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Home My WebLink About174-009P L UGG State cf Alaska LOC3.TION Cr_,EA~~CF R~,PORT ALASKA 0IL ~ GAS CONSERVATION COMMISSION Lease r_oS'O" ,_ca: Review the well file, and-ccmmen= on pluq~i~q, well head Signed Production TBU well D-26rd ~., Subject: Production TBU well D-26rd Date: Thu, 03 Jun 1999 09:13:09 -0800 From: Blair Wondzell <Blair_Wondzell~admin.state.ak.us> Organization: SOA-AOGCC To: Larry Greenstein <greensteinlp~unocal.com>, Stephen E Mcmains <steve_mcmains~admin.state.ak.us> Larry, As we discussed, All of the production from TBU well D-26RD since the redrill in August 1998 should be charged to the new well, API 50-733-20260-01, PTD 98-129. Steve advises that revised production sheet showing this change from August 1998 are not necessary; he will change our records to show the procudtion to the RD API "01" number, please change yours. Please continue showing all production from this well to D-26RD. We'll use this E-mail to reclassify the original well, D-26 as Abandoned. Thanks, Blair 1 of 1 6/3/99 9:14 AM ~...,, STATE OF ALASKA ~ ALASKA Oi-,-,-AND GAS CONSERVATION C,,.,,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Name of Operator 7. Permit Number UNOCAL 74-0009-0 3. Address 8. APl Number P.O. Box 196247 Anchorage, AK 99519 50- 733-20260-00 4. Location of well at surface 751' FSL, 1215' FWL, Sec. 6, T8N, R13W, SM At Top Producing Interval 753' FNL, 64' FWL, SEC 5, 8N 13W, SM At Total Depth 499' FNL, 730' FWL, SEC 5, 8N 13W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB above MSL I ADL 18729/17594 12. Date Spudded I 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 3/12/74 i 5/20/74 ~ 7/24/98 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 11,969' / 9,885' 11,048' / 9,148' 22. Type Electric or Other Logs Run No logs were run 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-26 11. Field and Pool McArthur River Field Middle Kenai "G" 15. Water Depth, if offshore I 16. No. of Completions 65 feet MSLI 1 i 19' Directi°nal SurveY I20' Depth where SSSV setYes: No: 302 feet MD I21' Thickness °, Permafr°stN/A 23. CASING SIZE WT. PER FT. GRADE 13-3/8" 61 # K-55 9-5/8" 47, 43.5, 40# N-80 & P-110 7" Liner 29# N-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD -, TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Surf. 3,306' 17-1/2" 3000 sacks N/A Surf. 10,239' 12-1/4" 4500 sacks N/A 10,082' 11,969' 8-1/2" 650 sacks N/A 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 10,668'-10,688'; 10,692'-10,709'; 10,735'-10,765'; 10,776-10,860' MD 8,843'-8,859'; 8,862'-8,876'; 8,896'-8,921'; 8,929'-8,997' TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) N/A ]26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27., PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR TEST PERIOD => OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 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 MAY 27 1999 Naska 0ii & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. " '~ 30. · " GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. '~-1 Top 10,611 -8,702' SS/8,808' TVD G-2 Top 10,665 -8,745' SS/8,851' TVD G-3 Top 10,731 -8,796' SS/8,902' TVD G-4 Top ~l 0,792 -8,846' SS/8,952' TVD "31. LIST OF A'Yi'ACHMENTS Weilbore diagram, daily operations summary, survey ~'2. I hereby certify that the foregoing is true and correct to the best of my knowledge Ddlling Manager May 26, 1999 Signed Title Date Dan Williamson 'Form 10407 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 space 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 productin 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 inter~al. 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". Trading Bay Unit Well 4/D-26 P & A Workover RKB to TBG Head = 41' Tree connection: 4~1/6" SIZECASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. -5/8" 47 P 110 8rd LT&C 8.681 Surf I0,239' (1'--le 29 N80 8rd [.T&C 6.184 10~082 11.969' N JEWELRY DETAIL NO. Dej~th ~ID Item I I 1,383~ 5.08 60' Casing Patch 2 1 L,780' 4.00 Brown 2B Pkr. w/millout ext, 3 11,796' 3.725 Otis "XN" Nipple, SiTx~ 3.813 4 11.807' Wireline Re-entry Guide G-2 G-3 G-4 10,941' 11,033' PBw/CT on 4/27~4 B-I B-2 B-3 1 WIREL1NE Worked a 3.0" GR to I0,155' on 1/14/97 Fill 'Fagged w/a 2.28" GR on6/12/96 FISH: ()tis Tbg, nipple plug, 12/2/92 (¢ 11,796' W!.M Coil Tubing 2.7" bit & motor assy. 4/22/94 £~ i t,642' CTM (6) Cotlet fingers ff CT Hyd. Discmmect (¢'I 1,004' CTM PERFORATION DATA ZONE TOP BTM AMT SPF DATE G-2 10,668' 10,688' 20' 6 6/18A14 G-3 10.693 10,709 16' 6 6/19/94 10~740 10,765 25' 6 6/t8/94 G~, t0,786 10,800 14' 6 6/1/94 10.800 10,860 60' 6 5/31/94 B-I ll,210' 11.243' 33' 6 Abandomxl B-2 11.273' 11,306' 33' 4 Abandoned B-3 11309' 11,435' 126 4 AbandoIled B-5 11.642' 11,750' 108' 6 Abandoned B-6 l 1,826'1 t,858' 32' 4 Abandoned STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION wELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: GAS: SUSPENDED: ABANDONED: X SERVICE: 2. Name of Operator 7. Permit Number UNOCAL 74-0009-0 3. Address 8. APl Number P.O. Box 196247 Anchorage, AK 99519 50- 733-20260-00 4. Location of well at surface 751' FSL, 1215' FWL, Sec. 6, T8N, R13W, SM At Top Producing Interval 753' FNL, 64' FWL, SEC 5, 8N 13W, SM At Total Depth 499' FNL, 730' FWL, SEC 5, 8N 13W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB above MSL I ADL 18729/17594 12. Date Spudded 13. Date T.D. Reached I 14. Date Comp., Susp. or Aband. 3/12/74 5/20/74 I 7/24~98 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 11,969' / 9,885' 11,048' / 9,148' 22. Type Electric or Other Logs Run No logs were run 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-26 11. Field and Pool McArthur River Field Middle Kenai "G" 15. Water Depth, if offshore I 16. No. of Completions 65 feet MSLI 1 I 19' Directi°nal Survey I20' Depth where SSSV setYes: No: 302 feet MD I21' Thickness °f Permafr°stN/A 23. CASING SIZE 13-3/8" 9-5/8" 7" Liner CASING, LINER AND CEMENTING RECORD 24. Perforation~ VVT. PER FT. 61 # 47, 43.5, 40# 29# GRADE K-55 N-80 & P-110 N-80 SETTING DEPTH MD TOP BOTTOM Surf. 3,306' Surf. 10,239' 10,082' 11,969' open to Production (MD+TVD of Top and Bottom and HOLE SIZE 17-1/2" 12-1/4" 8-1/2" CEMENTING RECORD 3000 sacks 4500 sacks 650 sacks 25. TUBING RECORD AMOUNT PULLED N/A N/A N/A interval, size and number) 10,668'-10,688'; 10,692'-10,709'; 10,735'-10,765'; 10,776-10,860' MD 8,843'-8,859'; 8,862'-8,876'; 8,896'-8,921'; 8,929'-8,997' TVD SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR TEST PERIOD --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 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. RECF. I¥£D Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. G-1 Top 10,611 -8,702' SS/8,808' 'rVD G-2 Top 10,665 -8,745' SS/8,851' TVD G-3 Top 10,731 -8,796' SS/8,902' TVD G-4 Top 10,792 -8,846' SS/8,952' TVD 31. LIST OF ATTACHMENTS Wellbore diagram, daily operations summary, survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~"~/~ ~~)0~ Drilling Manager May 26, 1999 Signed Title Date Dan Williamson 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 space 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 productin 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 UNC)C L Trading Bay Unit Well # D-26 P & A Workover RKB to TBG Head = 41' Tree connection: 4-1/6" 5,~000# INSIZE CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. 47 P4 10 8rd LT&C 8.681 Surf 10,239' 29 N-80 8rd LT&C 6.184 10,082 11,969' JEWEI,RY DETAIL ~ Item ,38Y 5.08 60~ Casing Patch ,780' 4.00 Brown 2B Pkr. w/miIlout ext. .796' 3.725 ()tis "XN" Nipple. size 3.813 .807' Wireline Re-entry Guide WIREI,INE Workecl a 3.0' GR to 10,155' on t/I4/97 Fill Tagged w/a 2.28" GR on 6/I 2/96 FISH: Otis Tbg. nipple plug, 12/2/92 (¢ I 1 ~796' WLM 22' of Wiretine/~lling t(~)ts. 12/2/92 (re11 ~774' WLM Coil Tubing 2.7" bil & motor assy. 4/22/94 ~r,11,642' CTM (6) Collet fingers f/CT ttyd. Disconnect ~ 11 ,()tM' (?'I'M G-2 G-3 G-4 TOF @ 10,941' @ 11,033' ~B w/CT on 4/27/94 B-3 PERFORATION DATA ZONE TOP BTM AMT SPF DATE G-2 t0,668' 10,688' 20' 6 6/18/94 G-3 10,693 10,709 16' 6 6/I9/94 10,740 10,765 25' 6 6/18/94 G-4 I0,786 10800 14' 6 6/1194 I 0~800 10.860 60' 6 5/31/94 B-I t t.210'11.243' 33' 6 Abandoned B~2 l 1,273'11.306' 33' 4 Abandoned B-3 11309' 11.435' 126' 4 Abandomxl B-5 11,642' l 1,750' 108' 6 Abandomxl B-6 11.826' 11,858' 32' 4 Abandoned B-5 Unocal Corporati( Oil & Gas Operations 909 West 9th Avenue, p.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 Alaska Dear Ms. Miller: UNOCAL( November 9, 1995 ORiGiNAL Re: Ms. Joan Miller Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 At~.~ ~i~ & (~as Cons° , ~ch0rago Dolly Varden Plaffom Well D-26 APl Number 50-733-20260 On June 19, 1994 the following intervals were perforated in Well D-26: BENCH TOP (MD) BOTTOM (MD) FEET G2 10,668 10,688 20 G2 10,693 10,709 16 G3 10,740 10,7565 25 G4 10,786 10,860 74 Total 135 verY truly yours, Candace Williams STATE OF ALASKA '~ ALASKA OIL AND OAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG i. Sta{us of Well "' ClasSifiCation 0~ Sewice Well Oil [] Gas [] .Suspended [] Abandonment [] Service [] 2. Name o~ Operator ...... 7. permit Number UNION OIL COMPANY OF CALIFORNIA (UNOCAL). ~ '~ ~'~'~ 74-9 3. AddreSs ~ W~i 8. APl Number ~.0. ~ox ~s2~7 ^.c.o~,~E, ^K ~S~ ~t?~~~ ~0 733-~0~S0-00 4. Location of well at surface ~,~ ~~~ 9. Unit or LeaSe Name 751 FSL, 1,215' FWL; Sec. 5-8N-13W-SM Trading Bay Unit At top of productive interva r~~ 10. Well Number 663' FNL, 296' FWL, Sec. 5~8N-13W-SM~ ~ ~,~ ~ ~ ~"~ L D-26 At total depth 11. Field and Pool 499, FNL, 730' FWL, Sec. 5-SN-13W-SM McArthur River Field G-Zone 5.~ Elevation in feet (indicate KB, DF, etcl) I 6. Lease Designatk~n and Serial No. 106'i ADL 18729 12' DateSpudded I 13' DateT'D'Reached3/12/74 J 14. DateComp..Susp. orAband. 15. WeterDepUllifofr~horeI,, 16. No, of Com~ i7. Total Depth (MD + TVD) I 18. Plug Back Depth (MD + TVD) 119. Directional Survey 20. Depth where SSSV set I 21. Thicl<n~ss of Permafrost 11,969'MD 9,885'TVDI 11,048'MD 9,148'TVD lyes ri , No E! 30ZI 22, ~'23. CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD _CAS_tNG SIZE VVT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8' 61# K-55 .... 0 ' 3,306' ', ' 17-1/2' 2~)0 SX ,, " " ,,, 9-5/8' 40~, 43.5~ N-80 0 101239' 12-1/4' 2690 SX , , , 7- 29~ N-sO 10,0S2' 11,952' ' .... S.1/2" S50 SX 24. Perforations open to Production (MD + TVD'of Top and Bottom and 25. TUBING RECORD ...... interval size and number) Size IDepth Set ~Di. IPacker See Attachment #1. Plugged & abandoned Hemlock and ' ' completed in G-Zone. ~~,,./ ~6. Acid, Fracture, Cement Squeeze,. Etc. /___ ../i.,A~.,,~)c~ ,1~ Depthlnterval~D) Amount& Kind of Material 0sed · 27. PRoOUCT~ON TEST Date I~irst Production Method of Operation (Flowing, gas I'~, etc.) "' Dat· of Test Houra Tested PRODUCTION FOR OIL-BBL GA~-MCF WATER-BBL CHOKE-SIZE! GAs-oIL RATIO 6/20/94 24 TEST PERIOD -) 24 125 102 251 .,~ I ~ Tubing Casing Pressure CALCULATEO OIL-BBL ' GASA~OF ' WATERLBBL OIL GRAVITY-APl (corr) Press. 110 1050 24-HOUR RATE -~ 125 102 251 ,,, 1.28~ ..... CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas'~ water. Submit core chipe. ' f,!OV 'i 'iSS5 .... ' ~ ,~orage ~ , ,, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUTED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TEST 'NAME ' ............ Include inte'rVal tested, pressure data, all fluids recovered and gravity, MEAS. DEP'CH TRUE VERT. DEPTH , ........ . 31. LIST OF ATTACHMENTS ~2. I h~reby,~ertify that the f'oregoing is true_an.~ correct to the be~t"of my knowledge ,, INSTRUCTIONS General: This form is designed for submitting a complete and correct well complete report and log on on all types of lands and leases in Alaska. Item 1: Classificaiton 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 cementing and the location of the cementing toot. Item 27: Method of Operation: Flowing, Gas LA, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If not cores taken, indicate "none". Attachment PERFORATION INTERVALS , , G-2 10,668' - 10,688' MD 8,843' - 8,859' TVD G-2 10,693' - 10,709" MD 8,863' - 8,876' TVD G-3 10,740' - 10,765' MD 8,900'- 8,921' TVD G-4 10,786' - 10,860' MD 8,937' - 8,997' TVD Page 3 i Gas Cons. Commission ;Anchorage ;"-'", STATE OF ALASKA ~" ALASKA O,L AND GAS CONSERVATION CO,,,,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE7 AK 99519 - 6247 4. Location of well at surface 751' FSL, 1,215' FWL, Sec. 5-8N-13W-SM At top of productive interval 663' FNL, 296' FWL, Sec. 5-8N-13W-SM At effective depth At total depth 499' FNL, 730' FVVL, Sec. 5-8N-13W-SM Stimulate Plugg_~ --. After casing Repair well 5. Type of Well: Development ~ Exploratory Stratigraphic __ Service DUPLICATE Perforate X Pull tubing Other 6. Datum elevation (DF or KB) 106 KB above MSL 7. Unit or Property name Trading Bay Unit , 8. Well number D-26 9. Permit number 74-9191-353 10. APl number 50-733-20260 11. Field/Pool Hemlock feat 12. Present well condition summary Total depth: measured true vertical 11,969' feat Plugs (measured) None 9,885' feat Effective depth: measured 11,905' feat Junk (measured) None true vertical 9,836' feat Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 3,306' 13-3/8' 2,750 sx 3,306' 3,148' Intermediate Production 10,239' 9-518" 2,690 sx 10,239' 8,501' Liner 1,870' 7" 650 sx 11,952' 9,877 13. Perforation depth: measured Sea Attachment #1 true vertical ~,'. ~... I...I ' i... Tubing (size, grade, and measured depth) 0 995 4-112" 12.6# L80 Butt Tbg w/Butt MOd couplings to 10,149' Packers and SSSV (type and measured depth) Brown 2B Pkr ~ 11,780'; Baker SABL-3 Pkr 4.0" ID (~ 10,111'; Camco TRDP-4A TRDV ~ 302' ~ta~ka 0it & GaS C01~S. Stimulation or cement squeeze summary .... '/~ch0rage Intervals treated (measured) 14. Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation 5/2/95 68 0 37 1022 140 Subsequent to operation 7/27195 211 182 2317 1037 110 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the forint/is true.pnd ~F),~ect to .~ of my knowledge. Signed G. Russell Schmidt ~-~1~~ ~~le Drilling Manager Form 10-404 Rev 06/15188 /r __ SUBMIT IN DUPLICATE ;t0~t Sheet2 ATTACHMENT #1 ,, TBU WELL D-26 PERFORATION INTERVALS G-2 10,668' - 10,688' MD 8,843' - 8,859' TVD G-2 10,692' - 10,709' MD 8,862' - 8,876' TVD G-3 10,735' - 10,765' MD 8,896' - 8,921' TVD G-4 10,776'- 10,860' MD 8,929'- 8,997' TVD I B-1 11,210' - 11,243' MD 9;285' - 9,310' TVD B-2 ....... 11,273' - 11,306' MD 9,335' - 9,363' TVD B-4 11,468' - 11,615' MD 9,496' - 9,611' TVD B-5 11,642' - 11,732' MD 9,632' - 9,702' TVD B-6 11,828' - 11,858' MD 9,778' - 9,,802' TVD Page I Unocal Corporation/'~",.. Oil & Gas Operations 909 West 9th Avenue ..... Box 196247 Anchorage. Alaska 99519-6247 Telephone ~907) 276-7600 UNOCAL., October 17, 1995 Alaska DUPLICATE Mr. Russ Douglas, Commissioner Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Mr. Douglas: Re: Dolly Varden Platform Well D-26 APl Number 50-733-20260 On July 25, 1995 the following intervals were perforated in Well D-26: BENCH TOP (MD) BOTTOM (MD) FEET G2 10,668 10,688 20 G2 10,692 10,709 17 G3 10,735 10,765 30 G4 10,776 10,860 84 TOTAL 151 Very truly yours, Candace Williams 0CT 2 0 ~995 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION COMM,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Operation shutdown Re-enter suspended well Plugging ~ /~,~..i~et.~e extension Stimulat-'~' Pull TUbing__ ' Variance__ Abandon Suspend Alter casing__ Repair well __ Change approved program__ 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 5. Type of Well: Development Exploratory Stratigraphic Service 3. Address P.O. Box 196247 Achorage, AK Leg A-1 Con. #7 Dolly Varden Platform 4. Location of well at surface 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number 751' FSL, 1,215' FWL, Sec. 5-8N-13W-SM At top of productive interval 663' FNL, 296' FVVL, Sec. 5-8N-13W-SM At effective depth At total depth 499' FNL, 730' FWL; Sec. 5-8N-13W-SM 12. Present well condition summary Total Depth: measured true vertical RECEIVED 1 1 1994 N~ska 0il & Gas Cons. Commissi D-26 9. Permit number/approval number 74-9 10. APl number 50- 733-20260 31~. Field/Pool Hemlock 1 1,969' feet Plugs (measured) None 9,885' feet Effective depth: measured true vertical 1 1,905' feet Junk (measured) 9,836' feet 11,760' Wireline Tool String casing structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Length Size Cemented Measured depth True vertical depth 3,306' 13-3/8" 2,750 sx 3,306' 3,148' 10,239' 9-5/8" 2,690 sx 10,239' 8,501' 1,870' 7" 650 sx 11,952' 9,877' B-1 11,210' - 11,243' MD 9,283' - 9,310' TVD B-2 11,273' - 11,306' MD 9,335' - 9,393' TVD B-4 11,468' - 11,615' MD 9,496' - 9,611' TVD B-5 11,642' - 11,750' MD 9,632' - 9,720' TVD B-6 11,828' - 11,858' MD 9,778' - 9,802' TVD 4-1/2" 12.6# L-80 Butt Tbg w/Butt Mod couplings to 10,149' Packers and SSSV (type and measured depth) ... Brown 2B Pkr @ 11,780'; Baker SABL-3 Pkr 4.0" ID @ 10,111'; Camco TRDP-4A TRFV ~ 302' 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch X~ Estimated date of commencing operation 15. Status of well classification as: April 24, 1994 If proposal was verbally approved Oil ~ Gas __ Suspended Service 17. I h~~ect to the best of my knowledge. Signe COnditions of approval: Notify Commission so representative may witness Plug integrity.~ BOP Test Location clearance MechaniCal Integrity Test w "~ubsequent form required 10-'~- 4~ Approved by order of the Commision Original Signed By David W. Johnston Approved Copy Returned IApprova, No. Commissioner Form 10-403 Rev 06/15/88 Date SUBMIT IN TRIPLICATE PROCEDURE DOLLY VARDEN PLATFORM WELL D-26 Objective' Plugback Hemlock and recomplete as a G-Zone producer. 1) RU coiled tubing unit. Pressure test lines from pumping unit to coil to 5000 psi. Pressure test coil, BOP's, and lubricator to 5000 psi. Function test BOP's. 2) SI lift gas and let well die. Fill annulus with 550 BBLs FIW. 3) RIH with cementing nozzle. Fill tubing with water. SI backside and establish injection pressure @ 1/4, 1/2, & 3/4 BPM not exceeding 3000 psi tubing and coil annulus. 4) Mix up 25 BBL's cement with additives for set time of 8 hours @ 183 F BHT and fluid loss not exceeding 50 cc's in 30 minutes. 5) With coil positioned 10' above fill noted, pump 2 bbls fresh water and start cement down coil @ 1 bpm. PU coil tubing as cement is placed in casing to maintain 20' under TOC. Place cement top @ 11,090'. PU coil to 10,500'. SI backside and pressure squeeze to 3000 psi. 6) WOC 12 hours. Retest squeeze to 3000 psi if pressure has dropped. RIH and tag TOC. Ensure TOC is above 11,150'. Ideal TOC @ 11,100'. Cap cement top to 11,100' if TOC is below 11,150'. 7) Unload tubing and casing. SI tubing when casing pressure flatlines on two pen recorder. Monitor for PBU for 3 hours. 8) RU E-Line unit. Pressure test BOP's lubricator. 9) RIH and perforate the following intervals underbalanced: Guns: 3-3/8" HC, 6 SPF, 60 Degree phase RUN ZONE INTERVAL FOOTAGE 1 G-4 10,830'-10,860' 30' 2 G-4 10,800'-10,830' 30' 3 G-4 10,786'-10,800' 14' 4 G-3 10,740'-10,765' 25' 5 G-2 10,693'-10,709' 16' 6 G-2 10,668'- 10,688' 20' COMMENTS Do not flow well for 1st run. 10) RD. Return well to production. 4/14/94 h:\wp\Sund~\D-26 RECEIVED N1AY l l 1994 Alaska 0il & Gas Cons. Commission Anchorage ICURR CoMpleted 5/20/91 9-5/8' 40. 43.5, 47~, N-80 & P-110 Butt Cs9 MARATHON OIL COMPANY~x TRADING BAY UNIT WELL D-86 Att Measurements ore RKB to top oF equipment. 41' CIW 4.5' Tbs Hanger 308' CaMco TRDP-4A TRFV SCSSV, 3.813' pro~'Ite w/ DB-6 loci< Comptetlon String: 0'-10,149' 4.5' 18.6#, L-80 Buttress tubing w/ Buttress ModiFied coupUngs. Gas lift Mandrels are 4.5' Danlets GLM 2A w/ 1.5' side pockets, RK latch. 2,224' #1 4,125' ~2 5,767' ~3 6,896' ~4 7,746' #5 8,488' #6 8,997' ~7 9,477' ~8 9,996' ~9 NOTE: 3.7" GR to 7,667' 2/94 3.5" GR to 9,027' TBG NOT CLEARED TDL 7' 10,082' 9-5/8' Cs9 8 10,839' 7' 89~ N-80 X-Une Fill @ 11,704' 8/3/91 PBTD 8 11,905' TD 8 1L969' B-1 B-8 B-3 B-4 10,052' 10,111' 10,138' 10,149' 15' BoRer PBR w/ scoop 4.75' I.D. 1 jt 4-1/8' L-80 Buttress tubing. Baker SABL-3 Packer. 4,00' I,D. 6' Mlllout extension. X nipple 3.813' I.D. BoRer Model E Hydro-trip Sub. 4,00' I.D. ~ire[ine Re-entry guide. 4.00' I.D. RECEIVED MA'¢ 11 1994 PerForations ..,~o~o ~,, ~ ~as Cons. Commissio~ B-1 11,810'-843' 6 SPF B-8 11,873'-306' 4 SPF Anchorage B-3 11,390'-435' 4 SPF · CMt. Squeezed B-4 1L468'-615' 6 gPF B-5 11,648'-750' 6 SPF B-6 11,886'-858' 4 SPF C(~sln9 porch set across Bench 3 Interval PrOM 11,383'-1L443' reduces I,D. by 0.5' 11,780' Brown Model 2B Isolotlon pkr. M~Uout extension 11,796' XN N~pp[e 3.813' I.D. w/ 3.725' No - Go. 11,808' ~hreUne Re-en~ry Gumle. 1L760' Top oF FISH - ~/;re[lne too[ storing in isolation packer. Revision Date, 4/12/94 Rev;sed ]By, $gL/evo Reosom U~do~e Previous Rewsion: 10/5/93 I PFROPOS ZDI Completed 5/20/91 9-5/8' 40. 43.5, 475, N-80 & P-110 Butt Cs9 MARATHF1N []IL TRADING BAY UNIT WELL D-26 Alt measurements are RKB to top of' equipment. 41' CIW 4,5' Tbs Hanger 302' CAMCO TRDP-4A TRFV SCSSV, 3,813' proFKe w/ DB-6 Lock CoMoletlon String, 0'-10,149' 4.5' 12.6~t, L-80 Buttress tubing w/ Buttress Modified coupbn9s. G~s ~iFt ~nd~e[s ~re 4.5' 9onlels GLN 2A w/ 1.5' side pockets, RK latch, ~224' 4,125' 52 ~767' 53 ~896' 54 7,746' 55 ~482' 56 ~997' 57 %477' 58 ~996' 59 RECEIVED MAY 11 1994 Alaska 0il & Gas Cons. Commission Anchorage TDL 7' 10,082' 9-5/8' Cs9 10,239' 7' 29# N-80 X-line PBTD 8 11,905' TD 8 11,969' 1~052' l~lll' 1~132' 1~149' 15' Baker PBR w/ scoop 4,75' I,D, 1 jt 4-1/2' L-80 Buttress tubin9, Baker SABL-3 Packer. 4.00' I.D. 6' M;Ltout extension, X nipple 3,813' I,D, Baker Mode[ E Hydro-trlp Sub, 4,00' I.:D. ~/lre[lne Re-entry guide, 4,00~ I,D, Proposed G-Zone 11,668' - 11,860' TOC 11,100' Perf,oratlons B-1 11,210'-243' 6 SPF B-2 11,273'-306' 4 SPF B-1 B-3 11,390'-435' 4 SPF B-4 11,468'-615' 6 SPF B-5 11,642'-750' 6 SPF B-2 B-6 11,826'-858' 4 SPF B-3 B-4 · CML, Squeezed Casing pa~ch set across Bench 3 interval f'rOM 11,383'-11,443' reduces I.D, by 0,5' B-5 11,780' Brown Mode[ 2B IsoLation pkr. Mit[out extension 11,796' XN NippLe 3,813' I.D, w/ 3,725' No - Go. 11,808' ~/lretlne Re-entry Guide. B-6 11,760' Top oF FISH - Wire[Ine too[ string in isolation packer. Revision Date, 4/14/94 Revised By, SSL/evo Reoson:_ P~opose.ct . Previous h[evi$ion: 2/9/94 Coiled DOLLY VARDEN PLATFORM Tubing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 psi WP ------ HYDRAULIC RAMS .'4 1/16, 5000 psi CHISTMAS TREE J,ll~ POSITIVE CHOKE RECEIVED MAy 1--1 1994 Alaska 0il & Gas Cons. Commission Anchorage 2' 5000 psi · 2' 3000 13 3/8' CASING DOLLY VARDEN 'PLATFORM Wireline Lubricator w/Associated BOPE f - GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP ii · · 4'~11~.6~. 5000 pal CHISTMAS TREE POSITIVE CHOKE RECEIVED Nask~ 0il & {~as Cons. Commission Anchorage 2' 5000 psi 2' 3000 pal 13 3/8' CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,.,31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operations Shutdown__ Stimulate__ Plugging__ Perforate__ Pull Tubing ~ Alter Casing__ Repair Well __ Other X Workover 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL (Marathon Oil Company - Sub Operator) Development X 106' KB above MSL feet Exploratory 3. Address Stratigraphic -- 7. Unit or Property name P.O. Box 196247 Anchorage, AK 99519 Service ~ Trading Bay Unit 4. Location of well at surface Leg A-1 Con. #7 Dolly Varden Platform 8. Well number 751' FSL, 1,215' FWL, Sec. 5-8N-13W-SM D-26 At top of productive interval 9. Permit number/approval number 663' FNL, 296' FWL, Sec. 5-8N-13W-SM 74-9 / 91-188 At effective depth 10. APl number 50- 733-20260 At total depth 11. Field/Pool 499' FNL, 730' FWL, Sec. 5-8N-13W-SM Hemlock 12. Present well condition summary Total Depth: measured 1 1,969' feet Plugs (measured) None true vertical 9,8 8 5' feet Effective depth: measured 1 1,905' feet Junk (measured) None true vertical 9,836' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor surface 3,306' 13-3/8" 2,750 sx 3,306' 3,148' Intermediate Production 10,239' 9-5/8" 2,690 sx 10,239' 8,501' Liner 1,870' 7" 650 sx 11,952' 9,877' Perforation depth: measured See Attachment #1 ~E ¢ E IV E D true vertical - i994 Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 Butt Tbg wi Butt Mod couplings to 10,149' .~ .... ~',~,~ u:, ~, C-,,as Cons. Comrllisslon Packers and SSSV (type and measured depth) Anchorage Brown 2B Pkr .(~ 11,7.80'; Baker SABL-3 Pkr 4.0" ID @ 10,111'; Camco TRDP-4A TRDV @ 302' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcf Water-Bbl. Casing Pressure Tubing Pressure Prior to well operation 4/24/91 117 198 2,225 1,21 0 100 Subsequent to operation 5/25/91 124"'''/ 125 1,320 1,075 120 15. Attachments 16. Status of well classification as: Copies of Log and Surveys run Daily Report of Well Operations X Oil X Gas Suspended Service Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE~ Attachment #1 TBU Well D-26 Perforation Intervals B-1 B-2 B-4 B-5 B-6 11,210' - 11,243' MD 11,273' - 11,306' MD 11,468' - 11,608' MD 11,642' - 11,732' MD 11,828' - 11,858' MD 9,285' - 9,310' TVD 9,335' - 9,363' TVD 9,496' - 9,606' TVD 9,632' - 9,702' TVD 9,778' - 9,802' TVD docs\DVP\D26, doc Attachment #2 04/27/91 TBU Well D-26 Summary of Daily Well Operations Workover RECEIVED [~,AR -~ 4 1994 Oil & G~s Cons. Commission Anchorage Accepted rig at 00:01 hrs 4/27/91. Started moving equipment from Rig 77 to Rig 76. 04/28/91 Rig start up. Moved equipment from Rig 77. Hung off BOP's. R/U lines to D-26. Filled annulus w/420 bbls KCL. Rig up Schlumberger and perforated TBG from 9923'-9925'. 04/29/91 Killed well using 3% KCL with returns to well clean tank. Hole taking 25-40 bbls per hour. Mixed and pumPed 40 bbls HEC. R/U w/c and set bridge plug at 10,030'. Set BPV. N/D tree. Started N/U BOP's. 04/30/91 N/U and tested BOP's. Screwed into hanger. Backed out hold down pins. Pulled pkr free w/225K lbs. Circulate gas cut fluid out on choke. Monitored well - stable. POOH L/D 6 jts - hole swabbing. Monitored well - slight flow. Circ through choke. 05/01/91 R/U E-line and perforated tail piPe. pOOH L/D tbg. Hole initially taking fluid. Hole stopped taking proper fluid. S/I - No flow. Continued POOH closely monitoring well. After 173 jts L/D well started to flow slightly. CBU through choke. S/D pump - slight flow. S/I well and monitored build up - 36 psi on tubing after I hour. 05/02/91 Circulate on choke - shut in and monitor. SIDPP 45 psi SICP 37 psi attempt to bleed off pressure w/o success RIH picking up DP to TOL displace hole with brine - well dead POOH w/ DP. 05/03/91 Finished L/D tubing and packer - RIH w/9-5/8" scraper picking up 5" DP to top of liner at 10,081'. Circulate and filter. POOH. Daily Summary of Well uverations Well D-26 Workover Page 2 RECEiv u MAR - 4 1994 ~:~:~,:;ka Oil & Gas Cons. Commission 05/04/91 Anchorage POOH w/ 9-5/8" scraper ran storm packer to 500' and set same. POOH P/U BOP stack and inspect tubing spool. Change spool and N/U stack. o5/o5/9z Finished N/U BOPE and test to 250/2500 psi and annular 250/1500 psi. Retrieve storm packer and POOH. RIH with wash shoe and scraper. Wash fill 11,789'-11,901'. Circulate and filter hole clean. POOH. Had to begin pumping out after 3 stands pulled. 05/06/91 Pumped out of liner and POOH. Ran GR/CBT/CET across liner. Ran gauge ring and junk basket to 11,640'. Ran retainer and set at 11,447'. R/D E-line. RIH w/ retainer on drill pipe. 05/07/91 RIH and set retainer at 11,350' DPM. Squeeze bench 3 perfs with 45 SX to final 1/8 BPM at 5000 psi. Reverse out and POOH. RIH with retrievable pkr and set in liner at 10,139'. Test casing and liner lap to 2500 psi. POOH. WOC. 05/08/91 RIH w/6" bit. Drill retainers and cement 11,350'-11,458'. Push to bottom. Circulate and filter. POOH. P/U watermelon mill and RIH. 05/09/91 RIH w/watermelon mill. Worked through tight spots at 10,881', 10,915' and 11,088'. CBU. POOH. R/U E-line and set bridge plug at 11,320' DIL. P/U TCP guns and RIH. 05/10/91 RIH w/TCP guns. Correlated guns. Set pkr and perforated B-1 11,210'-11,243'. Flowed well to bubble bucket for 30 min. S/I for i hr. reversed out 60 bbls influx to well clean tank. POOH L/D guns. RIH open ended tagged bridge plug at 11,323' DPM. P/U 150' and dropped 12 SXS sand. Tagged fill at 11,270' DPM (53' fill). 05/11/91 POOH to 4500'. RIH and tagged sand at 11,269'. Dropped 3 SXS sand. POOH to 10,597'. R/U Schlumberger. RIH w/GR CCL tagged sand at 11,241' DIL. R/D Schlumberger. RIH and tagged sand at 11,256' DPM. POOH. Tested BOP's. P/U frac BHA. Tested to 7000 psi. RIH w/frac equipment on 3-1/2", S135 drill pipe. Daily Summary of Well ~erations Well D-26 Workover Page 3 05/12/91 RIH w/frac string. Tested string to 7000 psi. Set pkr at 10,996'. Pressured up annulus to 2000 psi. R/U Dowell. Held safety meeting. Tested lines to 12,000 psi. Pumped data frac. R/U Schlumberger and ran GR temp log. 05/13/91 RIH w/linc tool and downloaded data. POOH. Analyzed data. Tested lines to 12,000 psi. Pumped 152 bbls YF140 gel w/24,647 lbs 20-40 carbo lite. Displaced w/84 bbls YF 140 at 15 BPM. Final pressure 7665 psi. Monitored fall off. Opened pkr bypass and reversed out. Unset pkr. POOH L/D 3-1/2" frac string. 05/16/91 RIH with casing patch. Correlated same with GR log set patch 11,383'-11,443'. POOH L/D DP and DC's. 05/17/91 Change rams to 4-1/2" and test to 2500 psi. R/U and run 7" packer on 4-1/2" tubing. Set packer and test csg to 1500 psi. Circulate and inhibit packer fluid. 05/18/91 Inhibited packer fluid and displaced tubing with brine. Sting into packer at 10,111' and land hanger. Set BPV and N/D BOPE. Install tree and test same to 5000 psi. Skid rig and remove BOPE from sub. L/D Kelly and swivel. 05/19/91 Deactivating rig. 05/20/91 Deactivating rig. 05/21/91 Deactivating rig - Rig released at 12:00 hrs on 5/20/91. Final Report. \docs\dvp\d26. doc I I I I I I (:3 I (/3 (,~ 0 (4 0 0 · F I (~co z-~ z -< STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,,.,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operations Shutdown__ Stimulate__ Plugging __ Perforate X.~ Pull Tubing m Alter Casing __ Repair Well m Other 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P.O. Box 196247 Anchorage, AK 99519 Development Exploratory Stratigraphic Service 4. Location of well at surface 751' FSL, 1,215' FWL, Sec. 5-8N-13W-SM At top of productive interval 663' FNL, 296' FWL, Sec. 5-8N-13W-SM At effective depth At total depth 499' FNL, 730' FWL, Sec. 5-8N-13W-SM 5. Type of Well: 12. Present well condition summary Total Depth: measured true vertical Leg A-1 Con. #7 Dolly Varden Platform R£C£1V D ~!.~.;.~ 0il & Gas Cons. Ccmmissim ~ "'~ ~1~' A,qc;,gr-~- 6. Datum elevation (DF or KB) 106' KB above MSL -~feet 7. Unit or Property name Trading Bay Unit 8. Well number D-26 9. Permit number/approval number 74-9 / 91-353 10. APl number 50- 733-20260 11. Field/Pool Hemlock 11,969' feet Plugs (measured) 9,885' feet None Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 11,905' feet Junk (measured) 9,836' feet Length Size Cemented 3,306' 13-3/8" 2,750 sx 10,239' 9-5/8" 2,690 sx 1,870' 7" 650 sx See Attachment #1 None Measured depth True vertical depth 3,306' 3,148' 10,239' 8,501' 11,952' 9,877' 13. Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 Butt Tbg w/Butt Mod couplings to 10,149' Packers and SSSV (type and measured depth) Brown 2B Pkr @ 11,780'; Baker SABL-3 Pkr 4.0" ID @ 10,111'; Camco TRDP-4A TRDV @ 302' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation 10/24/91 Subsequent to operation 11/3/91 Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcr Water-Bbl. Casing Pressure 177 348 2,007 1,080 ,. 250 ~ 245 2,968 1,100 Tubing Pressure 130 160 15. Attachments Copies of Log and Surveys run Daily Report of Well Operations X 16. status of well classification as: Oil X Gas Suspended Service -- 17. I hereby c,e~tify that the foregoing is true and correct to the best of my knowledge Signed j~' ~.~~ Title~ [(''('' {/k~'k Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE.~ Attachment #1 TBU Well D-26 Perforation Intervals B-1 B-2 B-4 B-5 B-6 11,210' - 11,243' MD 11,273' - 11,306' MD 11,468' - 11,615' MD 11,642' - 11,732' MD 11,828' - 11,858' MD 9,285' - 9,310' TVD 9,335' - 9,363' TVD 9,496' - 9,611' TVD 9,632' - 9,702' TVD 9,778' - 9,802' TVD docs~DVP~D26, doc RECEIVED ;,~,:~.:;,.a u~i & G:~:s Csns. CmnmissJon Ans~orago DAILY NELL OPERATIONS 0-26 11/2/91 HLS RU. Took SCSSV off the well room panel and hooked up the auxiliary pump. Apply 4000 psi. Monitor. Held safety meeting. Pressure test lubricator to 2500 psi. Good test. Establish communications blackout. RIH w/ 3-3/8" guns 6SPF, 60 degree phasing. Flowed well to obtain underbalanceo Perforated the following intervals: RUN #1 HB-4 11,585' - 11,615' DIL Fired #2 HB-4 11,555' - 11,585' DIL Fired #3 HB-4 11,525' - 11,555' DIL Fired #4 HB-4 11,508' - 11,525' DIL Fired RD. Turned well over to production. RECEIVED I,AAR - 4 199~ Gas Cons. [~ammission Anchorage H: \wp\WEL LOPS\D26 ALASKA OIL AND GAS CONSERVATION CO~IMISSION WAITER J. HiCKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 July 14, 1993 M~'. G. Russell Schmidt Drilling Manager UNOCAL P.O. Box 190247 Anchorage, Ak. 99519-0247 Re: Trading Bay Unit, AOGCC Forms 10-403 and 10-404 Dear Mr. Schmidt, In' conducting an audit of well files I have found a number of wells containing approved Application of Sundry Approval forms (form 10-403) with no subsequent Report of Sundry Well Operations (form 10-404). Enclosed is a list of the wells in question. , To be in compliance with AS' 20 AAC 25.280(d) of the Regulations, the Form 10-404 is required to be filed within 30 days following completion of work. ~ in previous telephone conversatiqns concerning the subject, it had beeq_.explained to me that either ARCO or Marathon had been the~l~operator on the majodty of the work proposed; hoWever, it is the feeling of the Commission that if the work was completed, it is UNOCAL's responsibility to see that the appropriate paperwork be filed in a timely manner inasmuch as UNOCAL is the operator of the field and UNOCAL personnel signed the Application' of Sundry Approval forms. Your assistance in supplying us with the appropriate forms and in helping resolve this problem.in the future will be appreciated. We would also appreciate notification of any canceled Work so that the corresponding Application on file can'be marked accordingly.. ~... _ Sincerely, · · ~tatimic.,al 'l'echni¢ian ~ p, inled on recycled paper b ¥ ~'~'"~. - . Well Permit No. No. _ D-4 82-41 D-SRD 80-65 D-26 D-27 75-24 D-40 82-83 D-42 83-53 D-46 89-61 Approval Date & No. 3-1-91, 91-060 5-31-91, 91-163 7-2-91, 91-188 11-22-91, 91-353 9-2-91, 91-189 9-20-91, 91-284 11-27-91, 91-361 5-21-91, 91-161 10-24-91, 91-317 5-31-91, 91-160 7-2-91, 91-190 5-31-91, 91-162 12-11-91, 91-387 Trading Bay Unit Description Perforate 2-91 Perforate 5-91 Workovef 4a91 Perforate 11-91 Perforate 6-22-91 Reperf HB4/Pump Clay Stab. 9-10-91 Stimulate 12-8-91 CT Cleanout 5-28-91 Reperf. HB2,3&$4 10-3-91 Perf 5-91 Scale Cleanout 6-20-91 Perf 5-91 Reperf HB-2 11-91 10-403 Signed By G. Bush G. Bush G. Bush G. Bush G. Bush' G. Bush G. Bush G. Bush G. Bush G. Bush G-5 67-71 G-6 82-33 3/15-91, 91-086' 10-30-91, 91-325 4-21-92, 92-093 Short & long inj. profile (If work was completed the 10-403 required a 10-407, Completion, Recompletion report for this well. Perf. 10-19-91 Perf 4-92 G. Bush G. Bush G. Bush G-17 G-19 G-21 G-27 78-3 69-17 72-42 . 78-70 G-31 69-72 K-1 67-65 K-2RD 78-38 K-3 80-144 'K-9 68-38 11-1-91, 912331 11-10-92, 92-238 4-21~92, 92-094 6-17-93, 93-154 4-21'92, 92-95 i16/93, 92-203 3-21-91, 91-95 2-9-90, 90-082 10-11-88, 8-771 6-8-90, 90-440 7-9-91, 91-197 2-9-90, 90-081 11-14-89, 9-987 Perforate Temp. log 10-15-92 Perf4-92 Coil tubing cleanout Perforate Convert to inj. Production profile Perforate 2/90 Perf., cement squeeze Stim, p. tubing, perf. 6-90 Perforate 6-91 Perforate 2/90 Repair well, p. tubing, stimulate, perforate G. Bush . G. Bush ., G. Bush Ri" Schmidt ~:~ ~.- ~ . . . · ,.G~Bush R S chmidt G. Bush R. Roberts R. Roberts G. Bush G. Bush R. Roberts R. Roberts ?--% STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator ! 5. Type of Well: ' ' " .... ub '~ eralor' Development UNOCAL (Marathon Ul I [.,O- ~ up '~ ) Exploratory Z 3. Address ! Stratigraphic_ P. 0. Box 190247 Anchorage, AK 995~9 Service__ 4. Location of well at sudace Leg A-1 Cond. #7 Dolly Varden Platl'on-ii Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing ~ Variance __ Perforate ~ Other __ 751' FSL, 1,215' FWL, Sec. 5- 8N- 13W- SM At top of productive interval 663' FNL, 296' FWL, Sec. 5- 8N- 13W- SM At effective depth At total depth 499' FNL, 730' FWL, Sec. 5- 8N- 13W- SM 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-26 9. Permit number 74-9 10. APl number so-733-20260 11. Field/Pool Hemlock feet 12. Present well condition summary Total depth: measured true vertical 11,969 ' feet Plugs (measured) 9,885' feet Sand Plug ~ 11,791' Effective depth: measured true vertical Casing Length Structural Conductor Surface 3,306' Intermediate __10,239 ' Production Liner 1,870' Perforation depth: measured 11,905 ' feet Junk (measured) 9,836' feet Size Cemented 13-3/8" 2,750 sx 9-5/8" 2,690 sx 7" 650 sx trueve~l Attachment #1 None Measured depth True vertical depth 3,306' 3,148' 10,239' 8,501' 11,952' 9,877' RECEIVED Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 Butt tbg w/ Butt Modified couplings to 10,149' Packersand SSSV (type and measured depth) Brown Model 2B Isolation Pkr ~ 11,780' Baker SABL-3 Pkr 4,0" ID ~ 10,111.'; Camco TRDP-4A TRBV ~ 302' 13. Attachments 1, 2, Description summary of proposal --,X- Detailed operations program · BOP sketch .Z.. &3 Alaska 0ii & Gas Cor~s. OommJssior 14. Estimated date for commencing operation 11/2/91 16. If proposal was verbally approved Lonn ~ e Smith Name of approver I 1/91 I~te approved 15. Status of well classification as: Oil.Z_ Gas__ Suspended__ Service Date J Approval N/~//._ 0R~iNAL SIGNED BY LONNIE O. SMITH Commissioner Date 17. I hereby ce~/that the foregoing is true and correct to the best of my knowledge. Signed/ ~ ~, _.~..c~, ~ . (~ ,..,<3~ Fo~it~oM~Mi~,~iON~6~S~E ~ N Ly¥'L.~ Conditions of ap~J)val: NOtify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~.-~- Approved by order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 TBU WELL D-26 PROCEDURE TO REPERF & PERF HB #4 1) 2) 3) 4) 5) Obtain a 24-hour well test with a minimum of four (4) WC's. Skid rig #76 over D-26 {leg A-l). RU E-Line unit. Hook up platform communication system in unit. Pressure test lubricator and BOPE to 2500 PSI. Apply 4000 PSI control line pressure to the SCSSV with the auxiliary pump and monitor for any leak off prior to RIH. Pump to be located near lower wellroom entry door. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT USING THE PERFORATING CHECK LIST. RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE 0 1000' WHEN POOH. RIH with 3-3/8" carrier guns, 6 SPF, 60 -Degree phasing and perforate the following intervals underbalance. (Do not exceed the depth of 11,750' when RIH due to fish.) RUN BENCH INTERVAL (DIL) FOOTAGE i HB #4 11,585' - 11,615' 30 2 HB #4 11,555' - 11,585' 30 3 HB #4 11,525' - 11,555' 30 4 HB #4 11,508' - 11,525' 17 6) RD E-line unit. Return well to production and obtain two 24-hour well tests w/ 4 WC's. \docs\oe60\23. doc RECEIVED Attachment #2 . DOLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) LUBRICATOR · 4'~1~.i.6~.5OOO psi CHISTMAS TREE POSITIVE CHOKE RECEIVED i~!~:_~l 1 ~ ~ " Alaska Oil &. Gas Cons, CommiSsion ~,~chomg~ ---- 2' 5000 p;I 2' 3000 psi 13 3/8' CASING Attachment ~:3 MARATHON FIIL ~L3MPANY TRADING BAY UNIT WELL D-P6 Completed 5/20/91 9-5/8" 40. 43.5, 47~¢, N-80 & P-Il0 Butt Csg TOL 7" 10,082' 9-5/8" Cs9 10,239' 7" 29~4 N-80 X-line PBTD @ 1L~05' TD @ 11,969' B-1 B-3 B-4 B-5 AL/ measurements are RKB to top oF equipment. 41' CIW 4.5' Tbg Hanger 308' Camco TRDP-4A TRFV SCSSV, 3.813' I.D. Comp(eft;ion String: 0'-10,149' 4.5' lP.6t*, L-80 Buttress tubing w/ Buttress ModiFied couplings, Gas LiFt mandrels (~re 4,5' Donle~s GLM 2A w/ 1,5' side pockets, RK latch. 2,224' ~1 4,125' ~2 5,767' ~3 6,896' ~4 7,746' ~5 8,482' ~6 8,997' ~7 9,477' ~8 9,996' ~9 RECEIV[D I i Abska Oil o,"' Gas C0~,s.' ' Commission Anchorage 10,052' 10,111' 10,132' 10,149' 15' Baker PBR w/ scoop 4.75" I.D, 1 jt 4-1/2" L-80 Buttress tubing. Baker SABL-3 Packer-. 4.00" 6' mitLout extension. X nipple 3.813" I.D. Bcker Model E Hydro-trlp Sub, 4.00' I,D. V/ipe[;ne Re-entry 9ulde. 4.00" ~.D. PerForations B-1 11,810'-~43' 6 SPF B-~ 11,~73'-306' 4 SPF B-3 11,390'-435' 4 3PF B-4 11,468'-615' 6 SPF B-5 11,642'-750' 6 SPF B-6 11,826'-858' 4 SPF ·Cmt, Squeezed Casing patch set across Bench 3 interval From 11,383'-11,443' reduces I.D. by 0.5' 11,780' Brown Model 8B IsoLation pkr. Mittout extension 11,796' XN Nipple 3.813" [,D, w/ 3.785" No - Go, 11,808' Wiretine Re-entry Guide. 11,760' Top of FISH - Wiretine tool string in isototlon p~cker, Revision Date: 11/6/91 Revised By: JDM/evo Reason: Update STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casmg w Repair well __ Change approved program __ Name of Operator I 5. Type of Well: 2. ' ...... ub 0 eralor· UNOCAL (Marathon U1 / L,O - ~) P 'F ) Exploratory__ 3. Address ! Stratigraphic __ P, 0, Box 190247 Anchorage, AK 995~9 Service__ 4. Location of well at surface Leg A-1 cond' Cf7 Dol]y Varden Platfor~ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ ~ Perforate __ Other Workover 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Tradin9 Ba), Unit 8. Well number feet 751' FSL, 1,215' FWL, Sec. 5- 8N- 13W- SM At top of productive interval 663' FNL, 296' FWL, Sec. 5- 8N- 13W- SM At effective depth At total depth 499' FNL, 730' FWL, Sec. 5 - 8N - 13W - SM 9. Permit number 74-9 10. APl number 5o-733-20260 11. Field/Pool Hell ock 12. Present well condition summary Total depth: measured true vertical 11,969' feet 9,885' feet Plugs (measured) Sand Plug g 11,791' Effective depth: measured 11,905 ' feet true vertical 9,836 ' feet Casing Length Size Structural Conductor Surface 3,306' 13-3/8" Intermediate 10,239' 9-5/8" Production Liner 1,870' 7" Perforation depth:measured See Attachment #1 true vemca Tubing (size, grade, and measured depth) 4-1/2" 12.6# N-80 SL tb to 10 045' Packers and SSSV (type and measure~depth) ' D:::,I,,.~ I:'LI Dbv,, A /'tm, Trl /R 1(1 ~Ft")l. /'~.~4,- O%1 13. A~'a~;~nt~ ....... ¢~'scril~tGn~ur~'y"o't'p~)p~s~af ~-'"' Junk (measured) Cemented 2,750 sx 2,690 sx 650 sx None Measured depth True vertical depth 3,306 ' 3,148' 10,239' 8,501' 11,952' 9,877' RECEIVED JUL - 1 1991 Alaska 0ii & Gas Cons. C0mmissiotl Anchorage I'tV ~21 O¢10 I "ClCt'&ile"d'bp~ra'ti~s program .,,z. BOP sketch .,%. 14. Estimated date for commencing operation ! 15. Status of well classification as: 4/27/91 I 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Russ Doug.l ass 4/20/91 N ale of approver Date approved I Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title FOR COMMISSI(i)N USE OIq~.Y Conditions of approval: Notify Commission so representative may witness Date ¢///,,,~/~/ J Approval No. ~i,/./ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 1c- OrOnal Signed By Approved Copy Da. vid W. John Approved by order of the Corem --._ Commissioner Form 10-403 Rev 06/15/88 ---~'""~: -~'""'~-~" "-' Date SUBMIT IN TRIPLICATE r Attachment #1 TBU Well D-26 Perforation Intervals B-1 B-2 B-3 B-3 B-4 B-5 B-6 11,213' - 11,243' MD 11,273' - 11,306' MD 11,390' - 11,410' MD 11,410' - 11,435' MD 11,468' - 11,608' MD 11,642' - 11,732' MD 11,828' - 11,858' MD 9,285' - 9,310 9,335' - 9,363 9,432' - 9,449 9,449' - 9,469 9,496' - 9,606 9,632' - 9,702 TVD TVD TVD TVD TVD TVD 9,778' - 9,802 TVD docs\DVP\D26.doc RECEIVED J U L - 1 199t Alaska Oil & Gas Cons. Commission Anchorage Attachment #2 TBU Well D-26 KILL WELL & NU BOPE: 1. Skid rig # 76 over D-26. S! lift gas. RECEIVED JUL - 1 t991 Alaska Oil & Gas Cons. Commission Anchorage e Bleed tubing and casing pressure to production; then to flare. Fill annulus with Completion fluid {annular volume = 540 Bbls). As annulus pressures up, bleed gas to flare. e RU wireline unit. Pressure test wireline BOPE & lubricator to 2500 psi. Block in control line ~ panel. RU hand pump and pressure SCSSV CL to 3800 psi and monitor for leak off. Hand pump to be located near lower wellroom entry door. RIH with GS pulling tool and latch into WLR DKX SCSSV ~ 285'. Bleed CL pressure and POOH w/ DKX. RD Wireline unit. e RU E-Line unit. Pressure test BOPE & lubricator to 2500 psi against top master. Establish communication blackout and load guns. RIH and perforate circulation holes in tubing ~ 9,950'. POOH. Re-establish communication blackout prior to 1000' E-Line measurement. RD E-Line unit. Se RU flowlines to kill well and pressure test to 2500 psi. Circulate filtered completion fluid down tubing taking returns on backside to clear oil and gas. From this point until end of procedure, all workover fluids pumped into the well must be filtered. Monitor well for stability. NOTE: Spot a lost circulation pill only if necessary for safe well control. e RU Wireline Unit. Pressure test BOPE & Lubricator to 2500 psi. RIH w/X-line running tool w/"XR" plug dressed for XO sleeve at ~ 9963'. Set plug and POOH. Monitor for pressure build-up. RD wireline unit. Set BPV. e ND tree and send to CIW for inspection/repairs. NU BOPE and riser. Test to 250/2500 psi. Pull BPV. Be Make up joint in CIW tbg hanger 4-1/2" EUE 8rd (top) Buttress (bottom). RU wireline unit. Pressure test BOPE & lubricator. RIH w/GR pulling tool. Latch 'XR' plug, equalize, and POOH. RD Wireline unit. ge Attempt to release packer with 40,000-50,000#'s tbg weight. Pull packer free and monitor well. If packer does not come free, cut tubing and mill packer. TBU Well D-26 Workover Procedure Page 2 k 'CEIVED JUL - 1 t99t Alaska Oi~ & Gas Cons. Commission Anchorage 10. POOH and LD 4-1/2" tubing string and gas lift mandrels. Attached is a copy of handling procedures "Tubulars w/ LSA Scale". ][. RJR ~Jth bit and csg scrape~ dressed for 9-5/8", 471/f~ csg to top of lJne~ e ]0,082'. POOH. 12. Set 9-5/8" storm packer & PU BOPE. Inspect tbg spool & replace if necessary. Retrieve storm packer. 13. RIH with bit and csg scraper dressed for 7", 29#/ft csg to PBTD g 11,905'. Circulate hole clean. POOH. Pull wear bushing. 14. RU E-line and run CBT/CET including GR. Evaluate Bench 1 isolation. Cement squeeze as necessary. 15. Cement squeeze Hemlock B-3 a. RIH w/ cement retainer on E-line. Set retainer at 11,455'. POOH. RD E-1 ine. be Ce RIH w/ cement retainer on DP. Set retainer -110360'. Establish injection rate for HB-3 while monitoring annulus for flow. d. Cement squeeze HB-3. POOH. WOC 24 hours. e. RIH w/ retrievable packer to 11,000'. Set packer and pressure test annulus to 2500 psi. Release packer and POOH. f. RIH and drill out retainer and push junk to PBTD at 11,905'. Circulate hole clean by filtering completion fluid. 16. Prepare hole to run isolation packer and casing patch. RIH w/ window mill (6.059" ID), csg scraper dressed for 7", 29# and bit, circulate and filter fluid to make sure hole is clean. Work through casing from 11,380' - 11,450' four times and also through casing from 11,790' - 11,810' (isolation packer depth). POOH. 17. RU E-line. Set Baker N-1 drillable bridge plug at 11,260' DIL. RD E-line. TCP HEMLOCK B-1 18. Prior to picking up guns, a safety meeting will be held with the following personnel: Production and Drilling Foreman, Production Engineer, Operator #1, perforating specialist and helper, and all rig hands. The proposed work will be reviewed in detail, responsibilities established and safety issues discussed. The meeting will be repeated at the beginning of each shift change. TBU Well D-26 Workover Procedure Page 3 RE IVED J U L - 1 1991 Alaska Oil & Gas Cons. Commission Anchorage 19. MU & RIH slowly w/ Annulus pressure firing TCP assembly (4-1/2" guns loaded w/ 6 SPF, 45v phasing, 20.5 gram charges) on workstring. Fill string with completion fluid for a 2000 psi underbalance. Hemlock B-1 is to be perforated from 11,210'-11,243'. TCP assembly (see attached schematic) 20. RU E-line. PT lubricator to 2500 psi. RIH and correlate guns. POOH & RD E-1 ine. 21. Set packer in compression by rotating work string to the right 1/4 turn at the packer and slacking off 15K-20K. 22. RU flow control head, choke manifold and flowlines to production. Pressure test to 2000 psi. Test packer to 500 psi. 23. Pressure annulus to 1500 psi. This will shift and lock the underbalance valve open and fire the guns simultaneously. Monitor flow into drill string with a bubble bucket. Flow well for 30 minutes for clean up, then obtain a 1-hour surface PBU. 24. Pressure annulus to 2000 psi and slowly pick up weight off of packer until casing pressure drops. At this time the packer unloader will be open. Reverse out drill string with filtered 3~ KC1 to production. CBU, monitor hole. 25. PU again to release packer. Circulate w/ filtered KCl as needed. RD surface flow lines. POOH w/ TCP equipment. When guns have reached 1000', stop and conduct safety meeting. Finish POOH and LD TCP guns. Caliper guns and count shots that fired/misfired. Fracture Hemlock Bench 1 26. RIH w/ 3-1/2", S-135, 13.3#, (2.764" ID, .00742 bbl/ft cap., 24,840 psi burst 100~) uncoated, frac string, RTTS packer, multi-service valve, and MSRT LINC tool. Dope pin ends only. Fill DP w/ filtered KC1. Internally test DP to 7000 psi against multi-service valve after running lower assembly and 2 stands DP and again when at packer setting depth. Packer setting depth to be 11,080'. 27. MU D-S frac head to joint of DP that will be on top. RU to test DP joint. Hold safety meeting w/ drilling crew. Clear all personnel from rig floor. Pressure test DP joint to 5000 psi. If no leaks, bring pressure test up to 12,000 psi. Bleed off pressure. 28. MU top joint of DP and frac head to DP. Set packer above Bench i at +/- 11,080'. Pressure test frac string to 7000 psi against multi service valve. Monitor annulus pressure during test. Bleed off pressure. Pressure annulus to 1500 psi to open multi service valve. Bleed off pressure. TBU Well D-26 Workover Procedure Page 4 29. RU fracturing equipment capable of pumping 15 BPM at 12,000 psi. Secure al 1 surface 1 ines. PERFORM STEP RATE TEST AND DATA FRAC AS FOLLOWS DURING DAYLIGHT HOURS: A® Pressure test surface lines against frac head valve to 12,000 psi accourding to the following steps: ® Circulate WF140 through lines to clear air and visually check for leaks. ® Hold safety meeting w/ all personnel involved in the frac including Production Foreman and #1 Operator. Clarify job assignments and emergency procedures. One MOC employee from production will have authority to shut down fracture operations. Meeting is to include a discussion of platform conditions that would force a shutdown of frac operations once they are underway. Have in place and test method of cummunications (two-way radio and gaitronics). TBU Well D-26 Workover Procedure Page 5 Be C. De 0 . Advise all personnel to evacuate vicinity of lines to be tested. Dowel l supervisor to make walk through of area to ensure all clear. (Set up barricade as needed) Pressure lines to 5000 psi with D-S pump and monitor. One specified D-S person will walk line to visually inspect for external leaks. . When D-S "linewalker" is clear, bring pressure up to 12,000 psi and monitor. Repeat visual inspection. 6. Bleed off pressure. Repeat safety meeting and job assignments for data frac. All personnel non-essential to frac operations to remain clear of pipe racks, high pressure lines and pumping equipment. Post signs to stay clear at all access points to high pressure equipment. Apply 2000 psi to backside with rig pump. Monitor and maintain throughout steps 29 A-I and 30. For injection test, pump 100 bbls of WF140 (uncross linked gel) at 15 BPM. Shut down and record ISIP. Calculate frac gradient and estimate number of perfs open. E. Step rate - flowback. Determine fracture extension pressure upper '~ limit of closure and closure pressure using WF140 fluid. F. Rate, BPM Time, Min. Volume, Bbl 1/4 2 .5 1.0 3/4 2 1.5 I 2 2.0 2 2 4.0 4 2 8.0 6 2 12.0 8 2 16.0 10 2 20.0 15 2 30.0 95.0 After a stable pressure has been found during the 15 BPM stage, start I BPM flowback. Shut down pumps and monitor pressure during constant flowback. If necessary, repeat flowback test. Adjust flowback rate i f requi red. Calibration Test - Pump 100 bbls YF140 (surface cross linked gel) at 15 BPM. Tag fluid with 5 mci Scandium 46 (Sc 46). Flush to top perf w/ WF140. Monitor pressure to below closure pressure. Analyze pressure fall-off data for determination of leak-off. TBU Well D-26 Workover Procedure Page 6 G· To ensure DP is clear of x-link gel, pump additional 30 bbls of WF140 at 1/2 BPM. H· RU E-line. PT to 2500 psi. RIH w! LINC tool and retrieve data from MSRT. Reprogram for frac job. POOH. I · Run GR/temp log to determine extension of fractures. POOH. RD E-line. J® Analyze bottomhole pressure data and GR log. Modify frac design if required. 30. Repeat safety meeting and job assignments for frac job. Proceed w/ Bench I fracture treatment as outlined below: Monitor casing pressure closely at the start of the pumping operations to ensure there is no communication to the annulus. Maintain 2000 psi on annulus. Stage Pump Fluid Stage Prop Prop Prop Name Rate Name Fluid Conc Mesh Type BPM Vol. (gal) #1 gal PAD 15 YF140 1600 0 2 ppg 15 YF140 200 2 20/40 4 ppg 15 YF140 700 4 20/40 6 ppg 15 YF140 1200 6 20/40 8 ppg 15 YF140 gOO 8 20/40 10 ppg 15 YF140 400 10 20/40 flush 15 YF140 TBA 0 Carbo-lite mm mm II II II II II II Underdisplace treatment by 100 feet above top perf. (3.7 bbls) Job Totals: 5000 gallons YF140 and 21,600 lbs 20/40 Carbolite Gel quality and cross link as well as viscosity and pH to be checked prior to pumping. All materials and volumes to be visually inspected and all data recorded. 31. Shut down and monitor pressure for one (1) hour. Allow at least four (4) hours for fractures to heal and gels to break. Check surface samples to determine if gel is broken. 32. RU wireline. Pressure test lubricator to 2500 psi. RIH and tag sand. POOH. RD wireline - monitor well. 33. Release packer. CBU w/ 3% KCl (kill weight)· Observe well. Do not pump HEC pill (lost circulation material) unless necessary for safe well control. POOH & LD frac string. 34. RIH w/ DP and Model CP-1 plug plucker and junk basket. Clean out sand fill and drill up Model N bridge plug. Clean out casing to 11,905'. Circulate hole clean w/ filtered KC1. POOH. TBU Well D-26 Workover Procedure Page 7 NOTE: All polymer used including frac fluids will have a breaker Sand (solids) circulated out of the wellbore will have to ~e cleaned out of the surface circulating system and placed in boxes for disposal. Run Isolation Packer 35. RIH w/ 7" isolation packer - Baker Model F on DP as listed below. Packer to be set at 11,790'. a. Wireline Entry Guide 4-1/2" 12.6#, N-80 buttress modified pup jt - 10' XN nipple 3.725" No-Go 4-1/2", 12.6#, N-80 buttress modified pup jt - 6' X-over to 4-1/2" buttress Mil lout Extension Baker Model F Packer 36. Set packer at 11,790'. POOH. Run 60' Casino Patch to Cover HB-3 Perfs 37. The casing patch will arrive at location in one 60' section. The setting tool will arrive fully assembled. The patch will be set at 11,383' - 11,443' DIL. 38. PU setting tool and lift into derrick. Attach extension to polish rod coupling. PU 60' patch section and strip over extensions. Attach safety joint, solid cone, spring collet and bull plug to the bottom of the rod extension. Apply epoxy resin to patch and lower into well. TBU Well D-26 Workover Procedure Page 8 39. MU radioactive tag sub and RIH on work string at about 2000-2500 ft/hour. 40. RU E-line. PT lubricator to 2500 psi. RIH w/ GR/CCL and correlate casing patch. POOH and RD E-line. 41. Mark pipe once tool is on depth. 42. RU flow lines to 4000 psi pump. Proceed to set patch per rep. 43. When patch is set, remove surface lines. POOH w/ DP and setting tool. Run Comp 1 eti on 44. RIH w/ new 4-1/2", 12.6# L-80, Buttress Mod tubing, 4-1/2" GLM's w/ 1-1/2" valves and SCSSV on a Baker SABL-3 hydroset packer to 10,110' MD. GLM spacing will be provided by Operations Engineer on location. Set tubing hanger 2' above tubing spool. Check up and down weight of tubing string. Drop ball. Pressure tubing to 2000 psi and set packer. Close annular peventer and pressure test casing and packer to 1500 psi. Hold for 10 minutes. Bleed CP to zero. Pressure tubing to 3200 psi in 600 psi increments and shear out ball. PU to clear seal assembly from PBR. Pump completion fluid and corrosion inhibitor (corrosion inhibitor to consist of 0.5 - 0.754 volume KW132 in 34 KCl-FIW followed by -150 bbls of completion fluid. Land tbg hanger. Back out landing jt and LD. NOTE: Rabbit all joints w/ 3.83 drift. Maintain 5000 psi on SCSSV CL while RIH and during landing procedures. 4-1/2" Butt Mod tubing to be made up to mark (approx 4000 ft-lb). All field connections to be gatorhawked to 5000 psi or volume tested to 5000 psi. Baker SABL-3 Packer Assembly . 2. 3. 4. 5. 6. 7. 8. g. Wireline Entry Guide Baker Model E Hydro-trip Sub, 3-3/8" Ball 4-1/2", 12.6# L-80 Mod Buttress pup jt - 10' X nipple - 3.813" ID 1 pup jt - 4-1/2" - 6' 1 pup jt - 4-1/2" - 4' Cross-over (LTC to 4-1/2" tbg) Mi 11 out Extens i on SABL-3 packer 10. Anchor 11. 1 jr, 4-1/2", 12.6# L-80 Buttress tbg. 12. 15' (80 x 47) PBR RECEIVED dUL . 1 1991 Alaska Oil & Gas Cons. Commission Anchorage 13. 4-1/2", 12.6#, L-80 Mod Buttress Tubing and GLM's 14. 4-1/2" SCSSV w/ 10' pups on each side 15. 4-1/2", 12.6#, L-80 Mod Buttress tubing 16. Tubing hanger 45. Close SCSSV. Set BPV. ND BOPE & riser. NU new tree. Pressure test tree to 5000 psi. Pull BPV. Release rig. TBU Well D-26 Workover Procedure Page g 46. Install surface equipment. Unload well at -30 BPH. PTA to be onsite to unload well. Turn well over to production. 47. Test well to detemine post workover/frac rate and cut. 48. Obtain a production profile after production stabilizes. 4g. Evaluate placing a plug {PXN) in isolation packer (XN nipple) to shut off Bench 6. Test well. 50. Selectively reperforate Hemlock benches through tubing w/ 3-3/8" guns following tests. \docs\oe56\2g.doc Attachment # 3 MARATHON OIL COMPAN. DOLLY .VARDEN PLATFORM BOP STACK ! . Flowllne U R/~Cboragm Commission l: :1------- c,.-. co.-,,o. Pipe/~Rams. =/~~ 13 5/8' 5000 pal Double Rams Kill Line.3' BIin~ ~ Choke Line 3' 5000 Spool Pie~es Io Caslnghead 3' Howco Lo Torque 5000 pal Valve All Flanges ere 3' 5000 pal Remote AdJusltable Choke ' Pl'elaure Senior 3/4' Manual Rig Floor MANIFOLD . 3: V._.enl. L,_.ln_e i ~ . Valve Open) t Plug 3' m / 2" Blind Flange / o 6' lo Shaker CHOKE I 1/2' Manual Choke Choke Line 3' 5000 pal STATE OF ALASKA - AEASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Alter casing __ Repair well ~ -, Change approved program __ 2. Name of Operator / 5. Type of Well: Development X..~_ UNOCAL V(Marathon Oil Co~ Sub Opera):or) Exploratory __ 3. Address ! Stratigraphic_ P. 0. Box 190247 Anchorage, AK 995~.9 -? i SerVice__ 4. Location of well at surface Leg A-! Con(l. ~/ Mol ly. Varden Plattorm 751' FSL, 1,215' F14L, Sec. 5- 8N- 1314- SM At top of productive interval 663' FNL, 296' F14L, Sec. 5 - 8N - 1314 - SM At effective depth Operation shutdown ~ Re-enter suspended well ~ Plugging ~ Time extension __ Stir~ulate ~ Pulltubing ~ Variance__ Perforate X . - Other At total depth 499' FNL, 730' FWL, Sec. 5 - 8N - 13W - SM 6. Datum elevation (DF or KB) 106' KB above HSL 7. Unit or Property name Trading Bay Unit 8. Well number D-26 '/ 9. Permit number 74-9 10. APl number 50-733-20260 11. Field/Pool Hemlock 12, Present well condition summary Total depth: measured true vertical 11,969 ' feet Plugs (measured) 9,885' feet Sand Plug g 11,791' Effective depth: measured 11,905 ' feet Junk (measured) true vertical 9,836' feet Casing Length Size,~ Structural .Conductor Sudace 3,306' 13-3/8" 2,750 sx Intermediate 10,239' 9-5/8" 2,690 sx Production ~-~ Liner lu ~..~ ~, D" Perforation depth: moas true vertical _ - Tubing (size, grade, and measuCed d~ None Measured depth 3,306' 10,239' 650 sx 11,952' 11,213' - 11,243' MD 11_,.2Z3' -~!~06' MD 11,468' - 11,608' MD 11,642' - 11,732' MD B-6 11,828' - 11,858' MD True vertical depth 3,148' 8,501' 9,877' 9,285' - 9,310' TVD 9,335' - 9,363' TVD 9,496' - 9,606' TVD 9,632' - 9,702' TVD 9,778' - 9,802' TVD 4-1/2". 12.6# N-80 SL tbg to 10,045' Packers ano SSSV (type and measured ~epth) II ! · Bake_,- FH PI~Y. a.n Tn ca 1Il Ar)q~ , nt{: gv +... nE 13. A~achments 1,- 2- ~ De~crip{i6n ~u~6~r~ ~Fprop~s~i'~ -- -6eqa]le2Jp6rat,~ program __ 14. Estimated date for commencing operation ~15. Status of well classification as: February [99~ 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby cedi~ that the foregoing is true and correct to the best of my kn~ledge. -- O ' FOR COMMISSION US~NLY Conditions of~proval: Notify Collision so re~esentative may witness BOP sketch Gas Suspended __ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- .4/-~ ~ Approved Copy Original Signed 0'-,, Returned Approved by order ofthe Commis~d~vid W, johnst~:;,~ ~.-I~-c~ | - Commissioner feet Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE . . . 0 Attachment # I D-26 PROCEDURE Obtain a 24-hour well test. RU WL unit. Hook up PA system in unit. Pressure test lubricator to 2500 psi. Hook up 2-pen recorder to well. SI 1 ift gas and manumatic. RIH w/ 4-1/2" pulling tool dressed to pull WLR DKX SCSSV. Latch valve and POOH. RIH w/ 2.5" gauge ring, tag fill. POOH. RD wireline unit. RU E-line unit. Hook up communication system in unit. MU 2-1/8" strip guns. Pressure test lubricator to 2500 psi. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify logistic support and establish a communications blackout. Re-establish the communications blackout Sen guns are at 1000' when POOH. RIH with 2-1/8" strip guns, 4 SPF, 0° phasing offset 30o and perforate the following intervals underbalanced (well flowing). POOH. Run Bench Interval DIL I 1 11,213' - 11,246' Test well for 24 hours following cleanup. 2 2 11,273' - 11,306' g. Footaqe 33' 33' NOTE: Bench 2 may not be perforated if an incremental 100 BOPD is achieved from HB-1 reperf. RD E-line. Return well to production and obtain a minimum of two well tests. 10. SI for 12 hours. RU wireline unit, hook up PA system in unit. Pressure test lubricator to 2500 psi. 11. RIH w/ tandem Amerada 5000 psi element pressure/temp (O-200°F) gauges, two 24-hour clocks. Make 1/2-hour stops at 10,000' MD and 10,500' MD and a two-hour stop at 11,411' MD. POOH w/ gauges. 12. RIH and set WLR-SCSSV. POOH. Test WLR SCSSV. RD wireline. Return well to production. NOTE:- Maximum Anticipated SBHP : 4208 psi (6/2/g0) \docs\oe55\22. doc RECE)VED FEB 281991 AlaSka Qjl .& Gas Cons. Attachment #3 ~OLLY VARDEN PLATFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) -------- LUBRICATOR -4'~1JJ.6-'-, 5000 psi CHISTMAS TREE --- POSITIVE CHOKE --.-- 2' 5000 psi __ 2' 3000 psi , · 13 3/8' CASING Attachment #2 MARATHON OIL COMPANY TRADING BAY UNIT ~/ELL ]]-26 Compie-ted 6/74 Alt me~sur'ements ~r'e RKB to '~op ot= equipment. 41' CI~ 4.5' Tb9 H:nger ~98' Dtls VLR ~V Type DKX. 3.813' I9 Through Nipple ~.0' ID Thpough V~lve. ComDte~lqn St~in~ 0'-10,045' 4.5' l~.6fl, N-BO gL. G~s llF~ m~ndre[s ~re 4.0' U~I C~F', McMurray type M-gV3D-LP v<~[ve$. 9-5/8' 40. 43.~ 47~, N-BO & P-IlO ~61~' #1 ~4/64 Port ~678' #~ ' 406~' #3 501~' #4 5857' #5 6511' #6 7001' #7 7463' #8 79~0' #9 8340' #10 ' 8718' #11 9110' #12 9505' #13 989P' #14 24/64 Pots 'TOL 7' ~ 10,082' 9-5/8' Csg ~ 10,239' -. 7' Eg# N-80 X-tine 9963' 10,003' 10,045' Otis XO Sleeve 3.813' ID B~ker FH Pocker 4.0' ID Boker Sheor Sub 4.0' ID B-I B-4 B-5 per,ore,Ions ~-1 11,~13'-~43' 4 SPF O' Ph~slng 9/81 )~-~ 11,~73'-306' 4 SPF ' 9/81 3-4 11,468'-608' 4 SPF ' 9/81 ]~-3 11,390'-435' 4 SPF ' 11/89 ]~-5 11,64~'-73~' 3 SPF ° 8/79 ]i-6 11,8~6'-858' 3 SPF ° 6/74 ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter Casing m Repair well __ Change approved program __ Name of Operator ! 5. Type of Well: 2. · Development UNOCAL (Marathon 0~1 Co - Sub Operalor) Exploratory 3. Address | Stratigraphic P. O. Box 190247 Anchorage, AK 995]9 Servicem 4. Location of well at surface Leg A-1 Cond. #7 bo1 ly varden vla~form 751' FSL, 1,215' FWL, Sec. 5- 8N- 13W- SM At top of productive interval 663' FNL, 296' FWL, Sec. 5- 8N- 13W- SM At effective depth Operation shutdown m Re-enter suspended well __ Plugging ~ Time extension __ Stimulate ~ Pull tubing ~ Variance __ Perforate ..,Y,_ Other At total depth 499' FNL, 730' FWL, Sec. 5 - 8N - 13W - SH 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-26 9. Permit number 74-9 10. APl number 50-733-20260 11. Field/Pool Hemlock feet 12. Present well condition summary Total depth: meas'ured true vertical 11,969' feet 9,885' feet Plugs (measured) Sand Plug (~ 11,791' Effective depth: . measured 11,905' true vertical 9,836 ' Casing Length Size Structural Conductor Surface 3,306' 13-3/8" Intermediate 10,239' 9-5/8" Production Liner 1,870' 7" Perforation depth: measured feet feet true vertical Tubing (size, grade, and measured depth) Junk (measured) Cemented 2,750 sx 2,690 sx 650 sx None Measured depth True vertical depth 3,306' 3,148' 10,239' 8,501' 11,952' 9,877' B-1 11,213' - 11,243' MD 9,285' - 9,310' TVD B-2 11,273' - 11,306' MD 9,335' - 9,363' TVD B-4 11,468' - 11,608' MD 9,496' - 9,606' TVD B-5 11,642' - 11,732' MD 9,632' - 9,702' TVD B-6 11,828' - 11,858' MD 9,778' - 9,802' TVD 4-1/2" 12.6# N-80 SL tbg to 10,045' Packers and SSSV (type and measured depth) Baker FH Pkr 4.0" ID 0 10.(1(1~': r)tis RV f. vn~. nK (a ?qR' 13. Attachments 1 & 2 Description summ~ry of pt:oposal ~X "D'etailed operations program 15. Status of well classification as: 14. Estimated date for commencing operation September 15, 1990 Date approved 16. If proposal was verbally approved Name of approver BOP sketch REEEiVED i Oil x__ Gas__ suspende,~l~'G ) 0 1990 Service .'.,';,~t;~ ~:: ,t, ~.~ I~nn~ i~o~[SS[0It 17. I hereby c/e~ify that the foregoing is true and correct to the best of m'. fknowledge. Signed[ ~\ ._'~_~_,. ~.~. '~----~,..,,~k,~ Title ~,,e.~,~.-,,,,~' ~;,(~,~% ~-- ~ FOR COM~SION USE ONLY Conditions o~ a~oval~otify Commission so representative may witness Plug ~ntegrity __ BOP Test ~ Location clearance ~ ~. & Mechanical Integri~ Test __ Subsequent form required 10- ~' Approved by order of the Commission Date ~ - .2,.8, - ~ o I Approval N o'c:~).._ / ¢ - Approved ORIGINAL ~IGNED I~'f Retqrnea LONNIE P, RMITH ...,)~ I["~'~ L,;omml$$1orl~r Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment //1 TBU Well D-26 Setting Through Tubing Bridge Plug Procedure 2~ 3~ Be g e Be 9~ Place well in test and install two pen recorder to monitor tubing and casing pressure. SI well after obtaining 24-hour test. Disconnect SCSSV from system manifold and lock open SCSSV at 4000 psi with a hand pump. Hand pump should be located near well room entry door. Monitor control line pressure to ensure no bleed off occurs. Correct if required. RU WL unit. RU platform PA in WL unit. Pressure test BOPE and lubricator to 2500 psi. RIH with DKX pulling tool and latch into DKX. Bleed control line pressure and shut in needle valve on pump. POOH with DKX. RIH with 3.7" GR to tbg tail 0 10,045' POOH. Flow well to clean up debris. RIH with 3.8" to at least 657~'. POOH. Flow well for clean up. RD WL unit. RU E-line unit. RU platform PA in E-line unit. Pressure test BOPE and lubricator to 2500 psi. RIH with through tubing expendable bridge plug and plug setting assembly to 11,820' DIL. New PBTD will be 11,810' DIL. Depth to be correlated with CCL. NOTE: Position of upper slips will not change during setting operation. Monitor SITP until less than 20 psig/hour increase is observed on tubing. Set plug (approximately 35 minutes) and POOH. RIH with cement bailer. Tag top of plug. Position bailer and dump cement. POOH. Repeat bailer runs until a minimum of 10' of cement has been dumped on plug. In 7", 29// casing, 116' of 2-1/8" OD bailer is required. WOC 48 hours. Flow well in test obtaining WC every 4 to 6 hours. Rate & WC to be evaluated prior to reperforating. If the decision is made to not reperf, RD E-line unit and skip to step //14. REEEIVED AU G 0 1990 Alaska.Oil & G~s Cons. Gomm.~ss~o~ TBU Well D-26 Setting Through Tubing Bridge Plug Procedure Page 2 10. RIH with 2-1/8" Enerjet III strip guns, 4 SPF, 0° phasing and perforate the following intervals. All runs to be perforated with well flowing. Open choke and flow well to create drawdown prior to perforating. Following each perf run, flow well for 30 minutes to clean up perf debris. Monitor production separator for problems due to perf debris. If production is unstable, SI well prior to RIH & POOH. RUN BENCH DEPTH FOOTAGE i HB-4 11,573' - 11,608' 35 2 HB-4 11,538' - 11,573' 35 3 HB-4 11,503' - 11,538' 35 4 HB-4 11,468' - 11,503' 35 5 HB-1 11,213' - 11,243' 30 11. Flow well to test separator 12-18 hours to clean up perf debris· Test well in separator #2 for 48 hours, obtaining WC's every 4-6 hours. 12. Evaluate rate & WC. Determine if GLM pack off is required If not RD E-line unit and skip to step #14. ' ' PROPOSED TOOL STRING: GLM PACK-OFF A) Head, CCL, Setting Tool, Pack-off B) Approximate Length.. 25' C) Approximate Weight: 150# D) Max OD: 3.75" 13. SI well. RIH Merla tubing patch to GLM #6 (6,511' MD). Tie in on depth with CCL to GLM's. Position patch to straddle GLM #6 and set tubing patch. POOH. RD E-line unit. NOTE: MERLA TBG PATCH OD : 3 75" ID = 3 25" · , · · 14. RU WL unit. Redress DKX. RU platform PA in WL unit. Pressure test BOPE & lubricator to 2500 psi. SI well. RIH with DKX and set in profile. Shear off and POOH. Monitor control line pressure for an hour to ensure valve is open and holding pressure. RD WL unit. 15. Flow well in test for 24 hours obtaining water cuts ever 4-6 hours Turn well to production. · \ docs \ oe51\ 63. doc RECEIVED AU G ~) 0 1990 Alaska Oil & Gas Cons. Commission N~chorage Attachment -JOLLY VARDEN PL..'TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP - GREASE HEAD (Hydraulically Activated) LUBRICATOR · 4'~1/~;6~.5000 ps1 C"ISTMAS TREE POSITIVE CHOKE RECEIVE.i) AUG Alaska Oil & Gas Cons. Anchorage 2' 5000 psi _-- 2" 3000 psi 13 3/8' CASING - - STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ ,., - Pull tubing __ Variance m Perforate __ Other 5_.~.6 T, S C S S V 1. Type of Request: Abandon __ Suspend __ Alter Casing __ Repair well m Change approved program __ 2. Name of Operator ~ 5. Type of Weil: · Development UNOCAL (Marathon 011 Co - Sub Oper..al~or) ExPloratory__-- 3. Address | Stratigraphic m / P. 0. Box 190247 Anchor_a. ge, AK 995],9 Service__ 4. Location of well at surface Leg A-I ~Jond. ~/ uolly varaen Platform 751' FSL, 1,215' FWL, Sec. 5- 8N- 13W- SN At top of productive interval 663' FNL, 296' FWL, Sec. 5- 8N- 13W- SM At effective depth APPLICATION FOR SUNDRY APPROVALS 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number ,D-26 9. Permit number 74-9 At total depth 499' FNL, 730' FWL, Sec. 5 -8N - 13W - SM 11,969 ' feet Plugs (measured) 9,885' feet feet 12. Present well condition summary Total depth: meas'ured true vertical measured 11,905 ' feet Junk (measured) true vertical 9,836 ' feet Effective depth: 10. APl number $0-733-20260 11. Field/Pool ' Heml DC k Casing Length Size Cemented Structural Conductor Sand Surface 3,306' 13-3/8" 2,750 sx Intermediate 10,239' 9-5/8" 2,690 sx Production Liner 1,870' 7" 650 sx Perforation depth: measured true vertical None ,~...~ska 0il & Gas C0ns,Commissi0 Measured depth ' 'Tr, .v~..rtj.c_az. aep[n' 3,306' 3,148' 10,239' 8,501' 11,952' 9,877' Tubing (size, grade, and measured depth) 4-1/2" 12.6# N-80 SL tbg to 10,045' Packers and SSSV (type and measured depth) Ral~r FI-I Pier 4_13" Tr) O 113 1313~'~ Ati~ RV fvrm. r)K la 2qB' 13. Attachments' 1 & 2 Description summ~ry of proposal ~ bbtailed operations program 14. Estimated date for commencing operation 6/25/90 16. If proposal was verbally approved Date approved B-1 11,213' - 11,243' MD 9,285' - 9,310' TVD B-2 11,273' - 11,306' MD 9,335' - 9,363' TVD B-4 11,468' - 11,608' MD 9,496' - 9,606' TVD B-5 11,642' - 11,732' MD 9,632' - 9,702' TVD B-6 11,828' - 11,858' MD 9,778' - 9,802' TVD Name of approver BOP sketch X_._ 15. Status of well classification as: Oil X__ Gas __ Suspended __ Service Date 17. I hereby ~ify that the foregoing is true and correct to the best of ~my knowledge. Signed ~__~ S. ~ ,,,~ Title ~,,~,%~ o-,~,.~ "~,~ t, % ~ ~ FOR COM~ION USE ONLY Conditions of a~rova~otify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~'" ?~ Approved by order of the Commission Annr~it~er,. · 'Returned ' I Approval No. ~O- Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH SUBMIT IN TRIPLICATE Attachment #1 · e · TBU Well D-26 SCSSV Setting Procedure Flow well & establish steady production. SI lift gas & close masters. RU BOP & riser. Pressure test riser to 2500 psi. Open masters & re-establish production. RIH with scratchers and clean scale & deposits to depth of the SCSSV. Flow well to remove debris. POOH. SI lift gas. RIH with SCSSV & set. POOH. RD BOP & riser. Re-establish production. Note: Maximum anticipated SBHP is 4200 psi. docs\dvp\d26, doc Oil & Gas Cons. rjorn~-aissior~ Anchora~ Attachment #2 ~,JOLLY VARDEN P£ ~TFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED '"' BOP .,, GREASE HEAD (Hydraulically Activated) BRICAT -' OR ,, 4' :1/~,"6'"-. '5000 pal CHISTMAS TREE POSITIVE CHOKE ---- 2' 5000 pal ._- 2' 3000 pal 13 3/8' CASING DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6, TSN, R13W CONDUCTOR LEG #A-1: LAT: 60°48' 28.272" LONG :151°37' 57.620" "Y" COORD. ,. "X" COORD. WELL # FSL _ 2,490,836.22 FWL 1 2 3 4 5 6 7 8 9 10 ll 12 208,461.20 757.5~ 1212 0 LEG #A-2' 1 2 3 4 5 6 7 8 9 l0 ll 12 LEG ,B-I' LAT = 60°48' 27.485" LONG =151°37' 57.564" 2,490,836.95 208,454.55 D-27 758.1 2,490,840.99 208,456.66 D-28 .762.1 2,490,842.79 208,460.79 D-29 764.0 2,490,841.51 208,465.11' D-32 762.9 .2,490,837.76 208,467.60 D-40 759.2 2,490,833.28. 208,467.10 D-41 754.7 2,490,830.18 208,463.83 D-26 751.5 2,490,829.90 208,459.34 D-25 & RD 751'.1 2,490,832.58 208,455.72 753.7 2,490,835.56 208,458.66 D-24 & 34A 756.8 2,490,838.66 208,462.17 D-31 & RD 760.0 2,490,834.00 208,462.61 D-24A 755.3 2,490,835.42 208,381.20 754.7 2,490,836.16 208,374.66 D-1 755.3 2,490,840.19 208,376.67 ' D-17 759.4 2,490,842.00 208,380.80 D-11 761.3. 2,490,840.72 208,385.11 D-7 & RD 760.1 2,490,836.97 208,387.60 D-9 756.4 2,490,832.49 208,387.10 D-19 751.9 2,490,829.39 208,383.84 D-23 748.8 2,490,829.11 208,379.34 D-21 748.4 2,490,831.78 208,375.72 ' D-5 & RD 750.9 2,490,834.77 208,378.66 D-15 & RD.& 2 754.0 2,490,837.86 208,382 17 D-3 & RD 757.2 2,490,833.21 208,382.61 D-13 752'.5 1 2 3 4' 5 6 7 8 9 l0 ll 12 LEG #B-2: 2,490,756.22 208,462.00 " 677.5 2,490,755.48 208,468.53 D-8 & RD 677.0 2,490,751.45 208,466.53 D-6 672.9 2,490,749.65 208,462.40 D-14 & RD 671.0 2,490,750.92 208,458.08 D-20 672.1 2,490,754.67 208,455.59 D-16 675.8 2,490,759.15 208,456.10 D-22 680.3 2,490,762.25 208,459.36 D-2 & A & RD 683.5 2,490,762.53 208,463.85 D-4 683.9 2,490,759.86 208,467.48 D-10 681~ 3 2,490,756.87 208,464.53 D-12 & RD 678.3 .2,490,753.78 208,461.02 D-18 675.1 2,490,758.43 208,460.58 D-30 & RD 679.7 2,490,755.43 208,382.00 674.8 (Reserved for Compressors.) 1205.5 1207.4 1211.5 1215.8 1218.4 1218.0 1'214.8 1210.3 1206.7 1209.5 1213.0 1213.5 1132.1 1125.5 1127.4 1131.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1221.4 121'9.5 12i5.4 1211.1 1208.5 1208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 Unocal North AmeHc Oil & Gas Division ~. Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear MS. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-oPerated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet Your needs. Yours very truly, Ga% S .~~us~h' Regional Drilling Manager GSB/lew STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~odlON REPORT OF SUNDRY WELL OPERATIONS 1, Operations performed: Operation shutdown __ Stimulate __ Plugging Pull tubing __ Alter casing ~ Repair well __ 2. Name of Operator ! 5. Type of Well: - ,[ , Development X UNOCAl. (Marathon Oil Company- Sub speraT-orlJxploratory__ 3. Address P. O. Box 190247 Anchorage~ AK 4. Location of well at surface Leg A-1 Cond. #7 Stratigraphic 995 9 Service ~ Dolly Varden Platform Perforate X Other 6. Datum elevation (DF or KB) ]06' KB above MSI 7. Unit or Property name Tradin,,q Bay Unit 8. Well number 751' FSL, 1,215' FWL, Sec. 5- 8N- 13W- SM At top of productive interval 663' FNL, 296' FWL, Sec. 5- 8N- 13W- SM At effective depth At total depth 499' FNL, 730' FWL, Sec. 5- 8N- 13W- SM D-26 9. Permit number/approval number 9-444 10. APl number S0--733 - 20260 11. Field/Pool Hemlock feet 12. Present well condition sUmmary Total depth: measured true vertical 11,969' 9,885' Effective depth: measured 11,905' true vertical 9,836 ' Casing Length Structural Conductor Surface 3,306' Intermediate 10,239 ' Production Liner 1,870' Perforation depth: measured Size 13-3/8" 9-5/8" 7" feet feet feet feet Plugs (measured) Junk (measured) Cemented 2,750 sx 2,690 sx 650 sx Sand P1 ug @ 11,791' None Measured depth True vertical depth 3,306' 3,148' 10,239' 8,501' 11,952' 9,877' true vertical See Tubing (size, grade, and measured depth) 4-1/2" 12.6# N-80 SL tbg to 10,045' Packers and SSSV (type and measured depth) Baker FH Pkr 4.0" ID @ 10,003': Otis 13. Stimulation or cement squeeze summary Intervals treated (measured) Attachment #1 BV tvDe DK @ 298' - . Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11/19/89 250 82 1717 1100 160 Subsequent to operation 12/4/89 329 194 3098 1160 170 15. Attachments 2 Copies of Logs and Surveys run __ Daily Report of Well Operations _,Y, 16. Status of well classification as: Oil .Z,_ Gas_ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_~.L¢~'~X._.~--~E_.~O'V,'?_,"'~'~{~'~OTitIe Environmental Analyst Form 10-404 Rev 06/15/88 [/ ) - ' 1/12/90 Date SUBMIT IN DUPLICATE Attachment #1 TBU Well D-26 Perforation Intervals B-1 B-2 B-3 B-3 B-4 B-5 B-6 11,213' - 11,243' MD 11,273' - 11,306' MD 11,390' - 11,410' MD 11,410' - 11,435' MD 11,468' - 11,608' MD 11,642' - 11,732' MD 11,828' - 11,858' MD 9,285' - 9,310' TVD 9,335' - 9,363' TVD 9,432' - 9,449' TVD 9,449' - 9,469' TVD 9,496' - 9,606' TVD 9,632' - 9,702' TVD 9,778' - 9,802' TVD ~docs\DVP\D26. doc Attachment #2 TBU Well D-26 Summary of Daily Well Operations 11/26/89 RU E-line and ~T lub to 2500 psi. Good test RIH w/ 25' of 2-1/8" JRC strip guns, 4 SPF, 0v phasing, 20.7 gm charges w/ ~ell SI. Flow well, correlate, and tag fill at 11,853' DIL. PU and perforate 11,410' - 11,435' (25' B-3). Flow well for 10 min. SI. POH. All shots fired. MU 20' guns as above. SI well. RIH out tubing tail. Flow well, correlate. PU and perforate 11,390' - 11,410' (20' B-3). Flow well for 20 min. SI. POH. All shots fired, RD. Well on line. \docs\DVP\D26. doc STATE OF ALASKA -~ 0 R I G IN ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging ~ Time extension __ Stimulate __ Change approved program ~ Pull tubing ~ Variance ~ Perforate X~ Other 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon Oil Company - Sub (}perato~ve~.°Pm.entx / ~xp~oratory __ 3. Address / Stratigraphic_ P. 0. Box 190247. An?h~or~age,, A,K,., ,99,5]9 .. , 2~er_vi~ce,.__.z___ 4. Location of well at surface g~y /-t-1 t,,UIIU. 'ltl UUIly V(:I.['U~II rlal.,iuiIII 751' FSL, 1,215' FWL, Sec. 5- 8N- 13W- SM At top of productive interval 663' FNL, 296' FWL, Sec. 5- 8N- 13W- SM At effective depth Att°t~dgepthFNL, 730' FWL, Sec. 5-8N- 13W- SM 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-26 9. Permit number 74-9 10. APl number 50-7-33-20260 Fic. ld/P. ool ~mlocl~ 12. Present well condition summary Total depth: measured true vertical 11,969 ' feet Plugs (measured) 9,885' feet Effective depth: measured 11,905 ' feet Junk (measured) true vertical 9,836 ' feet Casing Length Size Cemented Structural Conductor Surface 3,306' 13-3/8" 2,750 Intermediate 10,239' 9-5/8" 2,690 Production Liner 1,870' 7" 650 Perforation depth:measured B- 1 11,213 ' B-2 11,273' true vertical B-4 11,468' B-5 11,642' 8-6 11,828' Sand Plug Ia 11,817' RECEIVED None OCT 2 7 Measured deleska f]ij& Anchorage sx 3,306' 3,148' sx 10,239' 8,501' SX 11,952' 9,877' - 11,243' MD - 11,306' MD - 11,608' MD - 11,732' MD - 11,858' MD Tubing (size, grade, and measured depth) 4-1/2" 12.6# N-80 SL tbg to 10,045' Packers and SSSV (type and measured depth) Baker FH Pkr 4.0" ID @ 10,003'; Otis BV type DK ~ 298' 13. Attachments 1 & 2 Description summary of proposal X__ Detailed operations program ~ 9,285' - 9,310' TVD 9,335' - 9,363' TVD 9,496' - 9,606' TVD 9,632' - 9,702' TVD 9,778' - 9,802' TVD BOP sketch 14. Estimated date for commencing operation October 30, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil _& Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~&~/'"~./~¢.~¢¢.~. j~::~Title Environmental Engineer /,4~5 ~6R COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- 90~ Original Signed By ApprOved by order of the CommissiE~ravid W. Johnston Date 10/26/89 Approved 0o9¥_ · Returned Commissioner lAppr°val N°. ¢_ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Well D-26 Procedure 1. RU wireline unit, PT to 2500 psig. RIH with 4-1/2" GS pulling tool and retrieve DKX safety valve at 298'. 2. RIH w/ 2-1/2" GR. Work through tight spot at top of liner and tag bottom. RIH with 30', 2" OD bailer to 11,500' (to ensure that 2-1/8" guns can get down to 11,450'). POOH, RD wireline. 3. RU E-line and PT to 2500 psig. 4. With well shut-in, RIH with 2-1/8", 0° phased, 4 SPF expendable carrier gun. Once on bottom, flow well to establish an underbalance. Perforate Bench 3 over the intervals listed below, shut in well prior to POOH to avoid getting blown up hole. 5~ BENCH 3 RD E-1 ine. Note: INTERVAL FOOTAGE 11,385' - 11,435' 50' Maximum anticipated SBHP is 3000 psi. docs\dvp\d26, doc Attachment #2 ~OLLY VARDEN P~L~TFORM Wireline Lubricator w/Associated BOPE · GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP CHISTMAS TREE --- POSITIVE CHOKE ----- 2' 5000 2' 3000 psi 13 3/8' CASING STATE OF ALASKA .."-',~ ALASF~ OIL AND GAS CONSERVATION COMN. SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-1 Cond. ~/ Dolly Yarden E±attor~ 751' FSL, 1,215' FWL, Sec. 5 - 8N - 13W- SM At top of productive interval 663' FNL, 296' FWL, Sec. 5- 8N- 13W- SM At effective depth At total depth 499' FNL, 730' FWL, Sec. 5 - 8N- 13W- SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-26 8. Approval number 8-278 9. APl number 50-- 733-20260 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 11,969 ' feet 9,885 ' feet Plugs (measured) Sand Plug @ 11,791' Feet Effective depth: measured 11,905 ' true vertical 9,836' feet feet Junk (measured) None Casing Length Size Structural Cemented Measured depth True Vertical depth Conductor Surface 3,306' 13-3/8" Intermediate 10,239 ' 9-5/8" Production Liner 1,870 ' 7" Perforation depth: measured B-1 true vertical B-2 B-4 B-5 Tubing (size, grade and measured depth) B-6 4-1/2" 12.6~f N-80 SL tbg to 10,045' Packers and SSSV (type and measured depth) Baker FH Pkr 4.0" ID @ 10,003' 2,750 sx 3,306' 3,148' 2,690 sx 10,239' 8,501' 650 sx 11,952' 9,877' 11,213' - 11,243' MD 9,285' - 9,310' TVD 11,273' - 11,306' MD 9,335' - 9,363' TVD 11,468' - 11,608' MD 9,496' - 9,606' TVD 11,642' - 11,732' MD 9,632' - 9,702' TVD 11,828' - 11,858' MD 9,778' - 9,802' TVD ; Otis BV type DK @ 298' 12. Stimulation or cement squeeze summary Intervals treated (measured) 13. Treatment description including volumes used and final pressure ,¢~,;(:!:~.~:,. , , _ : : .~;;i,'t Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 490 773 1958 1140 psi 120 psi Subsequent to operation 413 548 1611 1110 psi 400 psi 14. Attachments 1 & 2 Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ Title Environmental Enqineer Form 10-404 Rev. 12,1~_,-R~i;7 13.)RoDerts Date 5//'23/88 Submit in Duplicate Attachment #1 TBU Well D-26 Summary of Daily Well Operations 4/21/88 RU CTU injector head and lubricator, fill CT w/FIW and PT to 4000 psi, O.K. RIH w/CT w/cementing nozzle and tag fill @ 11,818' CTM (11,839' WLM). Hydrate GW-21 polymer in methanol and mix w/FIW and 3% KC1. Add silica flour, 100 mesh sand, 20-40 sand and 12-20 sand. Begin pumping 23 bbls of slurry @ 1 bbl/min between 2700-3000 psi. After 15 bbls displaced, PU CT @ 10'/min. Displace slurry w/17 bbls FIW. PU CT to 11,000' and wait for sand to settle. RIH and tag sand plug @ 11,769' CTM (11,790' WLM), 49' of sand plug, 36' of sand above B-6. POH w/CT and RD. RU slickline and RIH w/2.50 gauge ring to 11,791' WLM and tag sand plug. POH, RD. NEF/em/71/Sundr4 TBU Well D-26 Completion Schematic 2/7/83 Attachment # 2 41' CIW 4-1/2" Tubing hanger 4-1/2" 12.6# N-80 SL 9-5/8" 40, 43.5, 47# N-80 & P-il0 Buttress Casing 298' Otis wireline retrievable ball valve - Type DK 3.813" ID through nipple 2.000" ID through valve 2612' GLV #1 2678' GLV #2 USI C2F Mandrels, McMurray type M-DSVO-LP Valves, Mandrels 4.00" 4062' GLV #3 5012' GLV #4 5857' GLV #5 6511' GLV #6 7001' GLV #7 7463' GLV #8 7920' GLV #9 8340' GLV #10 8718' GLV #11 9110' GLV #12 9505' GLV #13 9892' GLV #14 9963' Otis XO Sleeve 3.813" ID 10,003' Baker FH Packer 4.000" ID 10,045' Baker Shear Sub 4.000" ID .Top of Liner 10,082' 10,239' Perforations (DIL) 11,213' - 11,243' Bench 1 7" 29# N-80 X-line 11,273' - 11306' Bench 2 11,468' - 11,608' Bench 4 11,642' - 11,732' Bench 5 Tagged Fill @ 11,850' 10/27/81 '11,791' - Top of Sand Plug 4/88 11,828' - 11,.858' Bench 6 11,905' PBTD 11,969' TD NEF.5/9/88 STATE OF ALASKA ALASF""'DIL AND GAS CONSERVATION OOMI~ION REPORT SUNDRY..W£LL OPERATIONS !. Operations performed: .. Operation shutdown [] Alter CaSing [] Other [] Stimulate [] Plugging [] Perforate [] Pull tubing [] · 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-I Cond. #7 Dolly Varden t'JLattori: 751' FSL, 1,215' FWL, Sec. 5 -8N- 13W- SM At top of productive interval 663' FNL, 296' FWL, Sec. 5 - 8N- 13W- SM At effective depth At total depth 499' FNL, 730' FWL, Sec. 5 - 8N- 13W- SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-26 8. Approval number 8-278 9. APl number 50-- 733-20260 10. Pool Hemlock Feet 11. Present well condition summary Total depth: measured true vertical 11,969 ' feet 9,885' feet Plugs (measured) Sand Plug @ 11,791' Effective depth: measured 11,905 ' true vertical 9,836' feet feet Casing Length 'Structural Conductor Surface 3,306' Intermediate 10,239 ' Production Liner 1,870 ' Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Junk (measured) None Cemented Measured depth 13-3/8" 2,750 sx 3,306' 9-5/8" 2,690 sx 10,239' 7" 650 sx 11,952' 4-1/2" 12.6# N-80 SL tbg to 10,045' True Vertical depth 3,148' 8,501' 9,877' B-1 11,213' - 11,243' MD 9,285' - 9,310, TVD B-2 11,273' - 11,306' MD 9,335' - 9,363' TVD B-4 11,468' - 11,608' MD 9,496' - 9,606' TVD B-5 11,642' - 11,732' MD 9,632' - 9,702' TVD B-6 11,828' - 11,858' MD 9,778' - 9,802' TVD Packers and SSSV(type and measured depth) Baker FH Pkr 4.0" ID @ 10,003'; Otis BV tyPe DK @ 298' 12. Stimulation or cement squeeze summary Intervals treated (measured) Oa ~ ~ ~ ........ ~ Treatment description including volumes used and final pressure .i 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 490 773 1958 1140 psi 120 psi Subsequent to operation 413 548 1611 1110 psi 400 psi 14. Attachments 1 & 2 Daily Report of Well Operations PA Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~m,~._.~ Title Environmental Enqineer Form 10404 Rev ~~ ~R°'bertS Date 5/23/88_ Submit in Duplicate Attachment #1 TBU Well D-26 Summary of Daily Well Operations 4/21/88 RU CTU injector head and lubricator, fill CT w/FIW and PT to 4000 psi, O.K. RIH w/CT w/cementing nozzle and tag fill @ 11,818' CTM (11,839' WLM). Hydrate GW-21 polymer in methanol and mix w/FIW and 3% KC1. Add silica flour, 100 mesh sand, 20-40 sand and 12-20 sand. Begin pumping 23 bbls of slurry @ 1 bbl/min between 2700-3000 psi. After 15 bbls displaced, PU CT @ 10'/min. Displace slurry w/17 bbls FIW. PU CT to 11,000' and wait for sand to settle. RIH and tag sand plug @ 11,769' CTM (11,790' WLM), 49' of sand plug, 36' of sand above B-6. POH w/CT and RD. RU slickline and RIH w/2.50 gauge ring to 11,791' WLM and tag sand plug. POH, RD. NEF/em/71/Sundr4 TBU Well D-26 . Completion Schematic 2/7/83 Attachment ~! 2 41' CIW 4-1/2" Tubing hanger 4-1/2" 12.6# N-80 SL 9-5/8" 40, 43.5, 47# N-80 & P-110 Buttress Casing 298' Otis wireline retrievable ball valve - Type DK 3.813" ID through nipple 2.000" ID through valve 2612' GLV #1 2678' GLV #2 USI C2F Mandrels, McMurray type M-DSVO-LP Valves, Mandrels 4.00" 4062' GLV #3 5012' GLV #4 5857' GLV #5 6511' GLV #6 7001' GLV #7 7463' GLV #8 7920' GLV #9 8340' GLV #10 8718'. GLV #11 9110' GLV #12 9505' GLV #13 9892' GLV #14 9963' Otis XO Sleeve 3.813" ID 10,003' Baker FH Packer 4.000" ID .Top of Liner 10,082' 10,239' 7" 29# N-80 X-line Tagged Fill @ 11,850' 10/27/81 10,045' Baker Shear Sub 4.000" ID Perforations (DIL) 11,213' - 11,243' Bench 1 11,273' - 11306' Bench 2 .. 11,468' - 11,608' Bench 4 11,642' - 11,732' Bench 5 '11,791' - Top of Sand Plug 4/88 11,828' - 11,.858' Bench 6 · 11,905' PBTD 11,969' TD NEF.5/9/88 STATE OF ALASKA ALASK.~, OIL AND GAS CONSERVATION COMM,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging I~' Stimulate J~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-i Cond. #1 Doily Varden ~iatl'or~, 751' FSL, 1,215' FWL, Sec. 5- 8N- 13W- SM At top of productive interval 663' FNL, 296' FWL, Sec. 5- 8N- 13W- SM At effective depth At total depth 499' FNL, 730' FWL, Sec. 5 - 8N- 13W- SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-26 8. Permit number 74-9 9. APl number 50-- 733-20260 10. Pool Hemlock RECEIVED 11. Present well condition summary Total depth: measured ! 1,969 ' feet true vertical 9,885 ' feet Plugs (measured) None Effective depth: measured 11,905 ' feet true vertical 9,836 ' feet Junk (measured) None Casing Length Size Structural Cemented Measured depth Conductor Surface 3,306' 13-3/8" Intermediate 10,239 ' 9-5/8" Production Liner 1,870' 7" 2,750 sx 3,306' 2,690 sx 10,239' 650 sx 11,952' Perforation depth: measured B-1 true vertical B-2 B-4 B-5 Tubing (size, grade and measured depth) B-6 4-1/2" 12.6# N-80 SL tbg to 10,045~: 11,213' - 11,243' MD 9,285' 11,273' - 11,306' MD 9,335' 11,468' - 11,608' MD 9,496' 11,642' - 11,732' MD 9,632' 11,828' - 11,858' MD 9,778' Packers and SSSV(type and measured depth) Baker FH Pkr 4.0" ID @ 10,003'; Otis BV type DK @ 298' APR 1 5 1988 Naska 0ii & Cas ¢0n~. C0m~ Anchorage True Vertical depth 3,148' 8,501' 9,877' - 9,310 - 9,363 - 9,606 - 9,702 - 9,802 ' TVD ' TVD ' TVD ' TVD ' TVD 12.Attachment¢ 1 & 2 Description summary of proposal [] Detailed operations program [] BOP sketch [] Attach #3 13. Estimated dateforcommencing operation April, 1988 14. If proposal was verbally approved~u~~ W~,k, ~e.~J Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge S~gned ~ /-~.,~- Title Enviro~tal Enqineer ROyYD. Roberts Commission Use Only Date 4/13/88 Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug i~ntegrity [] BOP Test [] Location clearance ApprOved Copy R~turned LONNIE C. SMITH by order of Commissioner the commission Date feet Form 10-403 Rev 12-1-85 (.~ Submit in triplicate ¢ Attachment 1 Well D-26 Coiled Tubing Sandback, Hemlock Bench 6 Procedure 1. RU Slickline and pressure test lubricator. 2. RIH, retrieve DK SSSV. 3. RIH w/ 3.70" gauge ring and tag fill. POH. RD. 4. RU CTU and pumping equipment. Pressure test lines and BOP's to 4,000 psi. 5. RIH and tag fill w/ CT. 6. Break circulation w/ FIW. 7. Spot sand and silica flour plug (sand assorted mesh sizes) in gel carrier fluid. Allow plug to settle and pack. 8. RIH and tag plug. Repeat Step 6 and 7 until top of plug tagged at ±11,780 CTM. 9. POH. RD CTU and pumping equipment. 10. RU slickline and pressure test lubricator. 11. RIH and tag fill w/ 3.70" gauge ring. POH. 12. Rerun and test redressed DK SSSV. 13. RD slickline and lubricator. 14. Put well back on production and obtain well test. 70/Sundr4 RECEIVED APR 1 Alaska Oil A Gas Cons. CommissiOIi Anchorage q~'° 12.6# ~8o SL ~-5/8" qO, q3.5., q7# H-8O & P-ilO Buttress casing -: Top of Liner IO,O8~;,239, AvQ. Dev. = 36.7° 7" 2~).f !180 X-Line -Tagged Fill g.11,840' .9/87 Attachme.nc.#2.. TBU.'I~ll D-26 Completion Schematic '(Completed' 6'/'74). ~---. 4 298' ).81)" lO through nipple 1.000" ID through valve Cl~ q~" ~ubing hanger Otis ¥~ireline retrievable bal'l valve - Type DK USi C2F Handrels, Hcflurray type LP Valves, Handrels qeO0 "J ! 4---- 2,612' GLV ~1 i. ( _ '2,678' GLV.#2 · USi C2 H-DSVO- ,' · · 4 - q,062' GLV #3 ~ 5,O12' GLV #q · ~ &,5il' GLV #6 7,001' ~ 7,q63' 7,~2o' ~ 8,3q0' ~ _ ~,718' ( _ ~,110' ¢ _ ~,505' ~ ~,892' .,--- ~,~63' GLV #7 RECEIVED GLV #9 #,o APR 1 5 1908 GLV #11 ' ,2~aska 0ii & Gas Cons, Commlssloll ~LV .~ Anchorage GLV GLV #lq Otis XO Sleeve 3.813" IO ~'-- 10,OO3' Baker rtl Packer 4.000" lO - I I .qoc;' 11,96~)' ( -lO,OhS' Baker Shear Sub q.O00" ID Perforations (DIL) 11,213' - 11,2q3' Bench I 11,273' - 11,306 Bench 2 '. 11,~68; ' 11,608' Bench q I1,6q2' ' 11,732' Bench Top of sand mixture @ 11,780' CTM (pronosed plug) 'BenCh 6 11,828' - 11,858' PBTD Revised 9/87 COILED TU~I-i~'*b-~ "I~IAGRAM - TBU WELL D-26 .. BOP w/1-1/4' RAMS SO00 PSI WP · · ~ ,~ HYDRAULIC RAMS LUBRICATOR POSITIVE CHOKE 4 CONTROL LINE PORTS W/TWO PORTS PLUGGED / VR PLUG ' f000 PSI VR PLUG 2' 3000 PSI 13 3/8' CASING --CHRISTMAS TREE 3-1/8' 5000'~ RECEIVE.I) AP~ ]. 5 ~988 Oil & c~ ¢on~. Commi~!~ An~o~go ,"'-": STATE OF ALASKA ~ ALAS , OIL AND GAS CONSERVATION COM .... SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operati,0~ Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] 'Plugging ~ Stimulate ~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at st~face Leg A-1 Cond. (/7 DoiLy Varden Flat~orn 751' FSL, 1,215' FWL, Sec. 5- 8N- 13W- SM At top of productive' interval . 663' FNL, 296' FW'L, Sec. 5- 8N- 13W- SM . At effective depth At total depth 499' FNL, 730' FWL, Sec. 5- 8N- 13W- SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-26 8. Permit number 74-9 9. APl number 50-- 733-20260 10. Pool Hemlock RECEIVED feet 11. Present well condition summary Total depth: measured true vertical 11,969 ' feet 9,885 ' feet Effective depth: measured 11,905 ' feet true vertical 9,836 ' feet Plugs (measured) Junk (measured) None APR 1 ©'' Alask= 0il & Gas Cons. C0mmissi Anch0raoo None Casing Length Size Structural Cemented Measured depth True Vertical depth Conductor Surface 3,306' 13-3/8" Intermediate 10,239 ' 9-5/8" Production Liner 1,870' 7" 2,750 sx 3,306' 3,148' 2,690 sx 10,239' 8,501' 650 sx 11,952' 9,877' Perforation depth: measured true vertical Tubing (size, grade and measured depth) 4-1/2" 12.6# N-80 SL tbg to 10,045' Packers and SSSV (type and measured depth) B-1 11,213' - 11,243' MD 9,285' - 9,310' TVD B-2 11,273' - 11,306' MD 9,335' - 9,363' TVD B-4 11,468' - 11,608' MD 9,496' - 9,606' TVD B-5 11,642' - 11,732' MD 9,632' - 9,702' TVD B-6 11,828' - 11,858' MD 9,778' - 9,802' TVD Baker FH Pkr 4.0" ID @ 10,003'; Otis BV type DK @ 298' 12.Attachment¢ 1 & 2 Description summaryofproposal [] Detailed Operations program [] BOP sketch [] Attach #3 13. Estimated dateforcommencing operation April, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed t/~;~..,~./"~/~/~ /',)..,.g' Title Environr~ental ~q~e~ ~D. ~r~ Commission Use Only Conditions of approval Approved by Date 4/13/88 ORIGINAl. SIGNED BY LONNIE C. SMITH Notify commission so representative may witness '[] Plug integrity [] BOP Test [] Location clearance Approved Copy Commissioner J Approval No. ~,,..,,~,,~ ~ by order of the commission Date'¢-"/.~~''' 2~~::~ Form 10-403 Rev 12-1-85 Submit in triplicate Attachment 1 Well D-26 Coiled Tubing Sandback, Hemlock Bench 6 Procedure 1. RU Slickline and pressure test lubricator. 2. RIH, retrieve DK SSSV. 3. RIH w/ 3.70" gauge ring and tag fill. POH. RD. 4. RU CTU and pumping equipment. Pressure test lines and BOP's to 4,000 psi. 5. RIH and tag fill w/ CT. 6. Break circulation w/ FIW. 7. Spot sand and silica flour plug (sand assorted mesh sizes) in gel carrier fluid. Allow plug to settle and pack. 8. RIH and tag plug. Repeat Step 6 and 7 until top of plug tagged at ±11,780 CTM. 9. POH. RD' CTU and pumping equipment. 10. RU slickline and pressure test lubricator. 11. RIH and tag fill w/ 3.70" gauge ring. POH. 12. Rerun and test redressed DK SSSV. 13. RD slickline and lubriCator. 14. Put well back on production and obtain well test. 70/Sundr4 REC IVED APR ] Alask,~ Oil & Bas Cons. commissio. Anchorage q{" lZ.6# n80 SL 3-5/8" 4o, 43.5, 47// ti-8o & P-Ilo Buttress casing' Top of Liner 10,08.2~ .~LJ ~ J.U t ZJ ~ · AvQ. Dev. : 36.7° 7" 2~ tl80 X-Line , Attachmen: #2.. TBU.'Well D-26 . ., ..Completion schematic (completed' 6/74) ,. -Tagged 'Fill .918, . ... J, ,...J ' .... : ..... .969' ; ~ ~i" ~ - Z38' "J ~ 2,612' · (,.~ '2,678' .' - ~ 4,O62' · GLV 13 ~ 5,~12' GLV #4 5,857' GLV ~5 , ~. 7,OO1' GLV ~? ~ 7,453' GLV #8 ~ 7,320' GLV #3 · , ~ 8,3~O' GLV #10 '~___ 8,718' GLV #ll · e--- 3,110' ( 3,505' ~ 9,8~2' · GLV · ~ 10,OO]~ ~ 10,O45' Perforations (DIL) CiW ~" ~ubing hanger Otis w;reline retrievable bal'l valve - Type OK ~.81]" I0 through nipple 2.000" I0 through valve GLV ~1 GLV.#2 USI C2F Handrels, Hc~urray ~ype . ~-OSVO-LP Valves, ~landrels ~.OO"10 RECEIVEI)., ApR 1 5 19 8 GLV ~12 Alask= 0il & Gas Cons. C0mmi~i0~ ~LV ~, ~ Anchorage Ol:iS XO Sleeve ].813" ID Baker Ftl Packer 4.OOO" ID Baker Shear Sub 4.000" ID !1,213~ - 11,2~3' Bench 1 Bench 2 11,~68; - !1,608' Bench 11,6~2' ' 11,732' Bench 5 Top o~ sand mixtu:e @ [[,780~ CTM (p:ooosed plug) 11,828' - 11',858' 'BenCh 6 PSTD TO Revised 9/87 ,' · . COILED TBU WELL D-26 lOP w/1-1/4' RAMS &O00 PS1 WP .. LUBRICATOR POSITIVE CHOKE VR PLUG ' 000 PSI ~CHRISTMAS TREE 3-1/8' 5000'~' ' 'l-:-t :4 CONTROL LINE PORTS w/TWo PORTS ,'LUOO,I~ECEIVED 13 3/8' CASING APR I 5 !~':~ Alaska Oil & Gas Cons. Commissior~ Anchorage STATE OF ALASKA ~--~ ALASK~, -)IL AND GAS CONSERVATION C.,MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLXI~ OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 74-9 3. Address 8. APl Number P. O. Box 6247, Anchorage AK 99502 50_733-20260 4. Location of Well Surface: Leg A-i, Cond #7, Dolly Varden Platform 751' FSL, 121.5' FWL, Sec. 5-8N-I~3W-SM 5. Elevation in feet (indicate KB, DF, etc.) KB 106.2' above MSL I 6. Lease Designation and Serial No. ADL 18729 12. 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-26 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: '(Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling 7'ubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On 10/26-28/81 the following intervals were perforated under drawdown: Bench 4: 11,548'-11,578' DIL, 3-1/8" 120° phasing The following intervals were repreforated under drawdown: Bench 4: Bench 2: Bench 1: 11,578'-11,608' DIL, 3-1/8" 180° phasing 11,468'-11,548' DIL, 2.6" 180° phasing 11,276'-11,306' DIL, 2.6" 180° phasing 11,213'-11,243' DIL, 2.6" 180° phasing Production before reperf: 1858 BFPD, 75% WC, 1394 BWPD, 464 BOPD Production after reperf: 2266 BFPD, 90% WC, 2039 BWPD, 227 BOPD NOV 2 *Marathon Oil Company - Sub-Operator Alaska Oil & Gas Cons. Oornrnfs$for~ Anchorage, 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The spat[ below for Commission use Date 11/20/81 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA iL AND GAS CONSERVATION C~_ ./IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator 7. Permit No. Union Oil Company of California* ' 74-9 3. Address 8. APl Number P.O. Box 6247, Anchorage, AK 99502 50-733-20260 4. Location of Well ~urface: Leg Al, Cond. #7, Dolly Varden Platform 751' FSL, 1215' FWL, Sec. 5, T8N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) KB 106.2', MSL 6. Lease Designation and Serial No. ADL-18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-26 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 1'0-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) . [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). We are requesting permission to reperforate existing intervals in Benches 1, 2, 4, and perforate a new interval in Bench 4. Perforate Reperforate Bench 4 11,548' - 11,578' Bench 4 11,578' - 11,608' .... 11,468' - 11,'548' Bench 2 11,276' - 11,306' Bench 1 11,213' - 11,243' All above intervals are in the Hemlock zone. 3.8" gun, 4 HPF, 120© phasing 3.8" gun, 4 HPF, 120© phasing 3.8" gun, 4 H~F, 120°'phasing 3.8" gun, 4 HPF, 120© phasing 3.8" gun, 4 HPF, 120© phasing Estimated start up date: October 20, 1981 R. ECEIYED OCT 1 6 lg"' *Marathon Oil Company - Sub-operator Alaska Oil & Gas Cons. Commission Anchorage 14. I ~ certify that the foregoing is true and correct to the best of my knowledge. Signe~--~;~//~t,~,,~_,~%/ /~.,4~., Title DRUG gERT SUPT The s~ce below fo/CZm r~ ~ssi-on us;'" Coyditions of Approval, if any: / ' - HII~I~ 11~',~ By Order of Approved by _ COMMISSIONER the Commission Form 10-403 I~ l~JJl~' C. :~t~ ' Rev. 7-1 ~0 Date 10/14/81 Submit "Intentions" in Triplicate anO "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals,) WELL1 I OTHER 2. NAME OF OPERATOR Union 0il Company of California* 3. ADDRESS OF OPERATOR P. 0. Box 6247, Anchorage AK 99502 4. LOCATION OF WELL At surface NE Leg, Cond #7, Dolly Varden, 751'FSL 1215'FWL, Sec. 5, TSN, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 106.2'KB MLLW 14, CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20260 . 6. LEASE DESIGNATION AND SERIAL NO. ADL- 18729 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Tradin~ Bay Unit 9. WELL NO. D-26 10. FIELD AND POOL, OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, T8N~ R13Wt SM 12. PERMIT NO. 74-9 )ort, or Other Data NOTICE OF INTENTION TO'. FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSE(~UENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING, ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form,) ].5. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. 08-23'79 Reperforated following interval Bench 5 11,642'-11,732'DIL under drawdoWn: 2 HPF 2-1/8" SOS EnerJet gun 08-24~79 Perforated following interval Bench 1 11,213'-11,243'DIL Bench 2 11,273'-11,306'DIL under drawdown:4 HPF 2-1/8" SOS Enerjet gun 4 HPF 2'1/8" SOS Enerjet gun Production tests: Before Perf: After Perf: 2181 BFPD, 24.5% WC 3312 BFPD, 35.5% WC *Marathon Oil Company - Sub-Operator ].6. I hereby ~fy t?t the foregoing is true and correct (Thi~ac~e for Stat~fice use) TITLE Dist. Drlg. Supt. 9i19/79 DATE APPROVED BY_ CONDITIONS O~/~,PPROVAL, I F ANY.- TITLE DATE See Instructions On Reverse Side FORM 484 REV, 3-65 DATE March 31, 1975 M~ATHON OIL COMI:--~:~NY HISTORY OF OIL OR GAS WELL · WELL NO. D-26 STATE Alaska FIELD MEASUREMENTS TAKEN FROM McArthur River ~ Surface: LEASE. Trading Bay Unit, Dolly Varden SEC. 6 TWP 8N PARISH Platform Hemlock: 5 8N ~ COUNTY Kenai Peninsula KB ELEV., 106' , ,, 'ToP OF OIL STRING. ELEV. HISTORY PREPARED BY I~"~ WolsteDholm .TOP OF ROTARY TABLE ELEV. TITLE ~] ~r~ .. GRD. OR MAT, . ELEV._ R..,iI~W SM x 13w SM It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations ot the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, ali tests, all completion operations and procedure, etc. DATE 1974 3-11 3-12 3-13 3-14 3-15 3-17 3-18 3-19 3-20 3-21 3-22 3-23 3-24 3-25 3-26 Reports as of 7:O0 AM for the previous 24 hrs activity. Nippled up 20" riser & hydril. Moved rat hole. Picked up new Kelly & installed new rollers in Kelly drive bushing. Changed oil in swivel. Checked drawworks. Mixed mud. PU 6-8" DCs & 12~ x 17½ hole opener. PU 5" drill pipe. Tagged cmt @ 352'. Displaced out contaminated mud & 50 BBLS wtr. Changed over to spud mud. Cleaned out conductor to 400'. Circ hole clean. RU & ran gyro in drill pipe. Spudded @ 3: O0 AM, 3-12-74. TD 860' - Drld and surveyed 12~" hole. TD 1,323' - Drld ~o!,, hole to 1323' POH. Layed down 5" DP. PU 12~ x 17½ hole opener· Opened hole from 400' to 1~000'. ! ,, ltl,, TD 1,518' - O~ened 12~ hole to_ from 1,000' to 1,323' in 7 hrs. POH & layed down 17~" assembly. PU 12~ - bit, turbodrill & 2° bent sub. RIH & oriented turbodrill & faced tool N31°E. TD 2,453' - Surveyed & ran check shots with gyro. POH. RIH with angle building hook-up. Reamed 1514' to 1628'. Drilled to 2,453' · TD 2,869' - Drld 12~" hole to 2,710'. POH. Layed down 12~" drilling ass'y. RIH with .turbodrill ~2 & 2° bent sub. Orient turbodrill for right hand turn..Drld 59' & surveyed. POH. RIH with drilling ass'y. Drilling 12~" hole. TD 3,320' - Drld from 2,869' to 3,320'. POH & layed down 2,000' of 5" DP. PU 12-1'' 17~-" ~ x hole opener, 17½" stab., & RIH. Opened hole from 1323' to 1800'. TD 3,320' - Opened hole to 17½" from 1800' to 2816'. POH. Cleaned and checked b~?, now opening hole. TD 3,320' - Opened 12!" hole to 17½" to 3320' POH. RIH, circ & cond mud to ~ · condition hole for 13-3/8" CSgo POH. started in hole with 13-3/8" casing. TD 3,320' - Ran 81 jts 13-3/8", 61#, K-55 Casing & landed @ 3,306'. Cemented casing with 30 BBLS water pre-flush, 3568 cuft C1 'G' cmt, 6% Gel, 0.8~ D-B1, 0.2% R-5, followed with 684 cu ft neat C1 'G' cmt with 0.8% D-31, 0.2% R-5. Started mixing @ 5:45 PM, 3-20-74 & finished mixing @ 7:10 PM. Pumped plug & bumped @ 8:57 PM. Pressured on plug to 2,000 psi. Bled back to 1,O00 psi. WOC. TD 3,320' - WOC. Ran 2-1/16" tubing down outside of 13-3/8" csg & found cmt 15' below floor. Cemented with 150 sxs C1 'G' 0.8~ D-31, 0.2~ R-5. Backed off land- ing joint. Started flanging up casing head & BOPE. TD 3,368' - Finished nippling up BOPE. Rebuilt mud pan. Tested. BOP's to 3,000 psi - OK, Hydril to 2,000 psi - OK. Installed wear bushing. RIH with bit & DC. Top cmt @ 3,175'. Drld cmt out to 3,306'. POH. Ran gyro. PU drilling ass'y & drld out to 3,325'. Tested formation to 500 psi - OK. Started drilling ahead. TD 3,962' - Drld & surveyed to 3,906' . POH. Changed bottom hole assembly. RIH. Drilling 12~" hole. TD 4,707' - Drld 12w hole to 4,660 . TriP for bit. Drilling TD 5,363' Drld & surveyed to 5,363 · Tripping for new bit. ~ped & cut drilling line on trip. ~ ~ ~ ~ / History .of Tradim~ Bay Unit Well D-26 Continued: 3-27 TD 5,926' - ~Drld to 5,786'. Trip for new bit & drilling a~sembly. Drilling ahead. 3-28 TD 6,394' - Drld to 6,394'. Trip for bit & bottom hole assembly. Drilling ahead. 3-29 TD 6,890' - Drld to 6,503'. Trip for bit change. Drilled to 6,890'. 3-30 TD 7,085' - Finished P.O.~t.. Pulled wear bushing. Tested BOPE to 3000 psi-OK.. Installed wear' bushing. RIH. Drld to 7,085 ' .. 3-31 TD 7,329' - RIH & drilled ahead. POH to change rotary table. RIH & drld to 7329'. 4-1 TD 7,B83' - ~rld to 7B60'. POH. RIH w/turbodrill & 2½° bent sub. Set turbodrill for turn to ~right. Drld from 7B60' to 7383'. POH. RIH w/drilling assembly. 4,2 TD 7,62B' - Finished in hole w/drilling assembly. Drld to 7,560'. Tripped for new bit ch~e & BHA change. Drilling ahead. 4-3 TD 7,900' -Drld to 7,804'. Tripped for bit change. Cut drlg line. Drlg ahead. 4-4 TD 8,145' - Drld to 8,~O9O'. Tripped for bit. Cut & spliced sand line. Drlg ahead. 4-5 TD 8,408' - Drld to 8,309'. Tripped to change bit & BHA. Drilling ahead. 4-6 TD 8,575' - ~Drld to 8,562'. Tripped for new bit. Drilling ahead. 4-7 TD 8,764' - Drld to 8,764'. Tripped for bit & BHA. 4~8 TD 8,975' - Drld to 8,887'. Tripped for new bit. Drilling ahead. 4-9 TD 9,122' - Drld to 9,091'. Tripped for bit. Drilling ahead. 4-10 TD 9,374' - ~Drld to 9,262'. Tripped for bit. Drilling ahead. 4-11 TD 9,56.0' - Drld to 9,399'. Tripped for bit. Drilling ahead. 4-12 TD 9,778' - Drld to 9,634'. Surveyed. Tripped for bit. Drld to 9,778' & surveyed. 4-lB TD 10,032' - Drld to 9,864'. Surveyed. Tripped for bit. Tested BOPE. Drlg ahead. 4-14 TD lO,lB9' - Drld to 10,083'. Tripped for bit. Survey @ lO,06B'. Drlg ahead. 4-15 TD lO,B04' - Drld to lO,B04'. Tripping for new bit. Surveyed @ 10,162' & lO,B04'. 4-16 TD 10,419' - Completed trip & drilling ahead. 4-17 TD lO,5BO' - Drld to 10,455'. Surveyed. Tripped for new bit. Cut & slipped drilling li~e. Drilling ahead @ 10,530'. 4-18 TD 10,621' - Drld to 10,600'. Surveyed. Tripped for new bit. Drilling ahead. 4-19 TD 10,706' - Drld to 10,702'. Surveyed. Tripped for new bit. Drilling ahead. 4-20 TD 10,822' - Drld to 10,822'. Surveyed. POH. Tested BOPE - OK. RIH w/new bit. 4-21 TD 10,894' - Drld to 10,888'. Surveyed. Tripped for bit change. Replaced 17 its H.W. Drlg ahead. 4-22 TD 10,965' - Drld to 10,932'. Tripped for new bit. Drilling ahead. 4-23 TD ll,105' - Drld to 11,083'. Surveyed. Tripped for new bit & stabilizers. Drilling ahead. 4-24 TD 11,192' - Drld to 11,172'. Surveyed. Tripped for bit change. Drlg ahead. 4-25 TD 11,258' - Drld to 11,258'. Surveyed. Tripping for bit change. 4-26 TD 11,322' - Drld to ll,B06', surveyed. Tripped for new bit. Drilling ahead. ~-27 TD 11,368' - Drld to ll,B56'. Surveyed. Tripped for bit. Tested BOPE to 3,000 psi - OK. Drilling ahead. 4-28 TD 11,406' - Drld to ll,400'. Tripped for bit change. Drilling ahead. History of Trading Bay Unit Well D-26 Continued: 4-29 TD 11,494' - Drld to 11,494'. Started out of hole. & stuck pipe @ 11',h68', 26' off bottom. Top of drilling assembly @ 11,099' - bumper jars @ 10,367'. Jarred down on stuck pipe fo~ 3 hrs. Pumped in & circ out 50 BBLS of 200 viscosity with 405 friction reducer. Continued to work pipe - jarring up @ 360,000~. 4-30 TD 11,494' - Continued to work pipe - unable to move pipe up or down. RU Dia-Log and ran free point & string shot. Backed off heavy wai1 drill pipe three its below jars @ 10,460'. Circ & cond mud. POH. Started in hole with drilling ass'y to condition hole to run casing. 5-1 TD 11,494' - Finished in hole to top of fish @ 10,460'. Circ & cond mud 7 hrs. POH - had tight hole from 9100 to 8650' & 4500'. 5-2 TD 11,494' - Ran 9-5/8" casing to 10,238.72' KB. Circ & cond mud. Pumped 30 BBLS water, lO00 sxs C1 'G' cmt w/l% D-31 & 0.3~ R-5, followed w/7 BBLS water. Cementing rate 8 BI~ @ 800~. Plug down @ 4:30 AM 5/2/74. Bumped plug to 2,500 psi, bled off pressure, held OK. Dropped bomb to open stage collar. 5-3 TD 11,~94' - RU sand line & chased DV tool to open DV sleeve. Pressured csg and opened DV valve. Circ thru DV valve for 3½ hrs - no cmt returns. Cmtd 9-5/8" csg, stage 2, 15 BBLS water ahead, lO91 sxs C1 'G' cmt, 4~ gel, l~ D-31, O.2~ R-5 followed by 300 sxs C1 'G' cmt with 0.8~ D-31, 0.2~ R-5, 15.5~/ slurry. Pumped plug with 2500 psi. No bleed back. PUBOPE, set slips and tubing head - tested to 3000 psi - OK. 5-4 TD 11,494' - Finished flanging up BOPE. Tested to 3000 psi - OK. RIH w/bit and drld stage collar @ 6501'. Tested csg to 3000 psi - OK. Drld float col- lar @ 10,157', hard cmt to shoe @ 10,23~', drld shoe & 3' hard cmt below shoe. Washed to top of fish @ 10,460'. Circ & cond mud. POH. 5-5 TD 11,494' - POH with bit. RIH with 5" open-ended DP to 10,460'. Spotted 200 sxs C1 'G' cmt, 1% D-31, 0.4~ R-5, 20 sxs sand - 14~ slurry, from 10,460' to 10,239'. Pulled DP to 10,230 & circulated out contaminated mUd. POH. RIH with bit. WOC 15 hrs. 5-6 TD 11,~94' - Washed down thru cmt plug from bottom 9-5/8" Csg at 10,239' to 10,~60', top of fish. Circ & cond mud - no cmt returns. ~OH. RIH open-ended to 10,460'. Set cmt plug from 10,460' to bottom of 9-5/8" csg - 400 sxs C1 'G' with l~ O-31, 0.4~ R-5, lO~ sand - 16~ slurry. CIP @ 5:00 PM, 5-5-74. Pulled 9705' & reversed - no cmt. POH. WOC. 5-7 PBTD 10~239' - WOC. RIH to 5104'. Pushed DP rubbers below bit POH PU 16' of 8-1/8" washover pipe. RIH & pushed rubbers from 5104 to 101033' [ Spudded on rubbers, POH. Recovered ll DP rubbers. Cleaned out wash pipe. Cut & slip~ ped drilling line. RIH with washover pipe. 5-8 TD 10,333' - Spudded on DP rubbers. POH & recovered 5 DP rubbers. RIH w/8~" bit & DA to 10,033'. Drld hard cmt to 10,245', started drilling formation. Drld from 10,245 to 10,314'. Ran survey &drld from 10,314' to 10,333'. Ran survey. 5-9 TD 10,452' - Drld to 10,355'. POH for bit & BHA.-RIH & reamed from 10,245' to 10,355'. Drilling ahead. 5-10 TD 10,518' - Drld to 10,515'. Tripped for bit & BHA. Installed wear bushing. Slipped drilling line. RIH. Washed from 10,470' to 10,515'. 5-11 TD 10,733' - Drld to 10,733'. POH for bit change. 5-12 TD 10,892' - RIH to 10,733' and drilling ahead. 5-13 TD 11,164' - Circulated bottoms up & ran survey @ 10,943'. Pulled up to' 9-5/8" shoe - hole in good condition. Drilling ahead. 5-14 TD 1!,320' - Drld to 11,171'. Tripped for new bit. Hole in good condition. Circ & surveyed @ 11,219'. Drilling ahead. 5-15 TD 11,446' - Drld to 11,438'. POH to 9-5/8" shoe. Attempted to retrieve survey --unable to do so. POH. Changed BHA & bit. RIH, reamed 60' & drilling ahead. ~HistorM,of Trading BaM Unit Well D-26 Continued: 5-16 TD 11,592' - Drld and circulated to 11,576'. Attempted to survey - hole tight. Continued drilling to 11,592'. Circulated hole and dropped survey at 11,592'. 5-17 TD 11,710' - POH, tested BOPE. RIH to csg shoe. Changed drilling line. Reamed from 11,530' to 11,592'. Drld to ll,710'. 5-18 TD 11,833' - Finished out of hole. RIH. Drld to 11,833'. POH, measured out of hole & corrected measurement. Left two cones in hole. RIH with bit. 5-19 TD 11,870' - Broke up cones & drld to 11,870'. Circ & cond mud. Made short trip to shoe. Circ & cond mud. Hole in good shape. POI{. RU Schlumberger. Ran Sonic & DIL logs from 11,854' to 10,239'. Now running density log. 5-20 TD 11,969' - Finished logging. RIH with bit & DA & drld to 11,969'. Making short trip. 5,21 TD 11,969' - Continued short trip. Conditioned hole to run 7" liner. POH. Ran 43 jts 29~, N-80, X-line, 7" casing. Hung liner with top @ 10,082', bottom of shoe @ 11,952', & float collar @ ll,905'.~Pumped 50 BBLS water ahead of 650 sxs C1 'G' cmt with 1% D-31 & 0.5~ R-5, 15.8 to 16~ slurry. Bumped plug with 2500 psi. Released pressure - held OK. Set liner hanger pkr. Reversed out 50 BBLS cement contamined mud. POH. WOC. CIP @ 3:15 AM, 5-21-74. 5-22 TD 11,969' - WOC. Completed out of hole laying down DCs & HW DP. RIH w/9-5/8" ~l,, 6" ~k,, bit to 10,082' POH. PU 2000' o~ DP & bit & started in csg scraper & v2 . · hole. 5-23 TD ~1,969' Finished in hole with bit. Rrld cmt from 11,756' to 11,905' - hard cement. Circulated hole clean. POH. RU & ran Eastman gyro from 11,905' to 2900'. RU & ran CBL log - stopped on top of liner. POH & changed springs & reran tools. 5-24 TD 11,969', PBTD 11,905' - Ran CBL log from 11,905' to 10,082'. Fair to good bonding between all Hemlock benches except 5 & 6. Fair bonding below 9-5/8" s.hoe. Ran Halliburton RTTS DST tools to test liner lap @ 10,082'. Ran 2000' of filtered inlet water for cushion. Set pkr@ lO,OlO'. Opened tool @ ll:lO PM, 5-23?74. Open i hr, closed 2 hrs. Pulled loose @ 2:15 AM, 5-24-74. IHP -4320, IFP-682, FFP 682, FSIP 752, FHP-4330. Had weak blow for lOmin. Re- covered 20' mud (1/3 BBL). Running CBL log. 5-25 PBTD 11,905' - Finished running CBL log from 11,905' to 10,082'. RU to run wireline formation test tools. Ran following test: Run Bench BHP RecoverM -~- 6 3--~0 Oil . 11,642 2 4 3310 ?O~wtr,30~oil 11,504 3 5 3930 Gas-cut mud 11,704 4 2 3650 ?O~wtr,30~oil 11,334 5 I 3250 " " " " 11,224 6 4 3580 30~wtr,70~oil 11,605 *Appears to be filtrate water 5-26 PBTD 11,905' - Rigged down Schlumberger. RIH w/bit to 11,905'. Circ & cond mud. POH - laying down drilling string. Pulled wear bushing. Installed 4½" rams. Started in.hole with tubing string. 5-27 PBTD il,905' - Ran 308 jts 4½", 12.6~, N-80, SL, Tubing with Baker hyd. pkr, circulating valve, gas lift valves & safety ball valve(tubing ret. type- full opening). Set pkr @ lO,OlO', bottom tail pipe @ 10,046', circ .sleeve @ 9969', & safety ball valve @ 309'. Set pkr & tested - OK. Set tbg hanger in head. Removing BOPE. 5-28 PBTD 11,905' - Finished removing BOPE. Installed xmas tree & tested to 5000 psi - OK. Tested safety ball valve & line to 5000 psi - OK. RU & shifted circ sleeve @ 9969' on second attempt. Started displacing~ole with filtered inlet water - down tubing. 5-29 PBTD 11,905' -'Displaced hole with water & then diesel. RU & closed circulat- ing valve, & opened gas lift mandrels. Gas lifted to top valve. History of Trading Bay Unit Well D-26 Concluded: 5-BO PBTD 11,905' - Unloaded well to approximately 2nd gas lift valve. RIH and closed one of the top gas lift mandrels @ 2617'. Ran BHP survey - 2905 psi @ ll,5OO'. Continued to gas lift. Ran BHP survey - 9lB psi @ ll,5OO'. Gas lifted - recovering spray of mud. 5-B1 PBTD 11,905' - Gas lifted well. RU and perforated bench #4 from ll,5OO' to 11,520' with B-l/8 jumbo jets, B/ft. Unloaded and cleaned up well to separator. After 5 hours of lifting well started U-tubing gas. Placed well in test separ- ator @ 5:BO AM and well produced B bbls of fluid first BO ~minutes and zero production from 6:00 AM to 7:00 AM. The B bbls production contained diesel, oil~ and ~% water. 6~1 PBTD 11,905' - Gas lifted bench #4 (lst set of perfs) for 4½ hrs - very little recovery. RU & perforated bench #4 from 11,578 - 11,608'; 11,518 - 11,548'; & 11,468 - ll,5OO'., B shots per ft w/B-l/8 jumbo jets. Unloaded and cleaned well to separator. Started unloading @ 9:BO PM. Started testing @ 1:00 AM. 6-2 PBTD 11,905' - Gas lifted bench #Q from 7:O0 AM to l:OO PM. Well producing @ rate of approximately650 BPD with 1% cut (mud). RU & perforated bench ~6 from 11,828 to ll,858'.(CBL), B shots/ft with B-l/8" OD jumbo jets carrier under drawdown conditions. Unloaded well to separator & tested. Well prod- ucing @ rate of 3480 BPD~ 0.2% cut, TP -llO psi., CP - llO0 psi., lift volume 1500 MCF. Preparing to run gradient survey. 6-3 PBTD 11,905' - Tested well to separator for 24 hrs. Well produced @. rate of 3576 BPD with O.8% cut. RU & ran gradient survey. FBHP - 1688 @ perforations, operating on next to bottom gas lift valve. 6-4 PBTD 11,905' - Produced benches 4 & 6 for 5 hours. RU & perforated bench #5 from ll,7B2' to 11,642' with B holes/ft., B-l/8" casing gun - Jumbo Jet. Perforated under draw-down conditions. Unloaded and cleaned well to separ- ator & started testing. Well produced @ following rates: 6720 BFPD, O.7% cut, 120 TP, llOO CP, 1258 lift gas, 1352 formation gas, 201 GOR. Released rig @ 12:01 AM 6/4/74. Union Oil and Gas E' ~iQn' Western Region Union Oil Company of Calif0~rnia 909 w. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 union June 28, 1974 Mr. Homer Burrell Division of Oil & Gas State of Alaska 5001 Porcupine Drive Anchorage, Alaska 99504 RE: TBuS D-26 (ll-S) DOLLY VARDEN PLATFORM Dear Mr. Burrell: Enclosed for your files are the Well Completion Report (p-7) and the directional survey for Trading Bay Unit State Well D-26, Dolly Varden Platform, Cook Inlet, Alaska. Very truly yours, im R. Callender District Drlg. Supt. sk Eno1. (2) cc: Marathon Atlantic Richfield Amoco Production Standard Skelly Phillips JUL 2 I974 OiL AND }"oPm P-- 7 ~' SUBMIT IN DUPLI~.C.,&fE* STATE OF ALASKA :see other bi- st ructions on reverse side ~, OIL AND GAS CONSERVATION CO/IAMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF w~LL: on,' WELL WELL L_J DRY[_J Other b. TYPE OF COMPLETION: w E L I, 0V F,R E X B aC K nESV R. Other __ 2. NAME OF 0P~CRATOIt *Union 0il Company of California 3. ADDRESS OF OPERATOR 909 West Ninth Avenue, Anchorase~ AK 99510 4. LOC^rION Or WrLL '-(Report location clearly and in accordance with any State requirements)* it su~ace 751.5' FSL & 1214.8' FkrL of Sec 6, TSN, R13W, SM, NE Leg, Conductor 4/7 Dolly Varden Platform At top prod. interval reported below ~ Hemlock-663' FNL & 296' FWL of Sec 5, T8N, R13W, SM At total depth 499' FNL & 730' FWL of Sec 5, T8N, R13W, SM §. AP1 N~CAL CODE API #50-133-20260 6. LEASE DESIGNATION A_ND SERIAL NO. APL 18729 7. IF INDIA.N, ALLOTTEE OR TRIBE NANLE 8. UNIT,FAfft. M OR LEASE NAME Trading Bay Unit 9. WELL NO. D-26 (11-5) 10. FIELD AND POOL, OR WILDC&T McAt thur River-Hemlock 11. SEC.. T., R,, M., (BOTTOM HOLE OIiklECWIVE) 12. Sec 6, T8N, R13W, SM (surface) PER.MIT NO, · 74-9 3/12/74 5/20/74: [ 6/4/74 ! +106.2' KB (MLLW)_ J+b5,2'{.MLLW) 11,969' lid a :q_aaS' TVq I 9.~' Tvn / -- ~L -- ~. P~ff~CIN~f~VAL(S), OF ~-CO,~TIO~--TOP, BOSOM, NAME (~ AND ~)* ~. ~VAS DIRE~ONAL : ] SURVEY MADE Hemlock: 11,~68' 11~858~ ~ or 9,~96~ - 9,800~ TVD t Yes 24. TYPE ELECTRIC AND OTHEI% LOGS RUN DIL/SP, Sonic/GR, ,Density/GR/Calip.. CBL 25. CASING RECORD (Report all strings set in w~ll) CASLNG SIZE WEIGHT, LB/FT,~ GI{ADE I DEPTHSET (1VID) HOLESIZE 13-3/8" OD 61gi/fc. [ K-55'[ i.-il:,_ I 9-5/8" OD %0#, 43.5#::, , N_80 ! 16;~i~' 12-1/4"[ 7" Liner ;ee~]nw &Iit'~htent #1' 26. LINER RECOIl.El . 7!' OD [10.082' [111_qq9' l,,, 650 ~ 28. PEIZF'OR. AT~ONS Op~NI TO PRODU%O1NT (interval, size and number) (See Attachment #2) CI~MLNTING RECORiD A~IOUNT PULLED (See Attachmanr #1~ 27. TUBING RECOP. D ir 4-1/ g~,'OD !0~0a6,,, , 10,0~n' ACID, Si!OT, FiIACTURE, CEJ, IENT SQUEEZE, ETC, i 6/DATE1/ 7 4FIRST PI%ODUCTION [ pI%ODucT1ONGas Lif tMEiliO'D (Fiowi~:g,_~las lifL purnping~e~{~ii~Pek6~.~l~i{~[~.A. .~.~. '*-"Pt~J~4~' ~.lll~a ~ !WELLanuL-in)STATUS (Producing or _ ' ' ' ] Producing ~AT~ 0e T=ST, I::OURS T~.ST~D: 'lCX:OX~. S:ZE IPP. OZYN FO,R oIL--BBL. G.,tS---tVLCF. WATEI-~--BBL. }GAS-OIL R.'kTIO [ [ ITrST PEPJ_ O D _6i9_r15/74 : | 168 : 10pen I - -" 141 823 [ 12.784 [ 132 Ja 306 FLOW,r_~Ess. TUNING [ICASLNG PRESSURE: [24-HOuR[CALCULATEDRATE .[OIL--BBL' GkS---MC~'.'" -WA~BBL." ' }0IL VITY-API (CORR.) 165 psi I 1,160 psil ' ; 15,975 I i 826 I 19 33° m i r;~s'Posmo~ o~ ~AS (,Sofa-, u,'¢a .tot tue~, ventea, etc.) ~" ~ ' ' .............. ' I ~E: WITNESSED BY Delivered to Marathon-Union Gas Gathering SFstem . E. Lawrence 32. LIST OF ATTACHMENTS " (1) Casinh& Cemen:ting Record. (2) Perforatin~ Record~ & (3) Directional Survey 33. I hereby/rce[tify that th~ fo_re~oJ,i~g and attached ~nformatton l~ eomplsto and correct aa determined from all-available re¢'Ords ii i i *(See Instructions and Spaces [or Additional Data on Reverse Side) *Marathon Oil Company --- Sub-Operator INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion rej~ort and log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attac~:~.~er'~ts Items 20, i~ncl 22:: If this well is completed for separate prcd~ction from more than one interval zone (multiple completion), so state ~n item 20, and in item 22 show the p:cJucir~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produceJ, show- ing the adlditionat data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~,d. (See instruction for items 20 and 22 above). , , 34. SUMMAH. Y OF FORMATION TESTS IN('I.UI)[N(; INTERVAL TFkSTED, PHIgS~q'URE DATA A.N'D RF_.COVERIES OF OIL GAS. 35. G I~I~OG IC M AR KKI::~ WATE~ AND MUD No DSTs or cores were taken, but a wireline formation test tool was run. . . ~.AS. For results refer to Attachment ~2. '~G" Zone 10,61~~ 8,799~ Hemlock 11,20~ ~N~ 'DE'~'ECq~Et) StiOWS OF OIL, G~S O'R ATTACHMENT I TBUS WELL D-26 CASING & CEMENTING DETAILS June 19, 1974 K. A. Thoma (1) Detail of 13-3/8" surface casing run on 3/20/74: Ran 81 joints of 13-3/8" OD, 61#/ft., K-55, Buttress casing. Landed casing with shoe at 3,306' and float collar at 3,221'. Cemented with 2,150 sacks of Class "G" cement with 6% gel, 0.2% retarder, and 0.8% friction reducer; tailed in with 600 sacks of Class "G" cement with 0.2% retarder and 0.8% friction reducer - no gel. (2) Detail of 9-5/8" casing string run on 5/1/74: Ran 250 joints of 9-5/8" OD, 40#, 43.5#, & 47#, N-80 & P-110, Buttress casing. Landed with shoe at 10,~239', with the float collar at 10,156', and a stage collar at 6,500'. Cemented as follows: 1st Stage (6,500'-10,239') - Used 1000 sacks of Class "G" cement with 4% gel, 1% friction reducer, and 0.3% retarder; and tailed in with 300 sacks of Class "G" cement with 1% friction reducer and 0.3% re- tarder - no gel. 2nd Stage (surface - 6,5007 - Used 1091 sacks of Class "G" cement with 4% gel, 1% friction reducer, and 0.2% retarder; followed by 300 sacks of Class "G" cement with friction reducer and retarder, but no gel. (3) Detail of 7" liner as run on 5/20/74: Ran 43 joints of 7" OD, 29#/ft., N-80, Extreme Line casing. Top of liner at 10,082' liner hanger at 10,091' , screw-set packer at 10,089', , collar at 11,905', and shoe at 11,952'. Cemented with 650 sacks of Class "G" cement with 1% friction reducer and 0.5% retarder. ATTACHMENT II June 19, 1974 K. A. Thoma TBUS WELL D-26 PERFORATION RECORD (1) Following are perforated intervals in the Hemlock formation presently open to production in Well D-26: Hemlock Perforated Footage Shot To tal Bench Interval Shot Density Holes 4 11,468'-548' 80' 3 HPF 240 4 11,578'-608' 30' 3 HPF 90 5 11,642'-732' 90' 3 HPF 270 6 11,828'-858' 30' 3 HPF 90 Total .... 230' ......... 690 Ail holes shot with 3-1/8" jet - casing guns, run thru-tubing (4-1/2" O.D.) which provide a 0.32" diameter hole. (2) A formation test tool was run on wireline (5/25 & 26/74), which shot a single 0.29 in. diameter hole at each test interval to take a formation fluid sample and pressure. All fluid samples recovered (approx. 2.7 gal. each) were analyzed as filtrate water and drilling mud with varying quantities of oil. Following are the depths tested and pressures recorded: Bench Depth (MD) BHP (p. si) 1 11,224' 3,250 2 11,334' 3,650 4 11,504' 3,310 4 11,605' 3,580 5 11,704' 3,930 6 11,842' 3,960 ATTACHPiENT I June 19, 1974 K. A. Thoma TBUS WELL _D-26 CASING & CEMENTING DETAILS (1) Detail of 13-3/8" surface casing run on 3/20/74: Ran 81 joints of i3-3/8" OD, 61f//ft., K-55, Buttress casing. Landed casing with shoe at 3,306' and float collar at 3,221'. Cemented with 2,150 sacks of Class "G" cement with 6% gel, 0.2% retarder, and 0.8% friction reducer; tailed in with 600 sacks of Class "G" cement with 0 2% retarder and 0.8% friction red~,cer _ no gel. . (2) Detail of 9-5/8" casing string run on 5/1/74: Ran 250 joints of 9-5/8" OD, 40f%, 43.5#, & 47#, N-80 & P-il0, Buttress casing. Landed with shoe at 10,239', with the float collar at 10,i56' and a stage collar at 6,500'. Cemented as follows: , l~t Stage (~500'-10,239,) _ Used 10~0 sacks of Class "G" cement with 4% gel, 1% iction reducer, and 0.3% retarder; and tailed in with 300 sacks of Class "G" cement with 1% friction reducer and 0.3% re- tarder _ no gel. 2nd Stage (surface _ 6,500~_ Used 1091 sacks of Class "G" cement with 4% gel, 2% friction reducer, 300 sacks of Class "G" and 0.2% retarder; followed by but no gel. cement with friction reducer and retarder, (3) Detail of 7" liner as run o.n. ~/20/74: Ran 43 joints of ~', ~- - ~'" ~ ~' , t up, 29~J/ft., N-80, Extreme Line ca ' at 10,082 , screw-set acke at 11,905', and~sh~ .P ~_ r at 10,089', li~=- ~ s~ng. Top of liner · ~ a~ ±l 9 ~ ~ hanger a cement with 1% ~'-~. , 52 . Cemente~ ..; ...... t 10,091', collar ~&cc~on reducer and O ~v ]_[~cn. o)O sacks of Class "G" .... 'o zeLaroer ,fill._ 2 i§74 ATTACHMENT II June 19, 1974 K. A. Thoma TBUS WELL D-26 PERFORATION RECORD (1) Following are perforated intervals in the Hemlock formation presently open to production in Well D-26: Hemlock Perforated Footage Shot To tal Bench Interval Shot Density Holes 4 11,468'-548' 80' 3 HPF 240 4 11,578'-608' 30' 3 HPF 90 5 11,642'-732' 90' 3 HPF 270 6 11,828'-858' 30' 3 HPF 90 Total .... 230' ......... 690 All holes shot with 3-1/8" jet - casing guns, run thru-tubing (4-1/2" O.D.) which provide a 0.32" diameter hole. (2) A formation test tool was run on wireline (5/25 & 26/74), which shot a single 0.29 in. diameter hole at each test interval to take a formation fluid sample and pressure. All fluid samples recovered (approx. 2.7 gal. each) were analyzed as filtrate water and drilling mud with varying quantities of oil. Following are the depths tested and pressures recorded: Bench Depth (MD) BHP (.psi) 1 ; 11,224' 3,250 2 '? ~ 11,334' 3,650 4 11,504' 3,310 4 11,605' 3,580 5 11,704' 3,930 6 11,842' 3,960 .ItJL i974 TUBING/CAS ING DETAIL Well No. ID-~C= Set ANCHORAGE DIVISION Date By ~x~o~w~ ~ ~.~ No. Length From To Size Wt. Thd. Gr. .Rge. Cond. Remarks .~q' ' ' ' " ] ' ' ..... , ........ ~ . t . i ' ........ ~ ' .. , ( ' ,.. , , ,, ,~ , ...... ~ , . ,, , . , . _~_ ~ - "i " I I ! t !. ! "i "I t ! ~' , .......... , ........... ~ ,.~ , . , i , I I I '"i .....,.~ "~ ...... i~ .......... .... I '1"t t ..... , i ....... ~ , '", " ' I.. '"'t ..... I ' , ..... '0 'WELL ~ -~ [~ Ran Casing As Fpllows: · .__ // Jts ' Spotted Centralizers At Following Depths: · ~1 /" ~P./~.,2~" Collar · j/.~. .? , Feet Feet · Feet Feet Feet Shoe ..- ~. 7-'~ Fee t Total~-Overall .?~2¢/,./7 Feet ,-. Landed Top.Of Collar I/¢, ~0 _ Feet Below KB.. """ · - , kan~led Shoe At ~3~.. ' KB With Top Of Float Collar At ~xn¢2/ KB. · ' ' .~ ~.~. ¢" ~ "'~' Cemented Casing With 'ccn/~ Sacks Of ~ % GEL, ~' ~ 0,$%.',. ~.--..,~ _ Caldium Chloride, Clas~ And With_ [~oo Sacks' Neat Cement With % Calcium ~hloride, .. ¢...3... % RS, ~:P,~ % :~ Used % Excess Cement Volume For Job, Pumped ~ 0 Slurw At _.,..C '7 ,,*A'?x,~?- f//Gal. Pumped ' Cement Slurry'And Displaced Casing With · ~Wi.th_ ~,¢..- . Pump. Plug Down At Bumped Plug With ~OOD PSI.' Mixed Cement · Barrel s Beh i nd Barrels_ /L~'/]7-z-:"/?. _ Ahead Of Cement Slurry. Barrels Of /~?/¥/~ ~,.~o¢~ Return While Cementing. ,~zo Barrels Cement To Surface After DisplacTng Casing. Released Pressure, Checked"~i':(~-~'~;-'E~-~-:~'p'n~ent. ' · .' Float Equipment Checked Waited On Cement. Itours. OILIER REMARKS FROM TO ORDER NO. ORDER NO. SIZE ,/,~ '"~'/St! WEIGHT , ,~'/~' · GRADE, RANGE ~ THREAD B~4 TT' ~~ __ MAKE COUPLING. TYPE REMARKS i , :OL: NO. OF NO. JOINTS _ . 3 ,,, 4 5 _ _ T REMARKS CARRI ER VEHICLE NO, TALLIED BY TUBING/CAS ING DETAIL ANCHORAGE DIVISION Well No..D-ZG Date Set No. ~ From To ]Z~ l~,l_~O.W~~ q,,o44,V~ i' . 2.5B' [0,23&, f4 q:O447fE t I Size o~/~ Wt. Thd. Gr. Rge. I..,-o c....L_.,, o,~,~' ,er_ 1,,~o, ,,-;o ~ i I . 1 / i I , I I 't - 1 Cond. Remarks ToP ,-,,mc{ ! ; /°A b- SI; / . to/F~I(,-- pctmP TUBING/CASI'NG ~ DETAIL ANCHORAGE DIVISION Well No. ~-~Co ~ -~" L.,o~*- Date ........... Se~ No: Length From To Size Wt. Thd. Gr. R~e. Cond. Remarks INBOUND TALLY P I PE TALLY OUTBOUND TALLY < RE. "Y/o,~,-~ c.s"~c,..., ~ ~-'~z.m_- ~_ BRANCH /-I, ~ INVOICE NO. . , CUSTOMER ,S ORDER NAME ~A~~ 0~ ~~~.~ , NO. ~UANTITY CAR INITIAL ORDERED ~ ~s.1 DESTINATION ~T 4~ ~ O.D.-I .D. AR~ ICLE ~ . SIZE SHEET [ OF I SHEETS WE I GHT '2.9"*' GRADE ~0.-~ RANGE ~THREAD ~.'" I ,,,,¢.,T&C __ PI ECES FEET JOTHs O~ IOTHS OF IOTHs OF I JOTHS OF 10THS OF ...... ~F'_oov FEET , . F~ FEET F~T FEET F~ FEET F~T FEET , ..... ~ ~j ~z 5~ .... 3 . , ~ . . - _ __ *,,. 4,3 ~ ~ 3 -~ ,. G .¢~ ~ ~'T ~..- ~~ ~o ~ .'~0 ,.,~3,, ,.. . ....... 13 14 ' '' '" , , ............ [ , , - . . . . . , ........... ~ , ......... ......... ,, , .... ,9 ~9 j ............ - , , , , ~ . , , .......... , ~ .... ~1 ......... ~ ,. .... .......... , - ,r, .. , COLUMN ' '" ' " ' ' ' .... Ii', I 'il [, il ,,!, ,','.Il'_ ..,,! ,,, COLU~ TALLIED BY TOTAL ~ COLUMN ~'-nu ~ ,8+~ ~ f nAmE OF CUSTOMER TRUCK Ck .~ " O~ TRUCKING C~tPANY NO. TOTAL SIGNATURE OF CUSTOMER COLU~ OR TRUCKING C~PANY TOTAL EEPRESENTAT I VE __ ..... : , COLU~ ~L GRAND TOTAL PIECE5 TOTAL Service Company or Rig Customer Order Number LINER REPORT 0,!;: SETTING TOOL ~0, ., TOP OF L NER_IO.O ( PACKER. \O,O~'~ Mailing Address"~o ¢: ~..3~'0 Intermediate Set at_ Intermediate Float Collar Total Depth_ I1: ...~ (¢ (I Length of Liner_ ~. ~"~ 0 Lenqth of Shoe t~ ,~" Length of Landing Collar. Length Hanger_ I O. 0 0 Length Packer ~' ,"5,2~' Length Change Over Sub_ Length Setting Tool -. Drift Drill Pipe. Number Centralizers. Number Scratchers Number of Stop Collars Circulated Mud ~. 0 Circulating Rate.. ~' Reciprocate Liner Rotate Liner Size Wt..~ ~2'& Z(77 ~' · . _ Size Wt._'"( _Type ~/ TYpe._~{_~\ ~ .'1'4, C Type- % .. Type TYpe ...,~ 5 , Type Type _Type Min. after Liner on Bottom -ga~s/m~n. Ft. strokes .Min. R.P.M. HANGE'R / [3. 0(4,0 COLLAR. SHOE LANDING COLLAR Rotate Liner " - .: Min. prior to cement Rotate Liner Mins. while cementing__ · Top of Liner at.. ~..O~O.~z~ I Above Bottom of Intermediate !~'(4 Pumped ,-%,5"" bbls. of Wash or Water ahead of cement Cemented .by ~. ;~ .' Type of Cement (~ Sacks used Type of Mix. Amount of Excess .... Start Mixing at.. ~ Finish Mixing at I Maximum Pumping Pressure .... I ~ O0 Average Slurry Weight Average Displacement Rate Back Washed Pressure--Plug~ped at ~~._ Comments P.S.I.... lb/gal - bbls./min.- bbls.. I SET SHOE [ I~ C~,,%~(.), ......... (This copy to customer) Set No. Len g th. From 4~.~'~' ~?ZTb L 13' 4, ~;~ go?. f/ To TUB I NG/CAS I NG -'~ DETAIL ANCIIORAGE DIVISION Date Wt. Thd. Gr. Rge. /~. 60.5: ~ : fi'go . . , Cond. Remarks / 1:- ..... - ........... I t '_'ri:r;'''~' 7'~"z: ;;z!~: '...tO -Zp:,%' /6" ,Z I ' ' ^-'":" '¢-'.:0 -f?' '"" , c C rn.'..r Irc ~' /~- . .: '~ . : /, r.. ~ Y ,-,f, f,.c /-,? ;]: I 4~ 4~ 4"~ 7 fM. '~c 4~ 74L~,4a 74j 7. 4o,ol,.T4 4'3 Size 4~ 4~ 4~ 4~ 4~ 4o ~L5,2 4'ob6.77 4~ 5. L. //-90 .., DETAIL A~CHORAGE DIVISION Date By Set ,¢'. 4~ To ?/o?, 5'¢ Size 45 Wt. Thd. Gr. Rge. Cond. .¥ _.r~ ,_, I -' '-'-I , , ,_.- ,_,,_:~_,:/£~L ~, ~ ! Id. fr'?E-- FN w k~P.. Re ma r ks b c..~.x O -Z P './:.'. ; ~P 6~ L t 'GAS LIFT INSTALLATION SHe'"T / · DATE INSTALLED . , TUBING CASING Size: ' - :,: Size: ~'~'-':: /!'~ .... / - Thread: ' '"~ ~ - ~ ~ .'.'; Thread: PACKER Make: Type: .... WELL NO: ~"~- FIELD: 3,?,':~;-~ ~.~ A 1--,. ~.,~ LINER O.D. Grade:._ Weight: No. Joints: :'- Seat: Avg. Length:. , Perfs · DESIGN INFO.: Top'. ............ VALVES Total Depth: GAS PRESSURE K. O. (AvaiL): FLU ID: K. O. (Req'd.):_ ~ '"~ .... Oil Gravity: . . Operating:. %HzO: , Grovlty: Fluid Grad.~ ELEVATION DATA: Fluid Prod (Req'd.):~ .. Static B. H. P. P.I. Trap Press: . Flowing B. P.: Static F. ! · Type Oper.: No. Valves: Type Checks: No. Checks: Mand. Type: ............ ' ' VALvE'PREssuRE Set i .... JOINTS SPACING DEPTH, 60° OPEN J60° CLOSE Differential~ PORT & CHOKE MISC. DATA . , ~. -, ~ .~. ..... · .......... ....... ......,~, ,,, ' ........... ....... REMARKS: REPRESENTATIVE TUBING CASING Size: , Size: , Thread: Thread: Grade: V/eight:' No. Joints:.., Seat: . PACKER Make: Type: Seat: .~MPANY: ,~. ~'n',-athon C' il Comp, any WELL NO: FIELD, .~':'~'i Page. 2 of '2 ' · LINER O.~' I. D,: , , Top: Avg. Length:. . Perfs.: DESIGN INFO.: VALVES Total Depth: , Fluid Prod (Req'd.): McM Type: GAS PRESSURE Stati, B. H. P- Type Opera. K. O. (^va;U:.., FLU J D: P.I.: No. Valves: K. O. (Req'd,):. Oil Gravity: ... Trap Press:. Type Checks:. Operating: %HzO: Flowing B.P.: No. Checks: Gravity:. . Fluid Grad · Static F. i · Mand. Type: : ,*J ;,;' I ~' . ELEVATION DATA: j 60° Differential PORT & CHOKE MISC. DATA ,,, ~.:t;Z I. 47 ,.. _ I , ,,, , , ,, , ,, -,. . ,. ,- . ,, ,, , - , , ~' · , , , , ....... , , ~ ,, , .... . . -,~ ........ ,,, , ,, ~ , , , , ........ ~ _ ~ ~ ~ Otis REMARKS: REPRESENTATIVE: -:RATHON OIL ¢0, TBU D"26 ......................................................... .~._.I, JL ......... U'L'~Ii lI- --.LLY BU$t~.I',qG ELEVATION ~06 FT, '---GYRO MULTIEHOT"SURVEY ........... '-.- jtt-t .... ~ ~=,' JUl .... ' ....---]--.']-'' .'-. ..... '~:':GE:,'TIAL METHOD OF COt.lPUTATION$ ............. ""~ "' /~//~ ~ .... EP;,.P. ED FOR EASTMAN-WHIPSTOCK BY FoMo L!NDSEY AND ASSOC° ........... ~]-"~'~"~-'0~'~"'(~,, ...... ...... ' .................. : ................................... -:L' ___ ........................................................ :.._ ' ' '-' " ' - -- RECORD OF SURVEY ..... ........... ALL CALCULAT!ONS PERFORMED BY-! B H ELECTRON!C-COMPUTER ................................................. -- ........ .. . - ......... E ' '- TRUE ..................................... : ......................................... DOG LEG -AS, DRIFT VERTICAL SUB DRIFT ..... TOTAL'COORDINATES ..... C L O'S U R E S SEVERITY -PTH A.NGL~ DEPTH SEA · DZREC ..................................... DtSTA;<CE . Ar,~GLE ~-" OF ' - -' - D,.-~flO T .... D ;4 D E G ° ..................... D t,~, S - - ---O---O- 0 ..... O.00 .... 106.00---bi 5! E ......... 0,,00 S ...... O.00 W ...... 0.00 S 0 0 O W .:-- 100- O i5--- 99,99 ..... 6,00 N 51 E ........ 0,27 N ..... 0,33 E ...... 0.43 N 50 59 59 E 0~250 200 0 15 199o99 93,99 N ~0 E .... 0.65 N ..... 0,5-5 E -- 0°85 N 40 "~ '" . 99 ........ ' ' 0,~0 3.~0 0 i5--. 299,:,9 __ la3,~ "t~l 2 E l~OS N ....... 0o57 E ....... !~22 N 27 ,q.'4 27 E. O~,l?l ....... 403 0 45 399°98 293.98 N. 7 E ........ 2038 N ........ 0~73 E -- 2°-%9 ,N 17 2 38 E O.5'01 50g 1 0 679,97 .. 393,97 N 8 E ............ 4,,11 N ....... 0,,97. f.. ....... 4~,22 Fl 13 19 31 g 0°250 600 C ~,5 _._ 599.96 .... 493.q6 N 64 E h.68 N _ 2.!5 E'. .... .. 5,~15 N 24 ~'3 33 E . 0o651 700 6 15 699.96 _. 593.96 S 78 E ......... 4.59 N. 2.-57 'E'" ....... 5.27 N 29 16 27 E 0,,57~, 800 0 30 799°96 693,96 N 58 E .... 5~06 N ___ '~...~.3i E .... 6,,05 9c0 O 30 _. 899.9.5 797,~,95 ...S 88 E. 5<,03 N 4.~9 E : ..... 6o5~ 'Q ..... 0 '~ ~ ................... ' ' " ' ' ...... ' ....... i, ~.. 999°95 893,,95 S 56 E 4.78 N ..... 4~55 E ..... 6°60 N 43 33 31 E 0~317 ~ 0 45 1099.94 993.9~+ S 39 ~ 3076 N 5.37 E 6:56 t,,' ~6 57 35 ~ OoE~a ',200 0 45 ~99.93 ]i093,9~ ..S 45 E 2.84 N ...... 6,30 E 6o91 N 65 42 26 E 0°079 LB,r)o O 65 ,1.299.92 !193.92 S 74 E ............2,q8 N 7,,55 E .... 7,95 Ft 7! 48. 50 E 0.376 '-- - .... '4~0 4' 15 1399.55 !29.3,65 N 61 E 6.07 N !~,,0q. E !5o29 N 65 35 59 E 3.757 ...... -- ...... ._ '500 7 45 1498.74 1392.74 'N /+2 E 16 09 hi ..... 2'~o06 E 23,12 N 55 5 I,. E .3 ~ " "'-' ~",'" '.'.SO& 9. 0 159.7.50 1491°50 N 28 E _. 29~91 N ...... 30~40 E ...... 42.55 N 45 23 25 E 2o2F.$ ..... L700 9 45 1696.06 1590.06 N 29 E '- 44.72 N ..... 38.61 E ___ .59o08 N 40 48 43 E 0.767 ,:.800 1..1 S0 1794.05 _.1688.05 N 28 E.'].-.-." 62°32 N ~7,97 E 78°65 N 37 S5 23-E 1.760 :g00 ~,2 45 1:89!.59 1785.59 N 29 E ..... 81.62 N _ _ 58.67 E 100,52 N 35 4Z .38 ~ _ !o2~7 ~000 15 30 I'9B7.95 1~q81.95 N 28 E ~05,,22 N ...... 7!,,22 E. .......... 127,,06 N 3.'+ 5 37 E 2o751 :'100 17 45 20a3°!9 !977.19 N 28 E ...... _]..,' !32~i4 N 85~53 E 157o40 N 32 54 5,5 E 2~250 .... _.. ;200 19 .30 2177o45 2071.45 N 28 E _ 151.51 N ~'.-.]-'-10!,20 E .... 190o~8 N 2,2 $ 22 E !,750 -- ~~ ............. _. _ _ -- 'R ECOR D "OF"-$UR~/EY .......................................... ALL_ CA'[,CiiC'AI;I6'N$-]_~FORHED BY '-[ B M .... ..... :-'.EAS, DRIFT DEPTH A~$GLE D M ?3oo 21 1.5 .'O 23 30 · ,:0 2.,5 15 26e0 28 0 2'700 2'7 !5 2ef,,,o 26 3,0 29,q0 2.3 45 BO00 31 45 3190 34 0 Z2'?g 35 30 3260 37 45 3390 39 30 34n0 40 30 35~0 41 30 ~...690 42. 0 37(',0 42 15 3ac,3 43 15 3t~(, ' 943 0 ,;0 44 0 4100 42 45 42 ?0 42. 15 a 3,2,") 42 0 4400 42 0 4 5 '.';~) 42 0 aSCO 42 0 4700 41 0 4q~O 4l 15 z, 900 4 1 30 5000 41 15 TRUE VERTICAL' .... ............ · ......................... DOG LEG ....... SUB DRIFT ToTA-I~'--COIERDINATES C L 0-$. U R E $ SEVERITY SEA ....... DIREC .................................... DISTANCE ..... ANGLE DEG/IOOFT DEG. D ,~,1 S 13~ 05 ~., ~ _. !5q.73 182.20 .. 234..,03 262.30 293,23 326.89 361.02 375.76 .3~;]. 19 437.27 475.28 _ .. 5!4.6-1 553oi8 ._ 592 639~61 67!,44 -- 712.29 . . 792.76 7?3.03 832,36 871 .69 910,.07 . 947,70 986.45 __ 1066,95 DEPTH 2270.65 2352.36 2452.81 2541.10 2630.00 2719.50 2807.17 2892.20 2975.11 3056.52 3088.15 3134.44 32!0.49 3285.38 3359.70 3433°72 3596,55 3579.69 365!~52 3725,96 3799.08 3873.39 3947.71 h022.O2 A096,34 4171.fll 4246.99 4321,~9 4397~07 2164.65'- N 30 2256.26 N 28 2346.81 N 29 2435,10 N 30 2524.00 N 34 2613,50 N 36 270!.!7 N 36 2786~20 N 36 2869,11 N 37 2050.52 N 36 2982.15 N 37 302~.44 N S5 310~,49 N 37 3179.38 N 35 3253.70 N 36 3327.72 N 35 54,00,55 t~ 35 ~472.69 N 34 3545.62 N 36 3619.06 N 37 3693.08 ti 37 3767.39 N 37 3~41.7! N 36 3916,02 N 36 -. 3990.34 N 35 4065.8I a 35 4140.99 N 36 4215~89 N 37 _. 4291.07 N 38 ......... 228.21 N .. 265,5! N 306.17 N 344.13 Fl 380,,23 N 419,14 N 461,71 N 506.37 N 553,35 N 572,91 N 60~,79 N 655,65 N 709.93 N 764,07 N 819.14 875~27 N 931,81 N 988.01 N 1042,22 N 1095.92 11A9.36 N !203,49 N 1257.62 N 1312.44 a 1366o18 N 1419,52 N 1472,44 N 1524,40 E_.. 226o91 N 3! 43 40 E 266.7t N 31 lO 15 .. E 309,34 N 30 52 !7 E 356.28 N 30 ~5 24 E 402,,01 ti 31 7 33 E ......... 440o48 N 31 36 44 E .... 49~.45 N 32 2 E 546,96 N 32 25 !0 E 602,72 fl 32 50 38 E 660.71 N 33 7 16 E 685.!4 N 33 15 35 E 723.27 N 33 24 15 E-:--'-- 783 ,09 N 33 42 1 E:'~._ 854.34 N 33 48 4 E 921.21 N 33 57 39 E 988,43 N 34 1 53 E 105(,.74 N 3/, 5 39 _ E 1125.14 N 34 5 19 E 119~.57 N 34 11 59 E 1262,38. N 34 2! 1 E ]329.54 N 34 29 3 E 1396.40 N 34 35 17 E !463~29 N 34 40 6 E 1530,!9 N 34 43 36 ..... E 1597.10 N 34 44 i7 _. E 1662.70 N 34 44 54 E 1728.62 N 34 47 46 . __ E 179~.84 N 34 52 39 E .... !860,68 N 34 59 17 .... SECTtC' D i $=, ,-, ~ "i E .. !,'-2,83 ..... 2i7,,6: E . .. 2,375 255.1' E ..... 1,798 295 E 2.736 ' '. " E .. 2,C(:,0 _._ 384,4.: E ...... !,17,.5 ..... E ..... 2.250 ..... 475:!C E 3.000 526.5' - _ _ E __. 2o3!~ .._ 58 E 1o605 ........ 6 :::. ,:-~ ,, E 5o919 652,2' E 3.097 6a9 5: E !.189 763.2} .... E 1.650 ........ E _.. 0.333 ..... 89~.22 E 0.716 953,7'- ..... E 1.O'~O 1 C, 2 5. -" ': E O.72b' ! C"-.; I. 57 E 1.721 1159oA9 E 1.426 12£5,09 E 0.53n., 129°~_ · 27 E 0.250 12,57.73 ............. '"~ ! 4-88 E ..... O.,.e,...; ..... E 0.659 1553.74 E 1o000 16!7.63 . . E 0,704- !652.07 E ..... 0,707 _ !7/,,7. ! i E .._ 0.707 ._ I812,07_ ALL CALCULATIONS PERFORatED BY ! B M EL£CTRON]C COMPUTER ............................... TRUE DOG LEG DRIFT VERTICAL DRIFT TOTAL-'¢O[DRDINATES ............ ..... ¢ L O S U R E $ -- SEVERITY A:';,.q L E D":PT H DIREC D I ST A""-" E ANG~ E DF--G/iOOFT ~' . .............. t ': %~ ~.. .. D M DEG. .......................... D P, . $ SUB 'I ~ 41 30 4471,97 4365~97 '200 40 45 4547.72 4441.72 '390 aO 30 4623.76 6517.76 ~6~0 39 45 4700,65 4594.65 :' 5 ~0 3~ 0 4779.49 4673.49 ~600 37 49 485~,.52 4752~5~ 5700 37 ~5 493&,12 4832.12 ,~,,, 36 0 5019,02 4913.02 :'9~0 35 45 500q.14 4993.14 5OC, O 90 0 5176.86 5070.g6 5!O0 z.O 0 5253~&6 5147.46 3200 42 0 52.27~78 5221~78 -;300 41 30 5402.67 5296~(,7 '400 41 45 5477,28 5371,28 55P0 40 a5 555~.04 5z~4?,04 5~(' 40 30 5629.0~ 5~23.08 7~ aO 0 5705.68 5599,68 5~00 39 BO 5782,84 5676,$4 7C'C0 Z9 0 5q37.72 5831 ,72 ~lna ~g 0 6016,52 ~910.52 7200 37 0 6096,38 5990.38 7300 3R 30 6174,65 6068,65 7400 37 15 6254,25 614~,25 7500 Z5 45 6~35~40 6229,40 76[~O ~5 45 641&.56 6310.56 7700 ~e O 6497,46 6391 7~OO ~. 45 6577,5g 6a71~59 7900 37 45 6656.66 6550.66 1628,75 N 1146~99 E t992~09 ~'1 35 9 13 g t679.22 N 11n7.86.; g 2056,90 N 35 16 ;uO .-= 1728,92 N 122q~10 E 2120.71 N 35 23 14 E 1777.43 N 1266.0! E 2182.21 N 35 27 39 E lg25.01 N 1304,53 E 2243~32 N 35 33 27 E _ 1872~05 N 1342.63 E 2~03.74 N 35 38 52 E 19!6.41 N 13~1.19 E 2362.27 N 35 46 51 E 1960.88 N 1~21~23 E 2421.76 N 35 56 3 E 2007.64 N ~463.33 'E. 2484.25 N 36 5 15 E 2055.41 N !506,35 ~ 254g~3~ N 36 14 i1 E 2104.35 N 1591~98 E.~ .... 26!4,75 N 36 24 g3 E .... 2152.81 N 1597,17 E,''L. 2680.59 N 36 34 18 E _ 2202.30 N 1641.73 Y_' 2746.89 N 36 42 1t E 2249~25 N 16q7.07 E 2~11.65 N ~6 52 19 ~ 229(.,75 N 1731.~6 E 2~7~.23 N 37 0 2.6 E 2342~20 N 17'76.~2 ~ 29~D.90 N 37 ~! 3 E 2Z~7,18 N i82!,79 E 3C02.93 N 37 20 57 E 2432.93 N 1~55.~8 E ' 3066,1i N 37 29 13 E 2z~77.43 N 19!0~48 E 3128~52 ~I 37 38 !5 E 2522,46 N 1952.~7 g 3189~g2 N 37 4~ 27 g 2565,75 N lg9~27 E 3249.65 N 37 51 24 g 2609.77 N 203~.29 S 3311.43 N 37 59 26 E 2652.57 N_ 2081.09 E 337.I.51 N 38 6 50 E 2693,1.6 N 2!23,12 f 3429,39 N 38 !5 0 ~ 2733,74 N 2!65,15 E 34~7.29 N 30 22 46 E 2773.07 N 220~,83 E 3545.26 N 38 32 17 E 28!2.33 N 2253,98 E 3604.11 N 38 42 39 f 2R50.89 N 2301,56 E 3663.95 N 38 54 53 ~ Oo7~7~. 0,998 0,697 ..... 0,750 1,859 0.500 1.728 0,956 2.250 2,105 .. 0.500 - _ 0.7t0 I .655 0 o 697 ! 0.500 O,80G 1.597 ... I.!7t 1.6:20 1o250 1,5!4 0.000 ! .!98 _ ...956 1.570 · . SECT l O;,i DiST .... r !S77.g4 ~941~30 2~05~a2 20,55.56 '"' 17 2!g?:51 2249.33 2307.70 ,.-9.77 2493~63 25S~33 2626,3° 2'5=.'_,53 2757.;." 2 ~ g 6.5 ! 2950°02 3076~3! 31Z7~6~ ~197 3259.81 3220.25 357~,64 3~37~S2 3495.~0 35=a 3616~77 TRUE ~^S. DRIFT VERTICAL EPTH ANGLE DEPTH RECORD OF SURVEY · ALL CALCULATIONS PERFORMED BY I g M ELEC-TRON'I¢ CO.'MPUTER -. SUB DRIFT SEA DIREC DEG, 6735,73 6629,73 N 51 6813,99 6707,99 N 52 E . 6892.2'5 6786.25 N 54 E 6968,85 6~62,85 N 54 E 7044.04 6938.04 N 54 7120.64 701z~.64 N 56 7197.52 7091.52 N 55 E 7274,41 716~.41 N 55 E 7352.94 7246,94 7432,01 7326.01 N 56 E 7511,34 7405.34 N 57 E 7591,21 7485o21 N 56 E 7671,33 7565.33 N 57 7750.67 7644.67 N 57 E 7~0,53 772a.53 N 58 7gI0.6~ 7804.66 N 57 7990,78 - 7~84~78 N 58 BO7!-17 7965,!7 N 58 8151.55 8045.55 N 58 E · 8231,42 8]25o42 N 59 E ~311.02 8205,02 N 6! E ~390,~8 8284,~8 N 60 E B470.22 8964.22 N 62 E . . 8627.79 8521.79 N 65 E ~708,18 8602.!8 N 66 E 8788,04 8682.04 N 66 8867~9! 8761.91 N 66 E ~948,55 8842,55 N 68 E D .,4 TOTAL COORDINATES 288'9,38 N 23a9,14 E 2927.71 N 2398.19 E 2964030 N 244P, o55 E 300200,9 N 2500.56 E 3040.84. N 2553.90 E' 3076,78 N 2607.19 E 3113.46 N 265q,57 E 3150o!3 N 2711.95 5 3184,75 N 2763.28 E 3218,99 N 2814,03 E 3252,14 N 28~5,09 E ... CLOSURES O I STANCE ANGLE D M S 3723,84 N 39 37~4..55 N 39 '3844..80 N 39 3907,08 t'~ 39 39"1:03 N 40 4032°87 N 40 4094.75 N 40 4156o69 N 40 4216o44 N 40 4275.59 N 41 a334.19 N 41 3285.80 3318,38 3351,54 3533,43 3416,02 3447,72 3479,2~ 3510.76 3541,76 357t.ll 3601.20 3629,78 3655°37 36a0,81 3705,00 3729.48 3753.96 3776.!! 2914 2965.16 E 3015.21 E 3067,25 E 3!!7~43 E __ 3!6,qo!7 321~ .61 E 3269.06 3320.64 E 9373,58 E 342~,?0 E 3479.4 5 E 3536.95 ~bgl ,'49 E 3645,83 E,"' 439~ 44 N 4t 4450.15 N 41 4508..92 N 41 4566,80 N 42 4624.67 N 42 4632°32 ,N 42 4739.,69 N 42 6 43 !9 19 33 26 47 32 I 33 !6 37 30 16 43 30 56 48 9 35 22 46 34 39 46 57 59 8 !! 38 23 0 34 49 46 17 N 3700.81 E N 3755,78 E N 3810,6! E 4797,11 N 42 57 29 4854,.c7 N 43 9 !6 4912.63 N 43 22 15 4973.32 N 43 34 9 502g.!1 N 43 ~7 19 5086,45 N 44 3 23 5142.68 N 4~ !7 46 5!97~99 N 46 32 19 5254,05 N 44 46 44 5310.19 N 45 0 50 5364~8 N 45 15 38 SlC',.9 3~ 30 ¢,200 38 30 F. 3OO 40 0 84C0 41 15 8500 4O 0 8600 30 45 57C;0 S9 ~5 8300 3S 15 Sg~O 37 45 "'~""9 37 30 91~0 37 O ~200 36 45 9300 37 30 ';40O 37 0 36 a5 ~7on 36 30 98oo 3,6 30 9900 37 0 .3n3o 37 15 Ol O0 37 0 ¢'2¢0 37 30 ~., 0300 39 0 0400 37 0 ,,500 35 30 3500 37 0 CTOO 37 0 0~03 $& 15 DOG L~ SEVERITY DEG/!0OFT 0.000 0,971 1,245 1 · 500 1.250 l,g05 0 O.OOO 1 -627 0,,500 O,660 0,735 0,650 0.750 0.785 0,650 0.598 0.250 O.O00 0,780 1,233 0.653 1.3-!O 2, S.t'5 2.095 0.7~0 O,500 0.0SC !.409 SECT ! O:'; D i 5TA:;C: 5677,9! 3740,02 3~0!.95 393!~47 3995.!5 4058.63 a!22~!! 42~4.08 4304~23 4Z6ZoS4 4422,96 44S5~!0 4601~5i &653,45 4719,05 ~777o65 45~6~75 4Sc-5,76 4954°65 50!3,75 5073.64 5151.23 5187~84 5245o!2 o. ALL. C^LCUL,~T'!O~"P R~O~D OF. ,SURVEY .... - .............. .............. . ERFORF*,ED BY..! B t-t EL'E'~'~6'k-i~']:CO;4PUTER TRUE ........................................................... " 'E,AS, DRIFT VERTICAL '-SUB .... DRIFTj:_"-..]~O'TA~ .... COORDIt~ATES C L 0 S U R E S ~E~TH ,,,~, - --. __. "- -- -- DCG LEG ..... u~E DEPTH SEA D!REC ........ ' .... - ...... .. _ D q - '' ' ............................. DISTA~CE A¢~GLE DEG/IOOFT ...... · . . .. DEG, .~ . ". ..... . { . .. - .......................................................... D M ..... .. - , . . 0 ,J 36 ~0 902R,9~ 8922,9~ N 68 E 3798,39 ~.." '5', . - ..... 1309 3B 0 9358.0~ 9252,0B N 69 E ...3882,63 ~.._ 40;6,80 E ._ 5629,85 N 46 2~ 50 E .. 1,630 _.. 1400 33 45 944~,18 9335,18 N 69 E ..... 3902,54 N_ 4128,67 E . 568!,18 ¢~ 46 36 46 E 0 750 1590 36 0 9522,08 9416,08 N 68 E 3924 56 N 4!63 17 E 5735.95 N 46 49 36 E Z.32! -,; 9 39 0 9599.80 9493,80 ~I 70 E 3946 0B ¢~ 4242 31 E_._ 5793 85 N 47 4 18 E 3,237... 17,.,O 39 0 9677.51 9571,5! N 68 E 3969,66 N 4300~66 E... 5[~52~68 N 47 17 30 E ........I~259 ........ 5052.07 1800 3p 0 9755,2B 9649.23 N 70 E 3991.18 N__. 4359,~9 E 5910,78 N 47 31 38.5 _. !~259 .... 59!,~.47 1905 40 0 _.9835,66 9729.66 N 70 E 40~4,27 N ..... 442'3,2~ E.,-" 5973,21 N 47 46 29 E 0 952 5~'73 IO . .. - .- t. -" - .... ozror. otz CLOSURE FE T AT '47 45 29 k ..... .... - .............................. . ........... ...... . ...... .. . ..... ................... . . , .... . .... .... ................... . ........... .-. ' ........ 7 .................... ' ' ............ _ _ - . ........... - ...................... _ .... . ............................................................ . ....... -. ........................................... ........................ ~ ................ - ......................................... _ _ - ............................. ~ . __ _ ....................................... ....... . ............ - ............................... _ _ ._ _ ....................................................................... ........ · ........7 .................................. -- ................. ] ._ - ....................... ...... _ ......... ~ ........... ' ........ ~ ........................................... ~._ ~ ........ . .............. . ................................. ' ................................................................ .............................. .............. -- ............................ .. _ ..... . .......... . . ._ . _ ................. ' . ._ - ............. ...... ................................... ' ....... ..... _ ............................................. ...... .. ............ - .... · ..............k .............. - ................ . ............. - -. ........... ............ "-~ ............ , ............. · ..... .......... ................................. . -- .............................. ,, .............. . ._ -'TANSEN r T'A[-ME TFIOD ..... PAGE 1 -NEASURE0'-G'-'- E' V--i-'-A--"T .... I O-'N DEPTH ANGLE DIRECTION TVD T-0 T"~ E-C~]-~-~"~'i'F~ A"} ~ s SUB SEA LATITUDE DEPARTURE C L 0 S U R E S DOG LEG SECTION DISTANCE ANGLE SEVERITY DISTANCE ORIGIN LOCALE · 10~ O-1 200 0 1 --' 3O0 0 1 400 0 4 ......... 5'00 1 500 O 4 -- 730 ............0 .... 1 800 0 3 9¢00 0 30 ' lOOO 0 15' 1 lO0 0 45' 1200 0 45' 13C0 0 45'--'-- 1400 4 15' 15CO 7 45' 1600 9 O' 1700 9 45' 1800 11 30' 1900 12" 45' 2000 15 30 ' - . . __ 2100 17 45' 2200 19 30' 2300 2l 1 2400 23 3 .... 25 O0 ...... 25-'1 26C0 28 2700 .... Z? 1 2800 26 3 2900 ..... 28 '4 3000 31 45' ..... ~ fo'b ..... -'~'~. .... 0" ....... D AT MD = 5' N 5 1E 5' N 30E 5' N 2E 5' N 7E O' N 8E 5' N 64E: 5' S 78_ O' N 58: 0.00, TVD = 0.00, LATITIJDE = 0.0 99", 99 -'6:'00 0'. 27N 0.33E 199.99 93.99 0.65N 0.555 299 ,'9~----'19 3-;'9 9 1.08N O. 57E 399.98 293.98 2.38N 0.73E 4P9.9'/ .......... '393:'~7 4. tin 0.97E 599.96 493.96 4.68N 2. 155 -699.96 -593.96 4.59N 2.575 799.96 693.96 5.06N 3 . 3'lE 793 ,-95 5-"03N ......... 4. 19E 893.95 4.78N 4.55E 993.94 3~"16N 57; 37E 1093.93 2.84N ..5';.30 E ...... 1i93.92 ........ 2,48N ,, 7.55E 1293.6,5 6,07N 14.04E i6.'09N 23'-' C6E 29.91N B0.40E 4z~,72N 38.61E ....... S'88 ............ 899.95 S 56 - 999.95 S 39" 1099.9z+ S 4'5: 1199.93 -S-74- 1299.92 N 615 1399.65 N 42E 1498.74 1392.74 N 28E 159/.50 1491.50 N 292 1696.06 1590.06 N 285 1794.05 1688.05 62.32N 47.975 N 295 1891.59 1785.59 81.62N 58.~7~ N 28E 1987.95 1881.95 105.22N 71.225 ....... Iq '28E 2083.19 ..... 1977~i9 ...... 132' 14M .... 85.53E N 28E 2177.45 2071,45 161.61N 101.20E b' N 3OH 2270.&5 2164.65 1'93. OON 119.335 O' N 28E 2362.36 2256.36 228. 211.~ 138.05E 5' ...... ~ 29E 2452o'81 2346.8i"~ 265.51N 158.73E O' N 30E 2541.10 2435,10 306.1TN 182.205 5' .......N 345 ........... 2630.00 .......... 2524*00 ..... 344 ~'13N 207.80E ....... O' N 36E 2719.50 2613.50 380.23N 234,03E 5' lq 36E 2807,17-. ..... 270~,17 ..... [ .... -419.14N 262,305 N 36E 2892.20 2786,20 461,71N 293.23~- N'"37E 2975'1! 2~'g-9%'i 1 50'6'~-37N ...... 32~-.'89E O, DEPARTURE = 0.00 0.43 N 51.005 0.000 0.43 0.85 N 40.505 0.O91 0.85 1.22 N 27.74E 0.'120 1,15 2,49 N 17,04E 0.501 2.14 4.22 N 13.32E 0.250 3.48 5.15 N 24.64~ 0.850 4.74 5.27 N 29.27E 0.574 4.99 6; 54'" N' ..... 39.79~' 0.292 6.48- 6.60 N 43.555 0.316 6.58 6.5~ N ~.95~ o.s~6 ~.51 6.9t ~ ~5.70~ o.o78 a.57 7,95'-"~ ~l.81E 0.375 7.26 15.29 N 66.59E 3.757 14.48 28.12 N 55.06E 3.978 27.89 42.65 N 45.47E 2.382 ~2.6! 59.08 N 40.815 0.767 5-2.65 78.65 N 37.5.~E 1.759 77.41 100 ~. 52'"-N"' 35.715 1,267 9 ;-.~. 30 127.06 N 34.095 2.760 123.45 ....... 157"40-N"'32,91E 2.250 152.14 loo.68 t~ 32.o5E 1.75o 18~..,.55 226.91 N 31.72E 1.883 218.07 266.71 N 31.17E 2.375 255.59 309.34 N"30L87E ..... 1'797 .... 295.98 356.28 N 30.75E 2.786 346.68 402.01 N 31.125 2.000 385.15 ...... 446-48....N...31.o61~ ..... . ....... 1._.174 42~].83_ aofi..~ N ~;,03E 2,250 475.92 , .~4.6o96 N 32.4iE 3.000 527.44 602.72 N 32.845 2.314 582.37 PAGE SECTIO~ ~ STANCE~ ~ r~_N~?_!?_IAL METHOD MARATHON OIL COMPANY TBU D-26 06/14/74 MEASURED D E V I A T I 0 N TOTAL COORDINATES C L 0 S U R E S DOG LEG "DEPTH ....... ANGLE DIRECTION ................ TVD ............... -SU~ .... SEA ..... -'-~ ~'i- l T OD'E ...... DEPARTURE ..... ~)-i-S T'ANt E ........... ~NG'L'E ........~'E'VER I T-Y" '~ I ---3200 3240 37 45 ' 3300 39 30 ' 3400 40 30'. 3500 41 30' ...... 3600 3700 42 15~ 3~00 43 1 5' .. _ 3~CG 43 O' 4000 44 0 4100 42 45' 4200 42 15' 4300 42 O' 4400 42 0~ ..... 4500 ....... 42 4600 42 O' 4700 41 O' 4800 41 15' 49'30 41 30' 5000 ~1 15' - -_ 5100 41 ~0' 5200 40 45' 5300 qO 30' 5400 39 45 ' 5500 ...... 38 ' O' ........ 5600 37 45' 5700 37 15' 5800 36 O' -3b' ...... i<~"'3~C ............. 3056~-52 .... k"9~0'~"5~ ......... 5'5~"~'_~5N .........361',6'2E ......... '8~7"i-'~ .... ~'$. 12E 1.604 N 37E ......... 3088.15 2982.15 .572.91N 375.76E .... 685.1~ N 33.25E 5.819 N 36E 3134.44 3025.44 ...... 603.79N ....... 398.19E 723.27 N-33.40E-' 3.096 N 37E 3210.4~ 3104.49 655.65N 437.27E 788.09 N._33.70E. !.188 .... N 35E ................. 3285.38'~' 3179.38 .......... 709.93N ......... 475.28~ ........ 854'34"N 33.80E 1.649 N 36~ - 5 · . ,: 3359 70 32.3.70 764.07N 514.61E 921.21 N 33.96E 0.832 N 35E .......... 3433.72 3327.72 ............. ~19.~4N ..... 553.18E .......... 988~'43"'fi .... 3~.03E 0.715 N 35E 3506.55 3400.55 875.27N 592.48E 1056.94 N 34.09E 1.CO0 ---- . N 34E 3579.69 3473.6~ .......... 931.81N 630.61E .... 1125.14 N 34.0~E--'-- 0.727 3651.62 ....... 3545.62 988.0iN 671 44E 1194 5~ N 34.19E 1.701 3725.06 3619.06 !042.22N T12.29E 1262,38 N 34.35E 1.426 3799.08 3693.08 i095.92N 752.76E 1329.54 N 34.48E 0.500 ..... . .......... , ...... . 3873.39 3767.39 1149,36N 793.03E 1396.40 N 3/~.60E 0.250 3947.71 3841.71 1203.49N 832 36E 1463 29 N 34.66E ...... 0 669 4022.02 3916.02 1257.62N 8.71.69E 1530.19 N 34.72E O.O00 4096.34 3990.34 1312 44N 1"9.i0 07E 1597 10 N 34 73E 0 669 4171.81 4065.81 1366.18N 947.70E 1662.70 N 34.74E 1.000 N 36E N 3i'E N 37E N 37E N 36E N 36E N 35E N 35E N 36E 4246.99 N 3'?E ....... 4321.89 ....... N 38[-: 4397.07 N 37E 4471,97--- N 38E 4547.72 N 39S 4623,76 N 39E 4700.65 N 38F 4779.45 N 39E ......... 4858.52 N 39E 4938.12 ..... 66_~.27 700.64 764.44 -- 829.06 894.56 960.13 026.96 093.20 --'-59C0 .......... 36 -~5' '-' N'42E 6C00 39 O' N 42E 61 o o ' '4 d---o-, ...... N .... ~ 2 e 4140.99 1419.52N 986.45E 4215,89 ~472,44N ..... 1026.'33E 1794.84 N 34.87E-- 4291.07 1524,40N 1066.93E 1860.6~ N 34.9~E 4365.97 1517.32N l106.~OE 1926.9C N 35.05E 4441,72 1628,75N 1146,99E 1992.09 N 35,15E 4517o76 1679.22N 1187.86~ 2056.90 N 35.27E 4594,65 1728.92N 1228, IOE 2120.71 N 35.38E 4673.45 1777.43N 1266,01E'---2182.21 N 35.46E 4752.52 1825.01N 1304.53~ 2243.32 N 35.55E 4832,12 1872.05N 1342.63E 2303,74 N 35.64E 1916.41N 1381,19~___ 2362.27 N 35.78E 1728.62 N 34.79E N 41E 5019.02 4913.02 5099. I4 4993.14 ...... i960.88N 1421.23E 2421.7~ N 35o93~: 5176.86 5070.86 " 2007.64N 1463.33E 2484.35 N 36.08E 5253,'46 .... 514'7,45 ~ b' 55'~ ~ i N'---Z 506';'~, 5 ~-----25-6 8';-30--N--3-6 ~.-23-E-- 0.703 ._ 0.706 O. 7O6 0.706 0.997 0.697 0.75O 2 1.859 2 ._ .0.662 2 0.500 2 _.1.727 2 0.956 2 2.250 · 2 1.CO0 2 1161.20_ 1227.88 1293.93 -_ 1359.67 1~25.i7 ~_ 1555.93 161'~.92 1684.46 1749.56 1814.5] ._ 187g.63 1943.96 2000.14 071.34 132.01 192.51 ._ 252.33 310.70 370.23 432.84 496.80 TANGENTIA MEASURED DEPTH A ............................... D I R E C T I 0 N A L S U R V E Y PAGE 3 ._L__~!..E_~_H. OD MARATHON OIL COMPANY TBU D-26 06114174 D E V I A T I 0 N TOTAL COCRCINATES C L 0 S U R E S DCG LEG SECTICN NGLE .... DIRECTION .............. TVD ..............'~'OB-'-~;EA-- -£-ATITODE ........ DEPARTURE'-- -D'isTANcE ................ ~NGL~' .... --S'~'VERiTY-~Ji'ST~'NCE- '6"20 o 6300 -- 6400 ....... 6500 -6600 ........... 6700 q2---b, N 43E 41 30' N 43E _ 41- 45' .... N 42l: 40 45' N 44 E 40 30' N 43E 40 O' N 45E 6~00 ......... 39-30'~ ...... ~q'-45E 6900 39 30' N 44E 7000 39 0 ~ N 45E 1100 38 O' N 43E 5327 5402.67 54.'77.28 ...... 5553.04 5629.08 5705.68 5782.84- 5860 5937 6016 -- '7 4 o 0- 7500 1600 7700 ~._ /800 7900 --.. 8000 8100 5200 8300 ---'8400 8500 .... b6'oo~ 8700 8800 6900 9000 9100 .--~ 2'0 o 1290 ..... 37 .....ii" ....... -N '44E ........ 6096 7300 38 30' N 45~ 6114 45E ..... 35 45' N 46E 35 45' N 46E 36 0 ' N 48E '36 45' N 49E 37 45' N 51E 37- 45' "'N 51E 38 30' N 52E 38 30' N 54E 40 O' N 54E 41 15' N 54E 40 O' N 56E 39-145, ...... N '55E .... 39 45 ~ N 55E 38 15' N 56E 6254 6335 64 16 6497 6577 6656 6735 6813 6892 6968 7044 7120 ~ 197 7274 7:352 37 45' N 56E 37 30' N 57E 37 0~ N 56E 3 6--4 ~-i- ...... N"-5 7 [2 5296.67 2152.8iN 1597. 17E 2680.59 N '36.57E 5371.28 ......... 2 5447.04 2 5523.08 2 5599.68 2 5676.84' 2 2.10/, 2563.48 0.500 262g.51 202'30N ..... 1641.73E' "2 746-. 89'-N' 36'~ 70E ..... C.709 .... 2695'76- 249.25N 1687.07E 2811.65 N 36.87E 1.654 2760.89 296.75N 1731.36E 2876.23 N 37.01E 0.697 2825.61 342.20N 1776.82E 2939.90 N 37.18E 1 385 288~.82 387.18N .... i 82i. 79E ....... 3002.9 3 '"N -3'7.34E ..... 0 "50'6 ..... 2'95":'.'3'5- .01 5754.01 2432.93N 1865.98E .72 5831.72 2477.43N 1910.48E °52 5910.52 2522.46N 1952.47E °38 5990-38 ..... 2565.75N ........ .65 6068.65 2 .25 614~',25 .... 2 .40 6229.40 2693.16N ..12123.12E .56 6310.56 ..... 2733.74N' 2165.15E ...... .46 6391.46 2773.07N " 2208.83E .59 6471.59 ......... 2812.33N-' 2253.98E -' .66 6550.66 2B50.85N 2301.56E .73 6629.73 2889.38N 234.9.14~ 3066.11.N .... 37.48E 0.636 3015.82 3128.52 N 37.63E 0.806 307').68 3189.82 N 37.74E 1,596 3141.03 1994.27E 3249.65 N 37.85E 1. 170 3201.08 609.77N 2038.29E 3311.43 N 37.99E 1.620 3263.26 652.57N 2081.,09E 337 1.5 '1'-~'-'38'~' 1 ~i F_' ...... i ~.'249 ..... 332"3 :'7'2-- 3429.39 iq 38.25E 1.6!3 3382.I2 . 3487.29 Iq 38.37E 0.COO 3440.51 354.5.2~ N 38.53E 1.198 3499.29 .. . 3604.11 N 38.71E 0.956 3559.11 3663.95 N 38.915 1.570 3620.23 3723.84' N-'39~ i IH 0.000 ........ 363!.36 .99 6707.99 2 .25 6786.25 2 .85 .'o4 s · 64 3 .52 3 .4I 3 .94 3 7432.01 3 7511.34 3 7591.21 3 767'£=Y~ ....... 3 6862.85 3 6938.04 7014.64 7091.52 7168.41 7246.94 7326.01 927.71H 2398.19E 3784.55 N 39.32E gs4.aoN 2448.56E 3844.80 N 39.55E 002.08N 2500;56E 3907.08 N 39.79E 040'84N .... 25513.90E ...... 3971.03 N .... 40.02E--' 076.78N 2507.19E 4032.87 N 40.27E ll3,~oN ...... 2659.5'TE---4094.75'N'-40~5OE !50.13N ........ 2711..5~9 ~ 4156. 184.75N 2763.28E ,2~6. ~-4 N 7405.34 7485.21 756'5',' 3'3 · 252.14N--'2865.09E ......... 4'33'4. t 9:'N 41.3 7E o.a59 285.80N 29l~.98E 4392.44 N 41.575 0.7~5 318'3BN .... 2'96'5-;-1'6'E'---4450:'"15 N 4t. 7-~: 6~'~'~'6 0.-q71 3743.44 1.244 3805.33 1.500 3869.23 1.249 3934.7'7 1.804 399 E . _--',9 0.688 4061.83 0.000 4125.26 1.626 4186.53 O. 500 424 7.13 . . -- 4307.2! 4366.78 442 5.84 PAGE 4 TANGENTIAL METHO0 MARATHON OIL COMPANY TBU D-26 06/I4/74 MEASURED D E V I A T I 0 N TOTAL-COORDINATES C L 0 S U R E S DOG LEG SECTION DEPTH ...... ANGLE ..... DIRECTION ............... TVD --SU~ ..... SEA LATITUDE .... CEPART'URE .... D-I sTANc ~ .......... ~,~'L E SEVERITY '~ISTANCE- -- '930 94 C 9 50 960 970 980 990 1000 _. iOiO 1020 -- 1030 1040 1050 1060 -- 1070 1080 1100 -'I !10 1120 __ 1130 1140 --1150 1160 --il 70 1180 --1190 (] ......... 37"30" ......... N .... 57E ....... 7750.'67 762~4'$~'? 335[.54N .... 3016.2iE ....... 4'508.92' ~,~ ..... 41"i-9~'g .... 0'~756 ..... 4'4'~5"'9~- 0 .......... 37 O' N 58E "1830.53 7724.53 3383.43N 3067.25E 4566.80 N 42.19:~ 0.785 4545.t5 0 36 45' N 57E ........... 7910.66 7804.66 ........... 3416.02N' .... 3117.43E ........ 4624.67 N"42.BSE ............ 0.650 4604.21 0 ......... 36 45' N 58E 7990.78 7884.78 3447. 72N 3168. ITE 4682. 32 N 42. 58E 0.598 4663.09 .... 0 37 O' N 592 8231.42 8125.42 3541'~76N 3320.64E 4854.~7 N 43.15E 0.779 4N39.20 0 37 15' ............ N 6'IE 8311.02 8205.02 3571.I1N 3373.58E 4912.6~ N 43.37E 1.232 4898.i2 ............. 0 37 O' N 601~ 8390.88 .......... 8284.88 ......... 3601.20N'-3425.70E ...... ~970.32 N 43.56E 0.653 4956.94 0 37 30' N 62E 0 ......... 39' O' .......... N"'66E 0 37 O' 0 36 30 ' 0 37 0~ 0 37 O' 0 36 15 0 ......... 36 30 3 36 0 0 35 0 0 34 30 0 33 0 0 33 45 0 36 0 0 39 0 o ..... 39 o 0 39 0 5 40 0 N 65E N 66E N 66E N 66E ' N 68[: ' N 68E ' N 68E ' N 6fie ' N 68E ' N 69E ' N 69E ' N 68E ' N 70E ' N 68E ' N 70E 84.70.22 8364.22 3629.78N 3479.45E 854.7.93 8441.93 : 3655.37N 3536.95E 8627.79 8521.79 3680.81N 3591.49E 8708.18 ......... 8602.18 3705.00N .... 3645.'83E ..... 8788.04 8682.04 3729.48N 3700.81E 8867.91 ........... 8761.91 ............. 3753.96N'?.~3755.78E 8948.55 8842.55 3776. I IN' ".:3810.61E 9028,.94 .... 8922.94' ....... 3798.39N .... 3865.76E 9109.84 9191.75 ...... ')274.17 9358.03 9441.18 9522.08 9599.80 9617.51-- 9755.23 5028.1i N 43.78E 5086.42 N 44.05E 5142.68 N 44.29E 519'7.99 N 44.53E 5254.05 N 44.77E 5310.19 N 45.0tE 5364.68 N 45.26E 5419.58 N 45.50E ' N 70E 9835.66 9003.84 3820.4IN 3920.26E 5473.94 N 45.73E 9085.75 ...... 3841.89N ..... 3973.44E' 5/J2 Y. 06-]',~ '45.96E-- 5579.60 N ~6.18E 5629.85 '"M- A'6.3 S E S681.I8 N 46.61E --. 5735.95 N 46.82E 5793.85 N 47.07E 9729.66 9168.17 3863.11N 4025.96E 9252.03 3882.63N 4076.80E 9335.18 3902.54N 4 128..67E 9416.08 3924.56N 4183.17E 9493.80 3946.08N 4242.31E 9571.51 3969.66N 4300.66E 9649.23 3991.18N 4359.79E 5910.78 N 47.52E 4014'*"27N 442'3-. 21E' '5973 .'2i'-~]--~ 7'~-7 7 E 1.309 5015.95_ 2.894 5075.72 2.092 5133.20 0.779 5t85.70 0.500 5246.86 0.000 5304.03 __.1.409 5359.51._ 0.250 5415.33 0.500 547(].48 --- 1.000 5524.30 0.500 5577.45 1.599 5628.22 0.?50 ~6BO.O1 2.321 57~5.16 3.237 5793.42 1.258 5852.47 1.258 5910.73 0.952 5973.21 CLOSURE 5973.21 N 47- 46' E DIRECTIONAL SURVEY . 'TANGENTIAL ~EfbCD NEA DEP TH T 0 T'-J'L-~C~]~-RS'i~ 'N'~ T E s ,',i, D- T V D I'VD SUB SEA LATI rUDE DEPARTURE DIFFERENCE VERTICAL CORRECTION 10 11 12 13 14- 15 16 1'7 18 2O 21 22 23 2,4 2 2 2 2 3 31 3-2 06 206. 06 306. 06 406. 06 50(',. 06 606. 06 706. 08 '806. 05 ..... 906. 06 1C06. Ob 1106. 06 1206. 06 1306. O0 100.00 0.67N 0.55E 0 O0 200.00 1.16N 0.58E 0 O0 300. O0 2.49N 0.74E 0 O0 qO0.O0 4.15N 1.04E 0 O0 500.00 4.68N 2. 175 0 O0 bUO.O0 4.62N 2.62E 0 O0 ~'30. O0 5.05N 3.37E ' 0 O0 8,00. O0 ............ 5.0 IN 4.21E O0 900. O0 4.72N 4.60E O0 1000.00 3.71~ 5'.'43E O0 1100.00 2.82N 6.37E (lO 1200.00 2.70N 7.95E 1406. O0 1300. O0 6.71N 14.61E 1506.00 1400.00 17.11N 23.60E .,, '". O0 ........ 1500.00 31.18N 31.11E ,., O0 1600.00 46.50N 3~o56E O0 1700.00 64.68N 49.28E O0 1~00.00 85.15N 60.55E O0 1900.00 110.32N 73.93E O0 2000.00 139.27N 89.325 O0 2100.00 171.22N 106.75E O0 ..... 2200.00 --206.57N 126.54E' O0 2300.00 24.6.20N 148.02E O0 ..... 2400.00'- 290.01N i72.87E O0 2500.00 333.flSN 200.89E O0 2600.00 374.78N 230.07E O0 2700.00 41fl.62N 261.92E O0 2800.00 469. lqN 298.835 O0 2900.00 524.20N 339. $3E 06 O7 09 1606. 10 1706. 12 1806. 15 1906. 19 2C06. 24 2106. 31 2206. 39 2306. 48 2406. . 560 25~6. 673 ~606. 785 2706. 899 2806. 017 2906. 38 3006. 63 3106. 0 0 0 0 0 0 0 0 o o 0 0 1 1 3 2 4 1 6 2 9 3 13 4 18 5 25 7 33 8 42 9 54 12 67 13 79 12 93 14 111 18 132 21 ' 1.57 25 O [ R EC T I ON AL S U R VE Y ......... ! N T ~RPL1£'A T E'D -V AE'[JE.~" FOR EV~'I~"' 1 PAGE MARATHON O[ L COMPAN?----?BO .... D='~ ......................... ~'~7-I~-7"~"2~- ................................................................. ~'~NGENTI A'[-'"~-f-~.~-- ..... ~r--ASUaEP .......................................................... T 0 ~ A iZ-"Gb-~R ~ [ kiAT E S DEPTH TVD SUB SEA LATITUDE DEPARTURE 3394 3206.00 3100.00 652.59N 434.97E 3528 3306.00 '" 3200.00 ........... 724.95N ........ 4~6,19E 3663 3406.00 3300.00 798 52N 538 73E 3799 3506.00 3400.00 874.'84N .592.17E 3937 3606.00 3500.00 952.36N 645..54E 4074 3706.00 3600.00 ~.028.15t~' 70lo69E 4209 3806.00 3700.00 1100.89N 756.51E 4344 3906.00 '3600.00 !173.1tN , 4478 4006.00 390U.00 1245.95N 4613 4106.00 4000.00 1319.31N 914.89E - 4745 4206.00 4100.00 1390.43N 965.32E ~ 4879 4306.00 4200.00 1461.21N ..... '1017.87E - _. 5012 4406.00 4300.00 1530.10N 1071.68E .: 5145 45L) 6.00 4400.00 1600.42N 1-124.85E " 5277 4606.00 4500.00 1667.43N 1178.31E _: 5407 4 ~06.00 4600.00 ........... 1732.21~ ...... 1230.68E 5534 4806.00 4100.00 1793.41N 1278.94E 5660 4906.00 .... 4,qO0.O0 ...... 1853.07N 1327.26E 57~4 5006.90 4900°00 1909.27N 1374.98E 5909 5106.00 ....... 5000.00 ......... lg65oOON ....... 1424.94E 6038 5206.00 5100.00 2025.81N 1479.69F 6171 5306.00 5200.00 ....... 2090.01N ' 1538.60E 6304 5406.00 5300.00 2155.01N 1599.15E ....... 64-38 5506.00 .......... 5400.00 ...... 2220.09N ..... 1658.92E 6570 5606,00 5500.00 2282.33N 1717.92E 67GC 5 106, O0 5600.00 23/,2.38N 1777.00E 6830 5806.00 5700,00 2400.91N 1835.05E .... 6959 5906.00 ......... 5800,00 ..... 2,'t59.27N ........... 1892,31E 7087 6006.00 5900.00 2516o45N I946.86E 721-2 6106.00 ......... 6000°'00 25'7 i-~-[6N .... 1999,'68E ME-TVD VERTICAL DIFFERENCE CORRECTION 810.28E 863.2iE 188 31 222 ................ " ........ 34 257 35 293 36 331 38 368 37 403 35 438 35 472 34 507 35 539 32 5'73 34 606 33 639 ' 33 671 32 701 728 754 778 8C3 832 865 898 932 964 9'94 024 1053 1081 1106 30 27 & 24 25 33 33 34 32 30 30 29 28 25 DIRECTIONAL SURVEY PAGE MEASURED DEPTH 7339 6 7464 .................. 6 758 ........... ? 71 783 809 82 1 834 ........ 84~ 861 ~.~ ~ 6 _ .. 949 ~61 ~6 999 iOll I037 1049 1062 1074 i08? '? 6 1 6 6 6 2 6 8 6 g 7 1 ................. 7 I 7 0 .... 7 7 7 3 ................... 7 8 7 4 7 g T 4 7 3 8 8 8 4 8 9 8 6 8 3 8 7 8 2 8 7 8, I 9 5 9 06/14/74 ............. TO(AL 'CO'oP~D i N'ATES M ......... _I'VD SUB SEA LATITUDE DEPARTURE OI , . _ E-TVD F FER ENCE . C CR TANGENTIAL MET POi] TICAL RECTION 206.00 6100.00 2626o63N 2055.15E I1 506.00 ............ 6200.00 ......... 2678.4'5N ---'2107.89E-- 11 406.00 6300.00 2728.46N 2159o67E 11 506.00 ............ 6400.00 ..... 2777.25N ...... 2213.64E .12 606.00 6500.00 2826.17N 2271.08E 12 706.00 6600.00 2874.89N 2331.25E 12 $06.00 6700. O0 2923 o79N 2393 . 19E 12 906.00 6800.00 2971.08N 2457.89E 13 C06.DO 6900.00 3021o23N 2526.91E 13 10~.00 7000.00 3069.91N 2'597.00E 13 206.00 7100.00 3117.50N 2665.34E 14 506.00 7200.00 3.164.06N 2732.59E 14 40,6 . ()() 7300.00 3207.72N 2797.33E 14 506.90 7'400.00 3249-9iN ......... 28& I':'g'4E -,:" 14 606.00 7500.00 3291.81N 2924.24E "-' 15 ?(36.00 7600.00 ....... 3332.87;~ ......... 29.3:F.46E 1.5 8'J$. O0 77()0.t)0 3373.63N 3051.57E 15 906.00 7800.00 34'14'~ 12N 3i14.51E 15 006.00 ~900.00 3453.69N 3177.72E I6 106.00 8,,']00. O0 3492.90N 3240.4'7E 16 206.~10 8100.00 3531.89N 3304.22E 16 506.00 8200.00--3569.25N -' 3370.245 16 406.q0 6_'300.00 3606.64N 34'35.94E 17 506.00 8400.00 3641.56N 3~>05.92E 17 606.00 8500.00 ~673.86N 3576.60E 17 '~06. O0 8600.00 3704.34N 3644.35E 17 806.00 8700.00 3734.98N 3713. lbE 18 906.00 8800.00 3764o42N 3781.68E 18 O0b. OO 8900.00 3792.03N 3850.02E 18 33 58 81 05 84 12 75 O5 34 61 87 12 38 6B ~8 13 37 62 13 67 gl 16 41 65 27 25 23 24 25 26 28 28 3I 32 30 29 27 26 25 26 25 25 25 24 25 26 25 27 27 24 25 . 25 24 1889 24 D I R E C T I 0 N A L S U R V E Y PAGE 4 INTERPOLATED VAL-UES ..... i~OP, "~VEN-"i'O~O ..... F'E'E~"-CJF ..... SU"~-' SEA DEPTH TANGENTIAL PETPCD HEASURED DEPTH TVD SUB .................... TOTAl[ COQP, D~rNArES ................. M SEA LATITUDE DEPARTURE DI D~-TVD FFERENCE VERTICAL CCRRECTI ON 11117 g206.00 1123~ 9'206.00 · 11358 9406.00 11480 9506.00 11608 9606.00 --'117'37' -9706. O0 11866 9~)U6.00 glO0.O0 3845.56N 3982.52E 9200.00 3870.52N 4045.25E 9300.00 3894.12N 4106o72E 9400.00 3920.18N 4172.33E 9500.00 3947.96N 4246.96E 9600.00' ....... 3977'~55N -"~3"22'%' 3'3 E 9ZO0.O0 4005.75N 4399.82E 1911 1932 1952 1.974 2002 2031 2060 22 21 20 __ 22 28 29 29 DIRECTION'AL SURVEY NAR A THCN -0 ~ ['- CO~P ANY ....... T'6U' '" D=2 6 ...................... '06-]'1 ~'~EASURED ............................. ' ............................ TOT A L- C-C-~'~-' ~ N A' T-E'S M ~='T'gC DEPTH TVD SUB SEA LATITUDE D~PAR'TURE DIFFERENCE PAGE I VERTICAL CORRECT! ON TANGENTIAL NETkOD 1000 c~q9.45 893 2000 1987.95 3000 2892.20 2786 4000 3651.62 3545 5000 4397.07 4291 6000 .................. '5 1 t6.86 ............5070 7000 5937.72 5~31 8000 6 135.73 6629 9COO 7511.34 7405 i~)O00'- 8311.02 8205 ~1000 9109.84 9003 .95 4.'78N 4.55E 0 ...95 ......... 105.22N ............ 71,22E./.- 12 · 62 988.01N ............ 671.44E ~~ 348 .07 1524.40N 1066.93E ""-----~ 602 .86 2007-64I'4 1463 33E ,~-ff~~ 823 .7Z ......... 2477.43N 1910~48E~ 1062 .84 3820.41N 3920.28E 1890 12 241 254 2'21 239 2O2 224 200 2O2 D I R E C T I 0 N A L S U R V E Y PAGE INTERPOLATED VALUES FOR NON SURVEY POINTS ...... T ~,qGEN T I-%L-' M E T HOD ............. .~ A RATHON- 0 i'[""-COjq'p ~-~/--'T BU-'-D2 2 ~ ........................... 0'&-')Y~-/7 4 M~RKER DV-"FAULT LOWER 8 C D ___ E ._. G-2 ._. ;3-3 G-4 TP i~EN [ BASE ~ .._ .............. TCP 2 SASE 2 TUP 3 G~SE 3 _ ............... T~P A GASE 4 __ LOP 5 BASE 5 LOP 6 ESI BASE MEASURED ......................... T'O'¥ AL CI]oR"j~ I NAT E S DEPTH TVD .... S..UB SEA LATITUDE DEPARTURE 3870 3557.75 34-51 ~'7'~ ....... dIA.85N ........ 619.I7E 4048 3686.87 __3580.87 iO14.03N 691.0SE 4530 4044.32 3938.32 ........ 1274.07N ....... 883.20E 5()~ 4437.51 4331.5I 1552o97N 1P, 88.46E ......... _ ......... . ........ 546~ 4751.08 z~645.08 1759.q_ 7N I252.36E 7597... 6414.13 6308.13 2732.52N 2163.89E 867~ 72~)7. z~9 .......... 715~.49 3142.06N ....... 2700.43E 10246 8505.47 8399.97 3641.55N 3505.90E i0614 8799.23 8693.23 ............... 3732o90N ....... 3706.50E lOb70 8843.u5 _ .. 8737.95 ........ 3746.6IN 3'739,.29E 10134 8895.33 8789.33 3761.49N 3774.43E l() (86 8937.26 8031.26 3'773.0IN 3802.93E ..... , ..... . ........... . ..... 10974 9()S~.81 $982.8I 3~14o68N 3006.09E llOgO 9183.56 ........... 9077.56 3RBg.75N 396,8-..12E 11204 9277. - ..... 11244 9311. 11260 9324. 11355 9403. 11364 9411. 114:~8 9471. 11454 9484. 11618 9613. . . 116~4 9626. llTO8 llSIO'-- 11876 9813. 52 9171.52 3863.89N ....... 4-027° 99E 07 9205.07 3871.70N 4048.33E 49 9218.49 3874.$2N ' 4056.465 77 9297.77 3593.58N 4105.33E 25 9305.25 3895.37N 41lO.ODE 92 9365.92 3910.91N 4149.38E 87 9378.87 ........ 3914'.43N ..... 4158,105 79 9507.79 3950.33N 4252.81E 22 9520.22 3954. ION 4262. lqE 9753.67 964'?°6? 3990.75N zt358.61E 9762.89 .... :" "9656'~89 ......... ~99~;'38N ..... 436~; 83E 45 _ 9.'1.97.."5 ..... __ Form No. In--4 -, STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT O:F DRILLING AND WORKOVER OPERATIONS SUBMIT ]IW DUPLICATE ~. APl NUAIEHICAL CODE 50-133-20260 6. LEASE DESIG1k1A~ION AN'D SE%RIAL NO. ADL 18729 1. ?. IF INDIA]~, ALOTTEE OR TRIBE NAME OIL [~[] GAS [~ WELL WELL OTHER 2. NAME OF OPERATOR *~mlon'.,,Oil£ C~mDa~c. of California 3. ADDRESS OF OPEH, ATOR' - 909 we~g~:Ni.n:t.h~ Avenue,:. :An~chgra~ie~, Alaska 99501 4. lXDCATION OF VCFJ~L Surface: 751.5' FSL, 1214.8' FWL, Sec. 6, T8N, R13~, SM, NE leg, Conductor #7, Dolly Varden Platform. Hemlock Top: 700' FNL, 375' FWL, Sec. 5, T8N, R13W, SM 8. Lq~IT,FA~ OR LEASE NAJ~E Tradin~ Bay Unit 9. WELL NO.- D-26 (11-5) 10. FLEI~D A-ND POOL. OR WILDCAT McArthur River Hemlock 11. SEC., T., R., M.. ~D~'~OM HOI~E omo~crn~O Sec. 5, T8N, R13W, SM 12. P~IT NO. 74-9 13. REPORT TOTAL DEPTH AT END oF MONTH, CHANGES IN HOLE SIZE, CASING AND CEiV~ENTING JOBS INCLUDING DEPTH SET ~ VOLUAT~ USED, PF~P~FO-RJkTIONS, ~-ESTS ~2N-D I{ESULTS, FISHING JO~.~, JLq~K I/~ HOLE A2~D SIDE-TR4%CKED HOLE A2N-D ANY OTHER SIGNIFICANT CI-IAN~ 1~ HOL~ CONDITIONS. TRADING BAY UNIT D-26, DEVELOPMENT WELL - MAY, 1974 5/1-3 Ran 250 jts. of 9-5/8" OD, 40#, 43.5#, 47#, N-80 & P-110 buttress casing in 12-1/4" hole to 10,239' & cemented with 1300 sacks of cement on 1st stage. Stage collar ~at 6,500'. Second stage cemented with 1391 sacks of cement. Landed casing in head with slips. 5/4-9 Installed BOPE. Drilled out Stage collar and tested casing to 3,000 psi - O.K. Drilled float collar & 9-5/8" casing shoe. Set plug with 400 sacks of cement from top of drill pipe fish at 10,460' to 10,033' inside 9-5/8" casing. Polished cement plug & sidetracked fish drilling 8-1/2" hole. 5/10-20 Drilled 8-1/2" directional hole following course N69OE to 11,969' MD. Ran open-hole logs -- DIL/SP, Sonic/GR, & density/GR. 5/21 Ran 43 jts. of 7" OD, 29#, N-80, X-line casing as liner with top at 10,082' & bottom of shoe at 11,952'. Cemented liner with 650 sacks of class "G" cement. 5/22-24 Cleaned out 7" liner to 11,905' PBTD. Ran Gyro-survey from 2,400' to 11,905' Ran Cement Bond Log across liner. 5/25-26 *Marathon Oil Co.- Ran wireline formation test tool with following results of Hemlock benches: Bench Depth (MD) B.HP (psi) 1. 11,224, 3,250 2 11,334' 3,650 4 11,504' 3,310 4 11,605' 3,580 5 11,704' 3,930 1!,842L 3.960 ( S e e ~*~~ s h e et ) District Dr] g. g'Tt, DA~ 6/14/74 , NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must ~ filecl in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. 5/27-29 Ran 4-1/2" OD completion tubing string with packer set at 10,010', circulating sleeve at 9 969' and safety ball valve at:309' (all M~). Removed BOPE & installed X-mas tree -- tested tree to 5,0~-P~i-~2'~-~'K' Displaced mud with water and displaced water with diesel. Gas lifted quantity of diesel from well to reduced BHP before perforating. Perforated Hemlock Bench 4 from 11,500' to 11,520' MD with 3 HPF. On May 31, 1974, gas lifting well to clean up for test. I974 /- Form No, P--4 ~-~,. 9-~0-~7 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMFr EN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS *Union 0il Company of California 31 ADDRESS OF OPEtL~TOR 909 West Ninth Ave., Anchorage. AK 99501 4. LOCATION O'F WELL Surface' 751.5' FSL, 1214.8' FWL, Sec. 6, T8N, R13W, SM, NE Leg, Conductor #7, Dolly Varden Platform. Hemlock Top' 700' FNL, 375' FWL, Sec. 5, T8N, R13W, S.M. ~. API NUSiERICAL CODE 50-133' 20260 LEASE DESIGNATION AND SL~IRIAL NO. ADL 18729 7. IF INDIAN~, ALOTTEE,OR TRIBE NAME UXIT,FAR~{ ~R-'LEA~ I~A.M~ Trading Bay Unit 9. WELL NO D-26 (11-5) 10. FIEf_AD A_ND POOL, OR wILDcAT McArthur River Hemlock SEC., T., R., M.. (BOTTOM HOLm Sec. 5, T8N, R13W, SM 12. PERMIT NO. 74 -9 13. REPORT TOTAL DEP~H AT F_~ND OF MONX~rI, CI~NGES IN HOLE SIZE,CASING AIqX)C~-%IENTING JOBS INCLUDING DEPTH SET AND VOLLrlVI~S USED, PF2FLFOI~TIONS, ~-ESTS ~ tLESULTS. FISHING JOINS. JLrNK IN HOL~ ~ND SIDE-TIR~kCKED HOLE AND ANY OTIiEi% SIGNIFICANT CHANGES IN HOI~ CONDITIONS. Trading Bay Unit D'26, Development Well - April, 1974 4/1-28 Continued drilling 12¼" directional hole following course N47°E from 7,329' MD to 11,494' MD. 4/29-30 While pulling drill pipe out of hole, pipe became stuck @ 11,468' MD. Circulated, spotted friction reducing chemical, and jarred with 360,000#, but couldn't free drill pipe. Ran free-point and string shot and backed off DP at 10,460', leaving fish in the hole from 10,460' to 11,468'. Ran in hole with bit on 4/30/74 to condition 12¼" hole to run 9-5/8" casing. *Marathon 0il Company--Sub-Operator S~G~, 1./__4,,~_~7[f/_~~~ Dist. Drlg. Supt. DA'I~ 5/13/74 NOTE--Report on this form is required for each calendar month, regardless of the status o~ operations, and mu~t De filed with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Union Oil and Gas D~.ion: Western Region Union Oil Company o, ~,alifornia 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 unl,, n I'.~y 8~ 1974 Dear Mr. Burrell: BU. Homer Burrell Division of Oil & Gas State of Alaska 3001 Porcupine Dr. Anchorage, Alaska 99504 TBUS D-Z6 (n-s) CHAN~ OF 'PLANS Submitted for your approval is the Sundry Notice (Form 107403) for a change of plans on Trading Bay Unit State Well #D-26, Dolly Varden Platform. Very truly yours,~ David A. Johnson Drilling Engineer sk Enclosures (3) MAY 9 I974 Dt¥iSt0N OF 0IL AND ~A$ Form I0 - 403 ~ ~V, rl -- ~'0--'~ · ~bw. tt "Intentions" in Trh~lic~te & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND 'GAS CONSERVATION CO:MMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR [~'ER~iT~-' 'for such 'p~o~osal-~0 .. · WELL W~LL OTHER 2. NAME OF OPERATOR *Union Oil ¢omvany of Califnrni~ 3. ADVR~SS OF O~m~ATOZ 909 West Ninth Avenue~ Anchorage, Alaska 99501 4. LOCATION OF WELL ^t~urf~ce 751.5' FSL, 1214.8' FWL, Sec. 6, T8N, R13W, SM Conductor ~/7, NE Leg, Dolly Varden Platform. 13. ELEVATIONS (Show whether DF, RT, OR, etc. KB 106.2' ~4. Check ~iate Box To I,nd/v, ate Nature of I~otice, Re 5. AP1 NLFNIEI~CA.L CODE 50-133-20260 6. LEASE DE&IGNATION AND SERIAL NO. ADL 18729 ?. IF INDIA.N, ALLO*iTI~E OR TRIBE NA.M.E 8. UNIT, FA_R1VI OR LEASE NAME Trading Bay Unit 9. WELL NO. D-26 (11-5) 10. FIELD AND POOL, OR WILDCAT McArthur River - Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 5, T8N, R13W, SM 2. P,~-~IT NO. 74-9 )orr, or Other Dtt~ NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT 0R ACIDIZE J ] ABANDONS REPAIR WELL CHANGE PLANB WA,ER sHuT-oF' J' J REPAIRINO WELL - FRACTURE TREATMENT J ALTERING CASING (Other) (NOTE: Report results of multiple completion on Well ~Other) Completion or Reeompletion RepOrt and Log form.) ! 15. DESCRIBE I'ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. It is necessary to alter the drilling and completion program for TBU Well D-26 as ori- ginally submitted on the Permit to Drill and approved by your office .on February 13, 1974 (Permit No. 74-9). The original program was followed while drilling to 11,494' MD, or 9,460' TVD. While pulling the drill pipe, it became stuck at 11,468' and could not be moved. A free- point was run and the pipe backed off at 10,460'. The fish was left in the hole from 10,460' to 11,468'. Presently, we are~conditioning the hole to run 9-5/8" casing. We will set 9-5/8" casing at 10,250', clean out, and set a plug from the top of the fish to bottom of the 9-5/8". The plug will be polished off to 10,350~ and we will kick off from that point to reach our target at 392' FNL, 706' FWL, Sec. 5, T8N, R13W, SM at the base of the Hemlock. We will:.rum~a 7" OD liner from estimated total depth at 11,810' MD, or 9,700' TVD, and lap back into the 9-5/8" casing. .. Verbal approval to alter the original program was given by Mr. HoYle H. Hamilton, Division of Oil and Gas, to Mr' D. L. Jones, Area Superintendent, Marathon Oil Com- any, on April 30, 1974. *Marathon Oil COmpany-- Sub-Operator MAY 9 974 16. I hereby certify that the for~oin&~i~ t~ue and correct Supt, co~m~o~s o~ ~vv~v~, i~ Approved Copy ~o~ No. P.-4 STATE fi,. ALASKA REV, 9-30-67 OIL AND GAS CONSERVATION COMMITTEE SUBMFF 13q DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS' 5. API NUMERICAI- CODE #50-153'-20260 LEASE DES:GNATION AND SERIAL NO ADL 18729 ~T. IF INDIA}4', ALOT/-EE,O~ TRIBE NAME 1, O,L [-~ OAS [----]OTaER WELL ___ WELL 8. L.~IT,F-~r~I OR LEASE N.a~ME 2.NAME OF OPE1R~TOR *Union Oil ComPany of Cali'fornia Trading Bay Unit 9. WELL NO 99501 6, T8N, R13W, 3, ADDRESS OF OPERATOR 909 West Ninth Ave., Anchorage, Alaska 4.LOCATION O'F WELL Surface' 751.5' FSL, 1214.8' FWL, Sec. S.M., NE Leg, Conductor #7 Hemlock Top' 700' FNL, 375' FWL, Sec 5, T8N, R13W, S.M. D-26 (11-5) lO. F!vJ.r) A_ND POOL. OR WIL'DCAT McArthur River Hemlock 11. SEC., T.. R., RI.. (BO~FOM HOL2E OmmCTF~E) Sec. 5, T8N, R13W, S.M. 12. PEH~IT NO. 74-9 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA.NGES IN HOLE SIZE, CASING AND CE~IENTING JOBS INCLUDING DEPTH SET AND VOLLrM'ESUSED, PERFORATIONS. TESTS AND RESULTS. FISHING JOBS. JLrNK LN HOLE A_ND SIDE-TRACKED HOLE AND ANY OTHiER SIGNIFICANT CqlA_NGES IN HOLE CONDITIONS. TRADING BAY UNIT D-2'6, Development Well - March, ~1974 3/12-20 Spudded Well D-26 at 3'00 a.m., 3/12/74. Drilled vertical hole to 1,323', then directionally drilled on a course N47°E to 3,320'. 3/21-22 Ran 81 JTS of 13-3/8" O.D., 61#, K-55 casing in 17-1/2" hole to 3,306' and cemented with 4,425 cu. ft. of cement. 3/23 Installed BOPE and tested to 3,000 psi. Tested bag to 2,000 psi. Drilled shoe and tested casing seat to 500 psi. Began drilling 12-1/4" hole. 3/24-31 Drilled directional hole to 7,329' MD. *sub-oPerator: Marathon Oil Company APR ! 5 1974 14. I hereby c~fY that the for~egoinF~is tr~e~a-,~d correct District Drlg. Supt. 4/15~/74 DATE (~IOTE'--~p(;;t'O'I~ tlli~'"~o"r'~'"i~*r"'e'~u*ired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. ~ !974 T~d!ng ~ ~t~ ~-26 (~ Oil ~y of ~llfo~la, ~ra~or ~-~!t ~, 74-9 Mr-. I~bert A~d~son Un!on Ol t ~y of Ca.! t lorn I ~ Enclosed is ~ ap~ ~!tcatlon for I~rttt 1~ drill 1t~ ~bove :referenced ~etl, oB or ~I~),~ May t, 1974, afa location fro~ fl~ Dot ty Vird~, Platter,. t~etl ~les., core c~Ips .~d a ~d tog are not required. A dteectlonal survey Is req~l r~d. in ~he e~t ~ suspension or aba~men, please gl'v~ this office adequate advance notlflcatlo., so that ~e mey h~ve · witness present. ~losur~ ~.: ~~ of Ft~ and ~, Habitat Section w/o encl. Department of En-vfronmen~t ¢o~,rvaf!on w/o e, ct. Robert T. Anderson District Land Manager Union Oil and Ga~'"',ivision: Western Region Union Oil Company of California ] 909W. 9th Avenue, Anchorage, Alaska 99 5~ Telephone' (907) 279-7681 union February 5, 1974 State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State'of Alaska Application to Drill Trading Bay Unit D-26 (11-5) McArthur River Field Gentlemen: Union Oil Company of California, Operator for the Trading Bay Unit, requests your approval to complete the Trading Bay Unit D-26 well in the Hemlock Oil Pool pursuant to Rule No. 5, Conservation Order No. 80. This proposed well will provide a crestal final withdrawal point, resulting in an additional ultimate recovery of Hemlock production. Your approval of this request will be appreciated. Very truly yours, HWR .'j b cc: Working Interest Owners Trading Bay Unit FE.:,3 - 5 !o74 D!'/:5.!C,~..I C,~" OiL AND GAS Porto I0-- 401 , P,-~ · I-I--71 SUBMIT IN ~ ~AT~ (Other mstructh.. reverse side) STATE O,F ALASKA OIL AND GAS CONSERVATION PERMIT TO DRILL OR DE ~E~, DRILL ~ DEEPEN NAME OF OP~TOR 909 West Ninth Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL 7~iu.~se FSL, 1214.8 FWL; Sec. 6, TSN, R13W, S.M. At prdposedprod, zone Leg A-I Conductor #7 375' FWL, 700' FNL, Sec. 5, T8N, R13W, S.M. (Top Hemlock) -APl # 50-133-20260 6. L~_.,ASIR- DI~IGNATION A_N]) S~:{,IAL NO. ADL 18729 ?, IF IN'DIAN, A. LJ, A~'i-r~:i~ OR TRIBE $ 8. UNIT~FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. D-26 (11-5) 101 FIELD AND POOL, OR WILDCAT McArthur River Hemlock 11, SEC.. T., R.. M.. (BOT'FOM HOLE OBJECTIVE) Sec 5, T8N, R13W, SM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFIC~g* 12. 21 miles NW of ienai, Alaska 14. BOND INFORMATION: , ~fl~tewide surety a~JJ~ol~.ited Pacific Insurance Co. 'B-55502 15. DISTANCE FROM PROPOSED* J16. NO. OF ACRES IN LEASE LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 375' ' 3085 (Also to nearest drig, unit, i£ any) ' ' 18. DISTANCE FROM PROPOSED LOCATION* 19. PROPOSED DEPTH TO NEAREST WELL DRILLING, COMPLETED, ORAPPLIEDFOR,~. :112050 MD 9700 1700 from D-1 ' ' TVD ,,~o,,-t $100,000.00 i?. NO. ACRES ASSIGNED TO THiS WELL. 80 20. RoTARY, OR CABLE TOOLS Rotary 1. Install .and test 20" riser and 20" 2000#-hydril on conductor. 2. Clean out conductor, dr~ll 12 1/4" .directional hole to 3300'. Open to 17 1/2". 3. Set 13 3/8" casing and cement. Install and test 13 5/8" 5000# riser, pipe and blind rams and hydril. 4. Drill directiona.lly controlled 12 1/4" hole tobottom hole location· 392' FNL, 706' FWL 5, 8N, 13W, S M.' MD 11,807' TVD 9700' · , · 5. Set 9 5/8" casing and cement· . ~ 6. Perforate the Hemlock section. 7. Run 4 1/2" tubing and packer, displace mud with diesel and gas lift well for production· *Marathon Oil Company--sub-operator IN ABOVE SPACE D]~SCRIBE PROPOSED PI~)GEA1V[: If ~1 ~ to dee~n 'give ~ on p~sent p~u~ive ~ ~d pm~ ~Wve~icalPr~du~iVedep~,~ne-GiveJL ~lblo~u ~e~0ter-iS ~ drill 0rp~g~am.~n dWect fondly,_ give ~men~,_ ~' on ' sgbSu~a~ ~t~ ~d .meas~ ~d ~ue s~G~ February 5, 1974 ~jstrict Land Manager ';~Thi, space fo'r S~te office .~) CoN~I~ON~ OF' ~P~ ' IF ~' ~NO_ ~--~ ~v~.~ February 13, 1974 ~o~ ~/~~~~~ t~.E~ecutive Secretary_ m~ February 13, 1974 SIZE OF HOLE SIZE OF CASING! WEIGHT PER FOOT GRADE SETTING DEPTH quantity of cement --17 1/2" 13 3/8" 61# 'K-55 3300' 3000 sacks //~o ~.~. e/e.e ,, ' , 5,40# N-80 & P-!lO ]2,0501 ~"4500 sacks //o o ~ ~.~.~ ., 12 1/4" 9 5/~8'i ,47~43., .... ' __ , , i L , 21. ELEVATIONS (Show whether DF, RT, CH, etc.) 22. APPROX. DATE WORK WILL START* KB 106.2' , 5/l/74 23. PROPOSED CASING AND CEMENTING PROGRAM 3J I I I I. I I I I ! ! D I TD 12,07'1 ? D-I? TO I 1,80e $ · 5 Io TD II ,Z BI D-:52 , ~,~'---- .... TD IJ,~ J FEB - 5 ~ " ,~, ~.J-~,~ Oi:: OiL /.'.F..~D GAS ~AN~ORA G~ ~ . ~ T D 13,462 D-4 TD 11,9~0 ~ O · ' +' j TD 11~237 I ' " I ~,, · ,, ~.~' .-~ . ,,. ~ ' %.,~ · ! I ~ .... O-~ ~,~ ~" TRADING BAY UNIT ,.,~o ~%_~ '~, McARTHUR RIVER FIELD T~ -- "1' ~ TO 16.60B Company Lease & Well No. CHECK LIST FOR NEW WELL PERMITS Yes No Remarks · Is well to be located in a defined pool ................. /~//~ Do statewi de rul es apply ........................ Is a registered survey plat attached .................. Is well located proper distance, from property line ........... Is well located proper distance from other wells ............ Is sufficient undedicated acreage available in this pool ........ Is well to be deviated ......................... /~z; I. Is operator the only affected party ................... ). ,Can permit be approved before ten-day wait ............... /~' O. Does operator have a bond in force ................... )~ string provided ...................... ~, 1. Is conductor 2. Is enough cement used to circulate on conductor and surface ...... ~//~ 3. Will cement tie in surface and intermediate or production strings . . . ~ cement cover all possible productive horizons ........... ~////~ ~ 4. Will 5. Will surface casing cover all fresh water zones ............ 6. Will surface csg. internal burst equal .5. psi/ft. to next string .... _ ~7. Will all casing give adequate safety in collapse and tension ...... ~,(')~J( 8. Does BOPE have sufficient pressure rating ............. ~.. ~C~7~{ ~dditional Requirements® -A-~-~o~aI -RecOmmended: KLV ~{/,?/~/, JAL HWK -~ ~ ~<' LCS