250 RHOa. MD2 -999.~50 D~HO.~.D~ -99~.250 TNPH.MD2 29.700 -999.250 -999,250 FTL~ ~)A~:E : ~i.>TT .On7 SF~vIC~ : ~LIC D~Tr : q4/l!/1, l M~X NYC SIZe: : 192.i FTL? TY~C : L~5~ FiL~ IS T~oe verificst,ton Listt~,a :hlumber~,!er ~!.as~ Co~:~':~'ott.[~a Center 10:5'1 PAGE: ¸2 2 )
