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Home My WebLink About199-071 Schwartz, Guy L (DOA) ° "1 ()1 From: Schwartz,Guy L(DOA) Sent: Monday, March 02, 2015 9:52 AM To: 'Juanita Lovett'; Dan Marlowe Cc: samantha.carlisle@alaska.gov Subject: RE:Withdraw Sundry#314-349 - Dolly Varden - D-48L1 PTD 199-071 Juanita, AOGCC will withdraw sundry 314-349 as per your request below. Scope of work included pulling patches and perforating. Regards, Guy Schwartz SCP►NNE I ;ar Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz@alaska.gov). From: Juanita Lovett [mailto:jlovett@hilcorp.com] Sent: Monday, March 02, 2015 9:43 AM To: Schwartz, Guy L(DOA); Dan Marlowe Subject: Withdraw Sundry # 314-349 - Dolly Varden - D-48L1 PTD 199-071 Guy, Please withdraw the above mentioned sundry. Thank you, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 Email: jlovett@hilcorp.com 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~/~ - ~ ? / File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [], Other Scanned by: Bevedy Mildred Dareth{~N...than..., Lo~vell,, TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha owell Date: ~//j,~.,~ /si ,;(4,01'/77 THE STATE A of �r^f ',‘ /, ( � �ti ,i•s - a_71`� R , \ J 333 West Seventh Avenue GOVERNOR SEAN hARN000 Anchorage, Alaska 99501-3572 Main 907.279.1 433 up �,.C.:, a>:: 907.276.754? SatitiV Dan Marlowe Operations Engineer 1 Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK, 99503 Re: McArthur River Field, Hemlock Oil Pool,Trading Bay Unit D-48L1 Sundry Number: 314-349 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0 1 /07173Ltic. ., Ca II y P. roerste Chair DATED this 54 day of June, 2014. Encl. • RECEIVED ` ‘. STATE OF ALASKA JUN 02201 ALASKA OIL AND GAS CONSERVATION COMMISSION 97—S 6/5 01.— APPLICATION FOR SUNDRY APPROVALS . OGC; 2OAAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate Q. Pull Tubing❑ Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate 0 Alter Casing❑ Other: Pull/Reinstall Patches CI 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC ' Exploratory El Development 0 • 199-071 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic 1:1 Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20132-60 • 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? CO 228A Will planned perforations require a spacing exception? Yes ❑ No 0/ Trading Bay Unit/D-48L1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 % McArthur River Field/Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,234 - 9,688 ‘ 11,234 9,668 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,099' 13-3/8" 2,099' 2,096' 3,090 psi 1,540 psi Production 10,182' 9-5/8" 10,182' 9,271' 6,870 psi 4,760 psi Liner 979' 7" 10,968' 9,705' 8,160 psi 7,020 psi Liner 1,306' 2-7/8" 11,221' 9,670' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic' See Schematic 4-1/2" 12.6#/L-80 10,038' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): SB-3 Perm Packer/Camco SCSSSV 9,960'(MD)9,079'(TVD)/295'(MD)295'(TVD) • 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 , Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/8/2014 Oil I]' Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(a�hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signaturee(141-1_, y , 1.47 Phrore� 7) 29 Date 6/2/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: LL// Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 _ —(ri t1 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: (j S-/y / , ,.,///��'''a-67 ,, ?/ �/�,y ,# q�uii c [�� Form 10-403(Revised 10/2012) ApprcOI RIfG1 I IjdAonths from the date of approval. RBDM in a1l2 s la Well Prognosis Well: D-48 L1 Hilcorp Alaska,LLC Date: 06/02/14 Well Name: D-48 L1 API Number: 50-733-20132-60-00 Current Status: Producer (Gas-Lift) Leg: B-1 (SE Cornor) Estimated Start Date: June 08, 2014 Rig: N/A (E-Line) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 199-071 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Current Bottom Hole Pressure: 3,569 psi @ 9,513'TVD 0.38 psi/ft(2009 static) Maximum Expected BHP: 3,800 psi @ 9,073'TVD 0.4 psi/ft(2011 data on offset well G-26) Max.Allowable Surface Pressure(Perf Job): -1,200 psi gas-lift pressure Brief Well Summary Well D-048 L1 is a Gas-lifted producer in the TBU McArthur River Hemlock Oil Pool. Slickline Procedure: 1. MIRU Slick-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RIH with slick-line and remove tubing patches at 2,361'-2,397' and 2,408'-2,467'. 3. RIH with slick-line and clean out to> 10,300'. 4. RIH with dummy gun to+1- 10,300'. 5. RD Slick-line. E-line Procedure: 6. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 7. RU e-line guns and perforate Hemlock Benches 1 &2 while flowing the well on gas-lift. Record tubing pressures before and after perforating run. 8. RD E-line. 9. RIH with slick-line and re-install tubing patches at 2,361'-2,397' and 2,408'-2,467'. 10. RD slick-line 11. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Dolly Varuen Platform ,ALASKA •BILLING Well # D-48 L1 J UNOCAL 76 Actual Completion 10-31-99 RKB=41'Rig Floor to TBG Hanger Casing and Tubing Detail SIZE WT GRADE CONN ID MD TOP MD BTM. CI 1 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,099' e 9-5/8" 47 L-80 Buttress 8.835 Surf. 10,182' m 6/11:Installed 7" 29 L-80 8rd TKC 6.184 9,989' 10,968' e 225"ID tb 2-7/8"Liner 6.4 L-80 Buttress 2.441 171' n 2 patches 2467'- (2-7/8"Liner) 6.4 L-80 STL 2.441 10,171' 10,474'; /2408'and 2397'- \Predrilled ) t ✓ 2:61'. 2-7/8"Liner 6.4 L-80 Buttress 2.441 10,474' 10,633' = 2-7/8"Liner 6.4 L-80 STL 2.441 10,633' 11,221' _ Predrilled Mill 4-1/2" 7 4-1/2" 12.6 L-80 Mod-Buttress 2.992 40' 10,038 M 3 Jewelry NO Depth ID Item 1 40' 4.00" CIW 4-1/2"Type F/FBB Tubing Hanger:4-1/2"EUE 8rd iiiii Box top x AB Mod Butt.Box BTM. _ 2 295' 3.812" Camco 4.5"TRDP-4A SCSSSV flapper type, (3.812"X-profile) MINI 3 2,113' 3.833" #11 4-1/2"Camco MMG GLM with 1-1/2"Valve _ 3,720' 3.833" #10 4-1/2"Camco MMG GLM with 1-1/2"Valve 4,774' 3.833" #9 4-1/2"Cameo MMG GLM with 1-1/2"Valve Top of 2-7/8" Mini 5,802' 3.833" #8 4-1/2"Camco MMG GLM with 1-1/2"Valve Liner @ 9,915' 6,473' 3.833" #7 4-1/2"Camco MMG GLM with 1-1/2"Valve DIL 7,153' 3.833" #6 4-1/2"Camco MMG GLM with 1-1/2"Valve 7,861' 3.833" #5 4-1/2"Camco MMG GLM with 1-1/2"Valve 8,355' 3.833" #4 4-1/2"Camco MMG GLM with 1-1/2"Valve e 4 8,844' 3.833" #3 4-1/2"Camco MMG GLM with 1-1/2"Valve 1115 9,372' 3.833" #2 4-1/2"Camco MMG GLM with 1-1/2"Valve e ,• , 9,897' 3.833" #1 4-1/2"Camco MMG GLM with 1-1/2"Valve 4 9,960' 3.958" Baker 192-47 Model EBH-22 Anchor Seal Assy. L=.70' t \ 7/ 5 9,960' 4.75" Baker SB-#Permanent Packer i i 6 9,971' 6.00" Baker Mill-out Extension 8 7 9,982' 3.813" Camco"SWS"Nipple TOL @ 19 8 10,026' 3.725" Camco"SXN"Nipple 9,989' 9 10,037' 3.950" Baker Bullnose Shear-Out Sub z. 1pZeZ e , HB1 Fish/Fill Information since 10/31/99 coil tubing redrill: m A. 06/29/00-Tagged fill @ 10,815 w/ broken 3.7"GR. e B. 08/15/01- Tagged top of 2-7/8"liner w/2-1/4"GR-unable to get deeper due to previous broken gauge ring nHB-4 setting on top of liner. t , C. 07/24/03 -Scale check-RIH w 3.70"GR to liner top @ 9915'. 0o47 r D. 06/26/11-Ran 2.25"swedge to 10480'and stopped(did not tag).Recovered broken GR. 1 Perforations Date Zone Top BTM Comments 3-3/4"hole TD 7/5/93 HB-1 10,202' 10,242' TCP KOP @ 9/10/93 HB-1 10203' 10,248 3-3/8"HC 6 SPF 60 deg 10582' DIL@ 11,223' 11/25/94 HB-1 10,203' 10,248' 3-3/8"HC 6 SPF 60 deg 1 6/27/95 HB-1 10,202' 10,248' 3-3/8"HC 6 SPF 60 deg. A 11/22/97 HB-1 10,200' 10,240' 3-3/8"HC 6 SPF II. Is • 1/22/98 HB-1 10,200' 10,240' 3-3/8"HC 6 SPF 60 deg. • � � � � � � 11/22/97 HB-4 10,455' 10,475' 3-3/8"HC 6 SPF �ti.,.ti.ti. . .,, HB-5 1/22/98 HB-4 10,455' 10,475' 3-3/8"HC 6 SPF 60 deg. fzigt"rtir1.31:? 9/15/93 HB-5 10,590' 10,665' 3-3/8"HC 6 SPF 60 deg TD=10,969';PBTD=10,873' 2/19/94 11B-5 10,615' 10,675' 3-3/8"HC 6 SPF 60 deg MAX HOLE ANGLE=30°@ 3,600' 11/24/94 HB-5 10,590' 10,675' 3-3/8"HC 6 SPF 60 deg 6/27/95 HB-5 10,590' 10,675' 3-3/8"HC 6 SPF 60 deg 11/7/97 HB-5 10,590' 10,710' 3-3/8"HC 6 SPF O:\Alaska\Fields\McArthur River\_Dolly Varden\1.0 Wells\D-48\Schematics\D-48L1 Schematic 2011.07.doc REVISED:July 2011 JHM McArthur River Field ` PROPOSED well# D-48 L1 . Actual Completion 10-31-99 % Hilwry Alaska,LLC Casing and Tubing Detail RKB=41' Rig Floor to TBG Hanger SIZE WT GRADE CONN ID MD TOP MD BTM. 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,099' II 9-5/8" 47 L-80 Buttress 8.835 Surf. 10,182' IC 1 7" 29 L-80 8rd TKC 6.184 9,989' 10,968' 2-7/8"Liner 6.4 L-80 Buttress 2.441 9,915' 10,171' 6/1l:Installed 2-7/8"Liner 6.4 L-80 STL 2.441 10,171' 10,474' 2 2.25"ID tbg Predrilled patches 2467 - 2-7/8"Liner 6.4 L-80 Buttress 2.441 10,474' 10,633' 2408'and 2397'- 2-7/8"Liner 6.4 L-80 STL 2.441 10,633' 11,221' �/ y 61 Predrilled • Tubing: 4-1/2" 12.6 L-80 Mod-Buttress 3.958 40' 10,038 Jewelry 3 NO Depth ID Item 1 40' 4.00" CIW 4-1/2"Type F/FBB Tubing Hanger:4-1/2"EUE 8rd Box top x AB Mod Butt.Box BTM. 2 295' 3.812" Camco 4.5"TRDP-4A SCSSSV flapper type, (3.812"X-profile) 3 2,113' 3.833" #11 4-1/2"Camco MMG GLM with 1-1/2"Valve 3,720' 3.833" #10 4-1/2"Camco MMG GLM with 1-1/2"Valve 4,774' 3.833" #9 4-1/2"Camco MMG GLM with 1-1/2"Valve 5,802' 3.833" #8 4-1/2"Camco MMG GLM with 1-1/2"Valve Top of 2-7/8" 6,473' 3.833" #7 4-1/2"Camco MMG GLM with 1-1/2"Valve Liner @ 9,915' 7,153' 3.833" #6 4-1/2"Camco MMG GLM with 1-1/2"Valve DIL 7,861' 3.833" #5 4-1/2"Camco MMG GLM with 1-1/2"Valve 8,355' 3.833" #4 4-1/2"Camco MMG GLM with 1-1/2"Valve 8,844' 3.833" #3 4-1/2"Camco MMG GLM with 1-1/2"Valve 4 9,372' 3.833" #2 4-1/2"Camco MMG GLM with 1-1/2"Valve e 9,897' 3.833" #1 4-1/2"Camco MMG GLM with 1-1/2"Valve 5 4 9,960' 3.958" Baker 192-47 Model EBH-22 Anchor Seal Assy. L=.70' e b' 6 5 9,960' 4.75" Baker SB-3 Permanent Packer 6 9,971' 6.00" Baker Mill-out Extension t; \ SWS 7/ 7 9,982' 3.813" Camco"SWS"Nipple 1 1 8 10,026' 3.725" Camco"SXN"Nipple SXN 8 9 10,037' 3.950" Baker Bullnose Shear-Out Sub TOL @ I 11 9,989' I-1 9 Fish/Fill Information since 10/31/99 coil tubing redrill: LC A. 06/29/00--Tagged fill @ 10,815'w/broken 3.7"GR. e _, B. 08/15/01-Tagged top of 2-7/8"liner w/2-1/4"GR-unable to get deeper due to previous broken gauge ring setting ni HB-I on top of liner. e C. 07/24/03 -Scale check-RIH w 3.70"GR to liner top @ 9915'. HB-2 D. 06/26/11-Ran 2.25"swedge to 10480'and stopped(did not tag).Recovered broken GR. n t - HB-4 Perforations Date Zone Top BTM TOP Btm Comments (MD) (MD) (TVD) (TVD) 11/22/1997& HB-1 10,200' 10,240' 9,287' 9,323' 3-3/8"HC 6 SPF 3-3/4" 01/22/1998 KOP @ hole TD 7/5/1993 HB-1 10,202' 10,242' 9,289' 9,324' TCP 10582' DIL @ 11,223' 6/27/1995 HB-1 10,202' 10,248' 9,289' 9,330' 3-3/8"HC 6 SPF 60 deg. 9/10/1993& 1-1B-1 10,203' 10,248' 9,290' 9,330' 3-3/8"HC 6 SPF 60 deg A 11/25/1994 "ile Future HB-1 ±10,212' ±10,232' ±9,298' ±9,316' �, ., Future HB-2 ±10,286' ±10,296' ±9,363' ±9,372' HB-5 11/22/1997& H8-4 10,455' 10,475' 9,512' 9,530' 3-3/8"HC 6 SPF 1:1::.::...,1:Y: 01/22/1998 :::0,1,1".41:47:11: i._ _.► 9/15/1993 11B-5 10,590' 10,665' 9,630' 9,68V Isolated below whipstock 11/24/1994& HB-5 10,590' 10,675' 9,630' 9,685' TD= 10,969'; PBTD=10,873' 06/27/1995 MAX HOLE ANGLE=30°@ 3,600' 11/7/1997 HB-5 10,590' 10,710' 9,630' 9,699' 2/19/1994 HB-5 10,615' 10,675' 9,650' 9,685' Updated by: JLL 06/02/14 • ~~~~il'~ Francisco Castro Chevron North America Exploration and Production Y Technical Assistant 3800 Centerpoint Dr. Suite 100 ~~ Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE dune 28, 2010 ~ j ;:~, ~ ~ ~ ~ ~ °®, ~~ To: AOGCC Mahnken, Christine R ~ w ~ ~. `' iii 333 W. 7t" Ave. Ste#100 ~~~,~ ~:~;~; dr " ~'~ [~-~ _ Anchorage, AK 99501 ~ .~ ~ .. . Transmitted herewith is one DVD containing the following data. • D-48L1 • Formation evaluation logs -LAS • Gamma ray logs -LAS • K-12RD2 • K-12RD2_Final_Survey.xls • K-12RD2_Tops.xlsx • MPR-Gamma ray logs -LAS, CGM, PDF • K-18RD • K-18RD_Final_Survey.doc • Density Neutron logs -LAS • K-18RDPB1 • UBI log -LAS, PDS, DLIS • survey.xls • K-24RD2 • Density Neutron logs -LAS • Final Mudlog Report -LAS., DOC • M-06 ~p~_~j~ l4i ~~~ ~t~r -/i~ bbl-~GII ~o~-~ ~ ~a3-/~s2 19~~~ /`~$~~ a~~b~ t9 ~r0 • Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS • M-lOTops.xlsx • USIT log -PDS ~U9 -®5' 3 l ~ ~,~ Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS • M-10PB1 Final logs; Depth, Formation Evaluation, Realtime, Time -LAS, PDS, DLIS M-16RD ~~~ - ~~U l 91 ~l ~'/ • M-16RD_Tops.xlsx • Final logs; Cement Bond Log, Completion Record -PDS • M-17 • M-17_Tops.xlsx • M17_MWD_Survey.pdf • Final Mudlog Report -LAS, DOC, DBF, MDX, PDF, DAT • Final logs; Depth, Formation Evaluation, Cement Bond, Plug Setting, Perforation - LAS, PDS, DLIS, TIFF Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 263 7828. Received By: Date: 10l ALASKA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 23, 2003 Dwight Johnson UNOCAL Field Superintendent PO Box 196247 Anchorage, Alaska 99519 RE' No-Flow Verification TBU Well D-48L1 PTD 199-071 Dear Mr. Johnson: On August 22, 2003 AOGCC Petroleum Inspector Lou Grimaldi witnessed a "no-flow" test on Well D-48L1 at UNOCAL's Dolly Varden Platform, Trading Bay Unit, McArthur River Field. Mr. Grimaldi arrived on Dolly Varden Platform and observed the well flowing to the clean-up tank at 1 psi. The well was shut in, allowed to build pressure and opened to the clean-up tank or production flow through 4 cycles over a total observation period of 4.5 hours. A maximum build up of 3 psi was noted. When the well was opened to flow, a maximum gas rate of 600 scl/hr was recorded which decreased to a sustained flow of 450- 500 scl/hr. At the end of the observation periods, the well pressure was 1 psi. Throughout the observation periods, no liquid flow was observed. The observed performance of TBU well D-48L1 (199-071) demonstrated that the well is incapable of unassisted flow of hydrocarbons to the surface. It has been concluded that TBU well D-48L1 (199-071) meets the criteria of a "no-flow" performance test and as such, is considered incapable of unassisted flow to the surface. The well's performance meets the criteria at 20 AAC 25.265 (b). Therefore the well is not required to have a fail-safe automatic SSSV, however, the pilot and SSV must be maintained in satisfactory operating condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well file on board Dolly Varden. Thomas E. Maunder, PE Sr. Petroleum Engineer TEM:qjc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' Randy Ruedrich, ,~'/L'){~~ DATE: Commissioner THRU: Jim Regg, P. I. Supervisor August 22, 2003 FROM: Leu Grimaldi, SUBJECT: Petroleum Inspector No-Flow Test Unocal, Dolly Varden D-48L1 Trading Bay Unit PTD 199-0710 NON-CONFIDENTIAL Friday, August 22, 2003: I witnessed a No-Flow verification on the Dolly Varden platform well #D-48L1 in the McArthur River field. Following is a timeline and well status during test. 1200 D-48L1 flowing @ < 1 psi to well clean tank. 1250 Shut-in well @ <1 psi 1300 Open well to flow meter, 600 scf @ 1 psi, flowed down to 550 scf @ < 1 psi. 1310 Sustained flow of 500 scf, shut-in well @ < 1 psi. 1405 SITP 2 psi, open well, initial flow 1100 scf down to 850 scf in 3 minutes, down to 650 scf in 8 minutes (total). 600 scf sustained flow. 1425 Shut-in well @ < 1 psi. 1525 Shut-in @ 3 psi, Blow down well to production. Line up well to flow meter. Sustained flow @ 500 scf. Observed in this state for 30 minutes. 1605 Shut-in @ < 1 psi. 1700 Shut-in @ < 2 psi. 1705 Blow down to production, 500 scf flow. Down to 450 scf flow. 1730 Sustained flow rate of 450 scf. Ended test, turned well back over to production. Note: The gauge used to check flow was incapable of measuring below 180 scf or above 2000 scf. 100-psi gauge used to check tubing pressure. Zero flow indicated by hose in bucket. This well exhibited inability to flow to surface unassisted and I recommend it be granted No-Flow status. I explained to John Lee (Platform Lead Operator) that any cleanout, perforating or other stimulation would require another No-Flow test. SUMMARY: I witnessed No-Flow verification on UNOCAL's Dolly Varden platform well #D-48L1 in the McArthur River field. NON-CONFIDENTIAL CC; Dwight Johnson (Unocal), (platform) No-Flow TBU D-48 08-22-03 LG.doc Unocal Alaska 909 W. 9th Avenue ..:~./ Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: harrisonb @ unocal.com Beverly Harrison Business Ventures Assistant DATA TRANSMITTAL January 17, 2002 To: Lisa Weepie Alaska Oil & Gas 333 W 7th Ave, #100 Anchora~le, AK 99501-3539 From' Beverly Harrison Unocal Alaska 909 W. 9th Avenue Anchora~le, AK 99501 Transmitting the following: iTRU.E.VERTICA.L. DEp.~H LOG 5 INCH10/30/199 10564-11234 ...... ! ........ i..D-48 L1 Film iTRUE VERTICAL DEPTH LOG 5 INCH 10/30/199 10564-11234 1 ilD-48 L1 B-Line MEASURED DEPTH LOG 5 INCH 10/30/199 10564-11234 1 D-48 L1 i~Film i'M'EA'SUREiDi. DEpi~H"'EO. Gii'i"i'iiiii.i.i... !.51.N. CiHii.i.i. ~`~!~1~/~.19~i~.i`~56~ii.~`.~3~i.~.~.~.~.~.~1~.`.~`~.~?D:~.~..~1 ....... i'B-Line RECEIVED JAN1 8 2002 Alaska Oil ~ G~o Cons, Please acknowledge receipt by signing and returning one copy of this transmilffal or FAX to (907) 263-7828. J Date: ,r STATE OF ALASKA ALASKA C~-~ AND GAS CONSERVATION u-~MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator UNION Oil Company of California (UNOCAL) 3. Address P.O. Box 19624, Anchorage, AK 99519 Classification of Service Well 7. Permit Number 99-71 8. APl Number 50- 733-20132-60 9. Unit or Lease Name 4. Location of well at surface 681' FSL, 1,220' FWL, Sec 6, T8N, R13W, SM At Top Produc~;~rv~ ~ '71467' FNL,'-2~rS' FI~_, Sec. 6, T8N, R13W, SM At Total DepthG.~ I~q ~ ..7--88 FNL, L;~7-+2' fWL, Sec. 6, T8N, R13W, SM Trading Bay Unit 10. Well Number D-48 L1 11. Field and Pool McArthur River Filed Hemlock 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 106' KB ADL -18729 12. Date Spudded10/21/99 13' Date T'D' Reached I 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' 'f °frsh°re I 16' N°' °' C°mp'et~°nsl 0/30/99 10/31/99 106 feet MSL 1 17. Total Depth (MD+TVD)18. Plug Back Depth (MD+TVD)I 1,234'/9,668' 11234'/9668' 19. Directional Survey ] 20. Depth where SSSV Setyes: X No: 295 feet MD ] 21. Thickness of PermafrostNA 22. Type Electric or Other Logs RunNA 0R!n!NA 23. CASING, LINER AND CEMENTING RECORD ~"' ~ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2-7/8" 6 L-80 9,915' 11,221' 3-3/4" Pre-drilled & blank liner 25. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 2-7/8" pre-drilled liner from 10,663' MD (9,680' TVD)to 11,221' MD (9,668'-I-VD) (Drilled with 16 each 1/2" holes/fi) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 10,038' 9,960' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production 11/1/99 Date of Test 11/10/99 Hours Tested 24 I Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD => OIL-BBL 965 GAS-MCF 333 WATER-BBL 484 Alaska 0il & Gas Cons. Commission CHOKE SIZE Full Open ~345 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 110 994 24-HOUR RATE => 965 333 484 32.8 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA 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. NA 31. LIST OF ATTACHMENTS Wellbore diagram, surveys and operations summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~l/~~ ~. Title X~''///~,.~/~ Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other 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 UNOCAL ) Dolly Va~',~a Platform Well # D-48 L1 Actual Completion 10-31-99 RKB = 41' Rig Floor to TBG Hanger Top of 2-7/8" Liner ~ 9,915' DIL TOL ~ 9,989' Bottom Whipstock at 10586' HB1 3-3/4" hole TD HB-5 TD = 10,969 '; PBTD = 10,873' MAX HOLE ANGLE = 30° ~ 3,600' D-48 L1 10-31-99.doc Casing and Tubing Detail SIZE WT GRADE CONN ID MD TOP MD BTM. 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,099' 9-5/8" 47 L-80 Buttress 8.835 Surf. 10,182' 7" 29 L-80 8rd TKC 6.184 9,989' 10,968' 2-7/8" Liner 6.4 L-80 Buttress 2.441 9,915' 10,171' 2-7/8" Liner 6.4 L-80 STL 2.441 10,171' 10,474' Predrilled 2-7/8" Liner 6.4 L-80 Buttress 2.441 10,474' 10,633' 2-7/8" Liner 6.4 L-80 STL 2.441 10,633' 11,221' Predrilled Tubing: 4-1/2" 12.6 L-80 Mod-Buttress 2.992 40' 10,038 Jewelry NO Depth ID Item I 40' 4.00" CIW 4-1/2" Type F/FBB Tubing Hanger: 4-1/2" EUE 8rd Box top x AB Mod Butt. Box BTM. 2 295' 3.812" Camco 4.5" TRDP-4A SCSSSV flapper type, (3.812" X-profile) 3 2,113' 3.833" # 11 4-1/2" Camco MMG GLM with 1-1/2" Valve 3,720' 3.833" # 10 4-1/2" Camco MMG GLM with 1-1/2" Valve 4,774' 3.833" # 9 4-1/2" Camco MMG GLM with 1-1/2" Valve 5,802' 3.833" # 8 4-1/2" Camco MMG GLM with 1-1/2" Valve 6,473' 3.833" # 7 4-1/2" Camco MMG GLM with 1-1/2" Valve 7,153' 3.833" # 6 4-1/2" Camco MMG GLM with 1-1/2" Valve 7,861' 3.833" # 5 4-1/2" Camco MMG GLM with 1-1/2" Valve 8,355' 3.833" # 4 4-1/2" Camco MMG GLM with 1-1/2" Valve 8,844' 3.833" # 3 4-1/2" Camco MMG GLM with 1-1/2" Valve 9,372' 3.833" # 2 4-1/2" Camco MMG GLM with 1-1/2" Valve 9,897' 3.833" # 1 4-1/2" Camco MMG GLM with 1-1/2" Valve 4 9,960' 3.958" Baker 192-47 Model EBH-22 Anchor Seal Assy. L= 5 9,960' 4.75" Baker SB-# Permanent Packer 6 9,971' 6.00" Baker Mill-out Extension 7 9,982' 3.813" Camco "SWS" Nipple 8 10,026' 3.725" Camco "SXN" Nipple 9 10,037' 3.950" Baker BuHnose Shear-Out Sub .70' Fish/Fill Information: A. Tag Fill @ 10,890' 7/27/939,900'. Tag fill @ 10,830' 11/1/97. Tight spot ~ 9,900' 8/19/98 B. Lost Camco 1.5" Valve 7/27/93 C. Lost blades from production log 2/17/94 D. Tag fill ~ 10,888' 6/10/95 Perforations Date Zone Top BTM Comments 7/5/93 HB-1 10,202' 10,242' TCP 9/10/93 HB-1 10203' 10,248 3-3/8" HC 6 SPF 60 deg 11/25/94 HB-1 10,203' 10,248' 3-3/8" HC 6 SPF 60 deg 11/22/97 ltB-1 10,200' 10,240' 3-3/8" HC 6 SPF 11/22/97 HB-4 10,455' 10,475' 3-3/8" HC 6 SPF 9/15/93 HB-5 10,590' 10,665' 3-3/8" HC 6 SPF 60 deg 2/19/94 HB-5 10,615' 10,675' 3-3/8" HC 6 SPF 60 deg 11/24/94 HB-5 10,590' 10,675' 3-3/8" HC 6 SPF 60 deg 11/7/97 HB-5 10,590' 10,710' 3-3/8" HC 6 SPF REVISED: 11/03/99 DRAWN BY: MWD Dolly Varden Platform D-48 L1 Operations Summary: 10/11-10117199: Complete mobilizing CT drilling unit. Test BOPE to 250/5000 psi. MU cleanout BHA #1 (dimple mill) could not pass through SCSSV. Turn down mill and rerun. Cleanout tubing and casing to 10,830'. POOH and PU undereamer. Cleanout 7" casing to 10,640'. POOH and LD BHA. RU wireline unit and RIH with USIT (casing inspection log) to 10,660'. Log 7" casing. POOH and PU thru tubing whipstock. RIH and set bottom of whipstock @ 10,586'. POOH with wireline. 10118-10/25199: RIH with window milling assy #1 and start to mill window. POOH due to motor problems. RIH with second dimple mill and mill to 10577'. POOH for formation and string mills. Mill to 10,583'. POOH and LD milling assembly and PU drilling assembly. Drill 3-3/4" hole from 10583' to 10,833'. 10125-10131199: Drill 3-3/4" hole from 10,833' to 11,234'. Connection above motor failed due to fatigue and motor left in hole. Decision was made to not fish BHA or perform OH side track. RIH with cleanout assembly. Spot fresh mud in hole. POOH and LD BHA. RIH with 2-7/8" predrilled liner. Release liner and change well over to 3% KCL and 3% KCL & bleach in OH. POOH and turn well over to production. Begin demobilizing CTDU. D-48 L1 Operations Summary. doc 11/03/99--2:53 PM Schlumberger Final 10' Surveys Client: Unocal Field: Trading Bay Structure: Dolly Varden Well: D-48 Borehole: D-48 L1 gryos to surface UW~/AP~#: 50-733-20132-60 Date: October 30, 1999 Grid Convergence: -1.42535438° Scale Factor: 0.99999671 Location: : Coordinate System: N 60 48 27.523, W 151 37 57.456 N 2490760.027 flUS, E 208467.469 ftUS NAD27 Alaska State Planes, Zone 4, US Foot Survey Survey Computation Method: DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference: Magnetic Declination: Total Field Strength: Dip: Declination Date: Magnetic Declination Model: North Reference: Coordinate Reference To: Minimum Curvature Lubinski 323.1600 N 0.000 ft, E 0.000 ft 106.0 ft above MSL 21.2810 55228.736 nT 73.4950 October 30, 1999 BGGM 1999 Grid North Well Head Station ID Tie-in Survey Base Window Stn-lnterp Az Stn-lnterp Az Stn-lnterp Az MD ITVD (,) I'nc' 10565.54 28.01 24.70 9609.48 10580.00 31.13 35.00 9622.01 10594.89 34.73 34.0O 9634.50 10602.00 36.00 29.00 9640.30 10613.00 38.88 32.00 9649.04 VSec I 1726.28 1729.11 1731.71 1733.23 1735.80 10624.91 46.38 32.00 9657.79 1738.71 10635.19 49.82 31.00 9664.66 1741.53 10639.00 52.52 31.00 9667.05 1742.65 10647.00 55.12 30.00 9671.77 1745.14 10658.00 59.17 29.70 9677.73 1748.80 3413.81 3420.05 3426.72 3430.23 3435.99 3442.82 3449.35 3451.89 3457.46 3465.47 E/-W I Closure 1677.56 3803.72 1681.17 3810.92 1685.75 3818.92 1687.89 3823.02 1691.29 3829.68 at Azim (o) 26.17 26.18 26.19 26.20 26.21 (o/100ft) 71.2 G 38.75 -9.O (3 24.45 -68.4 G 44.44 33.5 (3 30.98 0.0 G 1695.56 3837.70 26.22 62.97 -12.5 G 1699.56 3845.32 26.23 34.24 0.0 G 1701.09 3848.28 26.23 70.87 -17.5 G 1704.36 3854,72 26,24 34.03 -3,6 G 1708.96 3863.94 26.25 36.89 -30.3 G D-48 L1 Final 10' MWD survey report.xls Page 1 of 3 10/31/99-12:59 PM Station Survey 10666.06 60.97 28.50 9681.76 1751.64 3471.57 1712.36 3870.91 26.25 25.79 -7.9 G 10676.04 64.23 28.00 9686.35 1755.38 3479.38 1716.55 3879.77 26.26 32.97 -67.9 G 10682.00 64.98 26.00 9688.90 1757.75 3484.17 1718.99 3885.15 26.26 32.82 -51.8 G Station Survey 10699.53 68.32 21.53 9695.85 1765.65 3498.90 1725.47 3901.22 26.25 30.18 0.0 G 10714.00 75.51 21.53 9700.34 1772.86 3511.69 1730.51 3914.92 26.23 49.69 -20.8 G 10724.00 79.48 20.00 9702.51 1778.09 3520.81 1733.97 3924.64 26.22 42.42 -69.6 G Station Survey 10733.04 80.93 16.11 9704.05 1783.21 3529.28 1736.73 3933.45 26.20 45.33 -68.3 G 10741.00 82.01 13.40 9705.23 1788.10 3536.89 1738.74 3941.17 26.18 36.30 -77.8 G 10753.60 82.98 9.00 9706.87 1796.45 3549.14 1741.16 3953.23 26.13 35.47 -96.6 G Station Survey 10765.74 82.72 6.68 9708.39 1805.02 3561.08 1742.81 3964.67 26.08 19.08 -80.1 G 10774.00 83.23 3.80 9709.40 1811.10 3569.24 1743.56 3972.33 26.04 35.15 -62.6 G 10784.00 84.84 0.70 9710.44 1818.82 3579.17 1743.95 3981.44 25.98 34.78 -73.0 G Station Survey 10795.75 86.05 356.76 9711.37 1828.35 3590.88 1743.69 3991.85 25.90 34.98 -61.4 G 10805.00 87.01 355.00 9711.93 1836.11 3600.09 1743.02 3999.85 25.83 21.64 -53.3 G 10815.00 88.28 353.30 9712.34 1844.68 3610.03 1742.00 4008.35 25.76 21.21 -98.4 G Station Survey 10826.00 87.93 350.91 9712.70 1854.30 3620.92 1740.49 4017.51 25.67 21.95 -72.3 G 10836.00 88.38 349.50 9713.03 1863.20 3630.77 1738.79 4025.65 25.59 14.79 -103.2 G Station Survey 10847.13 88.03 348.01 9713.37 1873.23 3641.68 1736.62 4034.56 25.50 13.75 -75.1 G 10857.60 88.70 345.50 9713.67 1882.82 3651.86 1734.23 4042.73 25.40 24.80 -84.2 G Station Survey 10877.68 89.23 340.33 9714.04 1901.71 3671.05 1728.33 4057.55 25.21 , 25.88 -69.9 G 10888.00 90.56 336.70 9714.05 1911.66 3680.65 1724.55 4064.63 25.11 37.46 -62.0 G 10899.00 92.47 333.10 9713.76 1922.43 3690.61 1719.89 4071.68 24.99 37.04 -21.2 G Station Survey 10907.79 95.55 331.90 9713.15 1931.08 3698.38 1715.84 4077.03 24.89 37.59 -35.2 G Station Survey 10922.74 99.55 329.03 9711.18 1945.77 3711.27 1708.54 4085.66 24.72 32.83 -77.8 G Station Survey 10936.79 100.55 324.18 9708.73 1959.58 3722.82 1700.93 4092.99 24.56 34.73 -82.4 G 10943.00 100.83 322.00 9707.58 1965.68 3727.70 1697.26 4095.91 24.48 34.79 -131.1 G 10952.00 99.10 320.00 9706.02 1974.54 3734.59 1691.68 4099.87 24.37 29.13 -138.8 G Station Survey 10966.34 97.83 318.88 9703.91 1988.69 3745.36 1682.46 4105.90 24.19 11.75 -90.7 G Station Survey 10990.43 97.78 315.80 9700.64 2012.43 3762.91 1666.29 4115.34 23.88 12.67 -7.7 G 11002.00 99.98 315.50 9698.85 2023.76 3771.09 1658.30 4119.59 23.74 19.19 -67.1 G 11011.00 100.64 313.90 9697.24 2032.52 3777.31 1652.01 4122.77 23.62 18.97 -53.9 G D-48 L1 Final 10' MWD survey report.xls Page 2 of 3 10/31/99-12:59 PM Station Survey 11019.74 101.60 312.55 9695.56 2040.97 3783.19 1645.76 4125.65 11031.00 102.41 312.00 9693.21 2051.78 3790.60 1637.61 4129.21 Station Survey 11049.67 102.70 310.13 9689.16 2069.60 3802.57 1623.87 4134.79 Station Survey 11079.97 101.25 309.61 9682.87 2098.45 3821.57 1601.12 4143.42 11092.00 100.10 310.10 9680.64 2109.95 3829.14 1592.04 4146.92 Station Survey 11107.29 99.35 311.58 9678.06 2124.67 3839.00 1580.64 4151.67 Station Survey 11136.65 100.05 316.33 9673.11 2153.23 3859.08 1559.82 4162.39 Station Survey 11161.88 96.53 320.08 9669.47 2178.10 3877.69 1543.18 4173.47 Station Survey 11189.70 91.38 322.45 9667.55 2205.82 3899.33 1525.83 4187.23 Station Survey 11201.43 89.28 323.68 9667.48 2217.55 3908.70 1518.78 4193.41 Projection to top of fish 11221.54 87.00 321.00 9668.14 2237.65 3924.61 1506.50 4203.82 Projectto Bit 11234.00 86.00 320.00 9668.90 2250.07 3934.21 1498.59 4209.96 23.51 23.37 23.12 22.73 22.58 22.38 22.01 21.70 21.37 21.23 21.00 20.85 18.72 -33.5 G 8.64 -80.8 G 9.90 -160.6 G 5.07 157.2 G 10.36 117.1 G 10.73 81.1 G 16.12 133.2 G 2O.27 155.2 G 20.37 149.6 G 20.75 -130.4 G 17.49 -135.1 G 11.34 --- D-48 L1 Final 10' MWD survey report, xls Page 3 of 3 10/31/99-12:59 PM Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: childersd @ unocal.corn UNOCAL Debra A. Childers Technologist DATA TRANSMITTAL August 30, 2001 To: Lisa Weepie 333 W 7th Ave, Cf100 Anchorage, AK 99501-3539 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99501 Unocal Alaska Transmitting the following: TBu D-48 L1 ~ORMA'TION EVAL LOGS 10/30/99 1CD FORMATION EVAL DIGITAL DATA / ~- f:::)'-)t SURVEYS TBU K-13 RD2 FORMATION EVALLOGS 6/15/01 1CD ~O/.~Oq(~ SURVEYS I Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Date: TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION July 23, 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Williamson Drilling Manager Unocal Corporation P O Box 190247 Anchorage, AK 99519-0247 Re~ Trading Bay Unit D-48L1 Unocal Corporation Permit No: 99-71 Sur Loc: 68 I'FSL, 1220'FWL. Sec. 6, T8N. R13W. SM Btmhole Loc. 3688'FSL, 2660'FWL. Sec. 6, T8N, R13W. SM Dear Mr. Williamson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a nexv wellbore segment of existing well Trading Bav Unit D-48L1. Permit No. 92-154. APl 50-733-20132-01. Production should continue to be reported as a function of the original API number stated above. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given bv contacting the Commission at 279-1433. './ Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC~ Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA Orb AND GAS CONSERVATION C~OMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill: Redrill: X I lb. Type of well Exploratory: Stratigraphic Test: Development Oil: X Re-Entry: Deepen:I Service: Developement Gas: Single Zone: Multiple Zone: X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool UNOCAL 106' RKB feet McAuthur River Field 3. Address 6. Property Designation Hemlock P.O. Box 19-0247 Anchorage, AK. 99519-0247 ADL-18729 4. Location of well at surface Leg B1 Slot # 12 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 681' FSL, 1,220' FWL, Sec. 6 8N-13W-SM Trading Bay Unit At top of productive interval 8. Well number Number U62-9269 4,062' FSL, 2,882' FWL, Sec 6 8 N-13W-SM D-48 ~,~.. At total depth 9. Approximate spud date Amount 3,688' FSL, 2,660' FWL, Sec 6 8N-13W-SM .744¢99~ ¢¢~r~ 12. Distance to nearest 13. Distance to nearest well 14. Number of ~cres in'property 15. Proposed depth (MD and TVD) property line 1140 feet 475 feet 3085 11,798'/9,640' MD & ' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 10490 feet Maximum hole angle: 95 Maximum surface 2,071 psigAt total depth (q-VD) 3,000 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3.75 2-7/8" 6.4 L-80 STL None-slotted liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: truemeasuredvertical 10,969 feet9,959 feet Plugs(measured)0 ¢'::" ' Effective depth: measured 10,873 feet Junk (measured) true vertical 9,876 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 398' 33" 398' 398' Surface 2,099' 13-3/8" 2,000 SX 2,099' 2096' Intermediate Production 10,183' 9-5/8" 1225 SX 10183' 9272' Liner 980' 7" 270 SX 10,969' 9959' Perforation depth: measured true vertical 20. Attachments: Filing fee: X Property Plat: X BOP Sketch: X Diverter Sketch: Ddlling program: X Drilling fluid program: X Time vs. depth plot: X Refraction analysis: Seabed report: 20 AAC 25.050 requirements: 21. I herby certify that the foregoing is true and correct to the best of my knowledge: o~' ~,~ ! ,~j~' '~t~4i ~'tl~: Signed: r~te,he~,.B~l~for Dan Williams V Drilling Manager Date: "' Commission Use Only Permit Number IAPl number I Approval_~ ...¢:~..~..../4-~.date I See cover letter ~'?- 2'/ 50- 7~$- 2. o...,~--..,_ other for requirements Conditions of approval Samples required: [ ] Yes ~ No Mud log required: [ ] Yes ~ No Hydrogen sulfide measures [ ] Yes ~ No Directional survey required ~Yes [ ] No Required working pressure forBOPE [ ]2M; ~ 3M; [ ]5M; [ ] 10M; [ ] 15M Other: by order of ¢~,,~__~ Approved by ORIGINAL SIGNED BY Commissioner the Commission Date: · . ktobert N. Chdstenson Form 10-401 Rev. 12-1-85 Unocal Alaska Reso,. .... s Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL June 15,1999 Mr. Robert N. Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 TRADING BAY UNIT Well D-48 · APPLICATION TO DRILL AND COMPLETE ADL- 18729 Dear Chairman Christenson: Union Oil Company of California. as operator of the Trading Bay Unit, hereby requests approval to drill, complete and produce Trading Bay Unit State well D-48 in the McArthur River Field "Hemlock Zone" pursuant to Rule 5, Conservation Order No. 80. The proposed completion of the well will result in additional recovery of Hemlock Production. Your approval of this request is appreciated. If you require additional information, please contact Dan Thomas at 907-263-7624. or Hal Martin at 907-263-7675. Very truly yours, Enclosures Unocal Alaska Business Unit ~ Dolly Varden Platform Well #DV-48RD AFE # 134573 Prepared by: Mtiehell Damm Date:3/2/98 Revision #3 Estimate to drill short radius lateral with coiled tubing. No. Preliminary Procedure Prep tubing and casing for redrill I Cleanout tubing with coiled tubing 2 Run underreamer and cleanout casing 3 Run slickline casing caliper Set whipstock and mill window 1 Run whipstock on e-line - - 2 Mill window with coiled tubing unit. Prep rig for Redrills (Separate AFE will be prepared) 1 Activate Dolly Varden rig. 2 Install solids control equipment. 3 Skid rig from previous well Drill and Complete Short Radius Lateral 1 RU 2" coiled tubing drilling unit and equipment 2 Test tree and BOPE 3 MU BHA 4 RIHwithBHA. 5 Drill 10 ftt. 6 Perform LOT 7 Drill 3-3/4" hole. (75 ft/day) 8 Circulate and condition hole 9 POOH withBHA. 10 LD BHA. Run 2-7/8" Predrill Liner 11 RU casing crews for liner 12 Change casing rams and test BOPE 13 RIH with liner. 14 Continue to RIH with liner on coiled tubing. 15 Circulate and condition hole 16 Drop liner off on bottom by releaseing running tool. 17 POOH with setting tool 18 ND BOPE. 19 Turn well over to Production. 20 RD coiled tubing unit and associated equipment D-48RD Coil RD Cost Est2 .xls Page 1 of 1 6/1/99 Dolly Varden #48 Coiled Tubing Redrill U I~l O ~~/~} Depth Versus Time 10,400 10,500 10,600 10,700 10,800 10,900 ~ ~,ooo 11,100 11,200 11,300 11,400 11,500 11,600 AFE ~Actual Optimum 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 Time (Days) 20 D-48RD Coil RD Cost Est2 .xls 6/1/99/2:19 PM UNOCAL ) RKB = 41' Rig Floor to TBG Hanger £ e n e n t t TOL ~! 9,989' TD = 10,969 '; PBTD = 10,873' MAX HOLE ANGLE = 30° ~ 3,600' DV-48 7-9-93.doc Dolly Varwen Platform Well # 48 Completed: 7/9/93 Casing and Tubing Detail SIZE WT GRADE CONN ID MD TOP MD BTM. 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,099' 9-5/8" 47 L-80 Buttress 8.835 Surf. 10,182' 7" 29 L-80 8rd TKC 6.184 9,989' 10,968' Tubing: 4-1/2" 12.6 L-80 Mod-Buttress 2.992 40' 10,038 Jewelry NO Depth ID Item 1 40' 4.00" 2 304' 3.812" 3 2,122' 3.833" 3,730' 3.833" 4,783' 3.833" 5,811' 3.833" 6,482' 3.833" 7,163' 3.833" 7,871' 3.833" 8,365' 3.833" 8,854' 3.833" 9,382' 3.833" 9,906' 3.833" 9,960' 3.958" 9,965' 4.75" 9,971' 6.00" 9,983' 3.813" 10,027' 3.725" 10,038' 3.950" CIW 4-1/2" Type F/FBB Tubing Hanger: 4-1/2" EUE 8rd Box top x AB Mod Butt. Box BTM. Camco 4.5" TRDP-4A SCSSSV flapper type, (3.812" X-profile) # 11 4-1/2" Camco MMG GLM with 1-1/2" Valve # 10 4-1/2" Camco MMG GLM with 1-1/2" Valve # 9 4-1/2" Camco MMG GLM with 1-1/2" Valve # 8 4-1/2" Camco MMG GLM with 1-1/2" Valve # 7 4-1/2" Camco MMG GLM with 1-1/2" Valve # 6 4-1/2" Camco MMG GLM with 1-1/2" Valve # 5 4-1/2" Camco MMG GLM with 1-1/2" Valve # 4 4-1/2" Camco MMG GLM with 1-1/2" Valve # 3 4-1/2" Camco MMG GLM with 1-1/2" Valve # 2 4-1/2" Camco MMG GLM with 1-1/2" Valve # 1 4-1/2" Camco MMG GLM with 1-1/2" Valve Baker 192-47 Model EBH-22 Anchor Seal Assy. L= .70' Baker SB-g Permanent Packer Baker Mill-out Extension Camco "SWS" Nipple Camco "SXN" Nipple Baker Bullnose Shear-Out Sub Fish/Fill Information: A. Tag Fill ~ 10,890' 7/27/93 B. Lost Camco 1.5" Valve 7/27/93 C. Lost blades from production log 2/17/94 D. Tag fill ~ 10,888' 6/10/95 E. Tight spot ~ 9,900'. Tag fill ~ 10,830' 11/1/97. Tight spot ~ 9,900' 8/19/98 Perforations Date Zone Top BTM Comments 7/5/93 HB-1 10,202' 10,242' TCP 9/10/93 I-IB-1 10203' 10,248 3-3/8" HC 6 SPF 60 deg 11/25/94 HB-1 10,203' 10,248' 3-3/8" HC 6 SPF 60 deg 11/22/97 HB-1 10,200' 10,240' 3-3/8" HC 6 SPF 11/22/97 HB-1 10,455' 10,475' 3-3/8" HC 6 SPF 9/15/93 HB-5 10,590' 10,665' 3-3/8" HC 6 SPF 60 de# 2/19/94 HB-5 10,615' 10,675' 3-3/8" HC 6 SPF 60 deg 11/24/94 HB-5 10,590' 10,675' 3-3/8" HC 6 SPF 60 deg 11/7/97 HB-5 10,590' 10,710' 3-3/8" HC 6 SPF REVISED: 1/11/99 DRAWN BY: MWD UNOCAL RKB = 41' Rig Floor to TBG Hanger ¢ e e il t TOL ~ 9,989' Dolly Varh-~n Platform Well # 48 Proposed Casing and Tubing Detail SIZE WT GRADE CONN ID MD TOP MD BTM. 13-3/8" 61 J-55 Buttress 12.515 Surf. 2,099' 9-5/8" 47 L-80 Buttress 8.835 Surf. 10,182' 7" 29 L-80 8rd TKC 6.184 9,989' 10,968' Tubing: 4-1/2" 12.6 L-80 Mod-Buttress 2.992 40' 10,038 Jewelry NO Depth ID Item 1 40' 4.00" CIW 4-1/2" Type F/FBB Tubing Hanger: 4-1/2" EUE 8rd Box top x AB Mod Butt. Box BTM. 2 304' 3.812" Camco 4.5" TRDP-4A SCSSSV flapper type, (3.812" X-profile) 3 2,122' 3.833" # 11 4-1/2" Camco MMG GLM with 1-1/2" Valve 3,730' 3.833" # 10 4-1/2" Camco MMG GLM with 1-1/2" VaNe 4,783' 3.833" # 9 4-1/2" Camco MMG GLM with 1-1/2" VaNe 5,811' 3.833" # 8 4-1/2" Camco MMG GLM with 1-1/2" Valve 6,482' 3.833" # 7 4-1/2" Camco MMG GLM with 1-1/2" Valve 7,163' 3.833" # 6 4-1/2" Camco MMG GLM with 1-1/2" Valve 7,871' 3.833" # 5 4-1/2" Camco MMG GLM with 1-1/2" Valve 8,365' 3.833" # 4 4-1/2" Camco MMG GLM with 1-1/2" Valve 8,854' 3.833" # 3 4-1/2" Camco MMG GLM with 1-1/2" Valve 9,382' 3.833" # 2 4-1/2" Camco MMG GLM with 1-1/2" Valve 9,906' 3.833" # 1 4-1/2" Camco MMG GLM with 1-1/2" Valve 4 9,960' 3.958" Baker 192-47 Model EBH-22 Anchor Seal Assy. L= .70' 5 9,965' 4.75" Baker SB-g Permanent Packer 6 9,971' 6.00" Baker Mill-out Extension 7 9,983' 3.813" Camco "SWS" Nipple 8 10,027' 3.725" Camco "SXN" Nipple 9 10,038' 3.950" Baker Bullnose Shear-Out Sub Fish/Fill Information: A. Tag Fill @ 10,890' 7/27/93 B. Lost Camco 1.5" Valve 7/27/93 C. Lost blades from production log 2/17/94 D. Tag fill @ 10,888' 6/10/95 E. Tight spot ~ 9,900'. Tag fill @ 10,830' 11/1/97. Tight spot ~ 9,900' 8/19/98 Perforations Date Zone Top BTM Comments 7/5/93 HB-1 10,202' 10,242' TCP 9/10/93 HB-1 10203' 10,248 3-3/8" HC 6 SPF 60 deg 11/25/94 HB-1 10,203' 10,248' 3-3/8" HC 6 SPF 60 deg 11/22/97 HB-1 10,200' 10,240' 3-3/8" HC 6 SPF 11/22/97 HB-1 10,455' 10,475' 3-3/8" HC 6 SPF 9/15/93 HB-5 10,590' 10,665' 3-3/8" HC 6 SPF 60 deg 2/19/94 HB-5 10,615' 10,675' 3-3/8" HC 6 SPF 60 deg 11/24/94 HB-5 10,590' 10,675' 3-3/8" HC 6 SPF 60 deg 11/7/97 HB-5 10,590' 10,710' 3-3/8" HC 6 SPF DV-48 Proposed.doc REVISED: 4/19/99 DRAWN BY: MWD UNOCAL/DOWELL CTD RIG PIPING HAND CHOKE VENT LINE 2" 1502 5K PS~ CHOKE LINE KILL AND CHOKE LINE VALVES TO BE FLANGED TO FLOW CROSS HAND CHOKE 2" 1502 HIGH PRESSURE LINES ! 4" 5K TREE -'~-~11 ~'TO PROD MANIFOLD / ~ VALVE LINE ~J ~ BLEEDER LINE -- --~ PULSATION ~---~ DAM~--N E.i D/S C-PUMP ( ~ I BHI CHOKE MANIFLOD READOUT , LEGEND [] HIGH PSI LINE [] LOW PSI CHARGE [] LOW PSI LINE VALVE ACCUMULATOR ~ FILTER/SCREEN ,; /-~ CAP ,~ ~ HAND CHOKE ~ CHECK VALVE ~) PSI GAUGE ~) C PUMP '~ MICRO MOTION '~ HOPPER AGI'I'ATOR OAL Of Stack Up -- 37.416' 6.735" ID 5M Lubricator 8.0' BX155 x CO62 Thread X-Over 0.583' 4 1/16" Annular 2.083' CO62 Nut x BX155 X-Over 4 1/16" 10M TOT Quad BOPE 6.0' BX 155 x BX 155 Studded Flow Tee 2" ID Outlets 1.50' 0.75' BX 155 x BX 155 Riser Spool 17.0' R-39 x BX 155 X-Over Spool 1.50' < Wellhead to Rig Floor = 35.5' 2" Blind/Shear 2" Blind/Shear 2" Pipe 'Rams 2" Slip Rams D26 CT RD UNOCAL DOLLY VARDEN Platform D-48 slot #B1-9 McArthur River Field TBU, Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref: D-48Rd Ver. #5 Our ref: prop3314 License: Date printed: 12-May-99 Date created: 9-Feb-99 Last revised: 12-May-99 Field is centred on n60 50 4.803,w151 36 18.018 Structure is centred on n60 48 20.815,w151 38 22.052 Slot location is n60 48 27.523,w151 37 57.456 Slot Grid coordinates are N 2490760.071, E 208467.465 Slot local coordinates are 681.30 N 1220.20 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North D48rd Version 2.xls 1/2 6/1/99--1:37 PM UNOCAL DOLLY VARDEN Platform,D-48 McArthur River Field,TBU, Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref: D-48Rd Ver. #5 Last revised: 12-May-99 Measured Angle Azimuth Depth Degrees Degree TVD ectangular Coordinates Dogleg Vertical Deg/100ft Section 10 490.00 10 500.00 10 54O.OO 10 6OO.OO 10 700.00 10 800.00 10.826.32 10.900.00 10.901.28 11 000.00 11 100.00 11 200.00 11 300.00 11 349.99 11 400.00 11 500.00 11 600.00 11 700.00 11 798.70 28.46 24.71 30.65 20.54 40.36 8.29 44.92 342.41 61.99 311.21 83.97 289.62 90.00 284.50 93.79 270.25 93.85 270.00 94.92 250.23 95.41 230.15 95.25 210.06 94.46 190.01 93.85 180.00 94.46 169.99 95.25 149.93 95.41 129.85 94.92 109.77 93.85 90.00 9,543.21 9,551.91 9,584.47 9,628.94 9,689.21 9,718.62 9 720.00 9 717.55 9 717.47 9 709.85 9 700.75 9 691.35 9 682.80 9 679.17 9675.54 9 666.99 9 657.59 9 648.50 9.640.87 3380.86 N 1662.44 E 0 3747.49 3385.41 N 1664.33 E 30 3752.41 3407.86 N 1669.8 E 30 3775.08 3447.61 N 1666.17 E 30.03 3809.61 3511.82 N 1621.25 E 30.03 3848.98 3558.68 N 1539.32 E 30.03 3857.02 3566.38 N 1514.21 E 30.03 3853.45 3575.82 N 1441.38 E 20 3831.38 3575.82 N 1440.1 E 20 3830.84 3559.02 N 1343.62 E 20 3775.02 3509.77 N 1257.65 E 20 3694.18 3434.01 N 1193.85 E 20 3598.61 3340.88 N 1159.9 E 20 3499.84 3291.27 N 1155.55 E 20 3453.01 3241.65 N 1159.9 E 20 3409.82 3148.52 N 1193.85 E 20 3339.61 3072.77 N 1257.67 E 20 3297.72 3023.52 N 1343.64 E 20 3289.2 3006.73 N 1440.1 E 20 3314.54 All data is in feet unless otherwise stated. Coordinates from slot #B1-9 and TVD from wellhead (106.20 Ft above mean sea level). Bottom hole distance is 3333.81 on azimuth 25.59 degrees from wellhead. Total Dogleg for wellpath is 295.46 degrees. Vertical section is from N 17.26 E 7.97 on azimuth 24.87 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL DOLLY VARDEN Platform,D-48 McArthur River Field,TBU, Cook Inlet. Alaska PROPOSAL LISTING Page 2 Your ref: D-48Rd Ver. #5 Last revised: 12-May-99 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casin n/a 9543.21 3380.86N 1662.44E n/a 9543.21 3380.86N 1662.44E 9 5/8" Csg n/a 9543.21 3380.86N 1662.44E n/a 9640.87 3006.73N 1440.10E 7" Liner n/a 9543.21 3380.86N 1662.44E n/a 9543.21 3380.86N 1662.44E 13 3/8" Cas D48rd Version 2.xls 2/2 6/1/99--1:37 PM UNOCAI.~ Trading Bay Unit Dolly Varden Well D-48 CT. Lateral PROPERTY PLAT 29 GRAYLING 88 ADL-18730 Unocal Forcenergy / ADL-17594 Unocal Forcenergy D-48 [Trading [Bay Unit Boundary ADL-{7602 Unocal Forcenergy I SCALE IN FEET STEELHEA 9-48 Laterally'/ DOLLY 33 T9N TSN - R13W - R13W ADL-18729 Unocal Forcenergy ISO 9001 Certified UNOCAL DOLLY VARDEN PLATFORM WELL D-48 DEPTH INTERVAL WHIPSTOCK @ 10490' MD DRILL TO 11798' MD (9543" TVD) MUD TYPE FLO-PRO MUD ADDITIVES FLO-VlS, KCL, FLOTROL, CAUSTIC SODA, NACL, LO-WATE, {LUBETEX} POTENTIAL PROBLEMS HOLE CLEANING, HIGH TORQUE, DIFFERENTIAL STICKING, LOST CIRCULATION, GAS KICKS COST PER BARREL $26.75**-46.75 ESTIMATED ** Does not include lubricant or fluid loss control additive TM9912 (6/99) . . 3, . . . , . TREATMENTS/PROCEDURES Build mud with fresh water, FIo-Vis, KCL, and caustic soda and Greencide 25G. Displace well to new mud after setting whipstock. Higher hole angles increase the probability of cuttings bed formation. Monitor LSRV of the drilling fluid with a Brookfield Viscometer. Maintain a 1 minute LSRV of >_ 50,000 with FIo-Vis additions. Control solids by running the finest shaker screen size possible. Run centrifuge for removal of fine solids... Keep mud weights as Iow as possible. Mud weights should range from 8.55 ppg to 8.75 ppg. Note: Higher mud weights may be required. Report drill solids analysis on mud check sheet. Report hydraulics calculations on mud check sheet. Lo-Wate should be used as needed for a bridging agent to control seepage losses. NOTE: Maximum recommended Lo-Wate concentration for discharge purposes is 75 ppb. FIotrol should be used as needed for fluid loss control. NOTE: Maximum recommended Flotrol concentration for discharge purposes is 3 ppb. If torque is a problem. Lubetex should be added. Monitor decrease in torque with each % addition of Lubetex. NOTE: Maximum recommended KCL concentration for discharge purposes is 3% (10.33 ppb) NOTE: DISCHARGE IS GENERALLY NOT PERMISSABLE IF A LUBRICANT IS ADDED TO THE SYSTEM! 3 314" Hole Mud Formulation Fresh Water FIo-Vis 2.75 ppb KCL 10.33 ppb Caustic Soda .25ppb Grencide 25G 0.04 ppb Lo-Wate As needed for seepage losses Flotrol As needed for fluid loss control Lubetex As needed for torque reduction ANTICIPATED MUD PROPERTIES Mud Density 8.55 PPG LSRV 1 minute 50,000 cps Plastic Viscosity 8 - 10 cps Yield Point 40 - 45 #/100~ Gels 25/27/30 #/100~ APl Fluid Loss 6 - 8 cc pH 8.5 -9.5 MBT <2.5 ppb Drilled Solids <15ppb Note: This mud program is a guideline only. Hole conditions should dictate actual mud properties. DO NOT EXCEED Recommended M.A.C. of products or use products not approved in the old discharge permit. UNOCAL DOLLY VARDEN PLATFORM WELL D -48 ESTIMATED FLUID COST Estimated drilling fluid cost based on 8.55 mud weights Estimated cost with 3% Lubetex Estimated cost for polymer breaker (per bbl) $17,548 $31,223 $15.75 Unocal Alaska Resoun Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCA- June 15,1999 Mr. Robert N. Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 TRADING BAY UNIT Well D-48 APPLICATION TO DRILL AND COMPLETE ADL- 18729 Dear Chairman Christenson: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to drill, complete and produce Trading Bay Unit State well D-48 in the McArthur River Field "Hemlock Zone" pursuant to Rule 5, Conservation Order No. 80. The proposed completion of the well will result in additional recovery of Hemlock Production. Your approval of this request is appreciated. If you require additional information, please contact Dan Thomas at 907-263-7624, or Hal Martin at 90%263-7675. Very truly yours, Enclosures TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 12, 1999 ADMINISTRATIVE APPROVAL NO. 80.76 Re: The application of Union Oil Company of California (UNOCAL), operator of the Trading Bay Unit (TBU), to drill and complete the TBU D-48 L1 well as part of the pressure maintenance project approved by Conservation No. 80. Mr. Kevin A Tabler Landman UNOCAL Corp P. O. Box 190247 Anchorage, AK 99502-0247 Dear Mr. Tabler: Your application dated June 15, 1999 for a "Permit to Drill" TBU well D-48 L1 is proposed to recover additional oil from the Hemlock oil pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling and completion of the TBU D-48 L 1 well pursuant to Rule 5 of Conservation Order No. 80. DONE at Anchorage, Alaska and dated July 12, 1999. Robert N. Christenson, P.E. Chairman Camill~ Oechsli David W. J~hnston Commissioner Commissione~~ BY ORDER OF THE COMMISSION 1031548 16-JUN-99 2003568 DISCOUNT NET ~.00 100.00 .00 lO0.00 DATE iNVOICE/CREDIT MEMO NO. 16-JUN-99 DRILLPERMITD48 FORM 4-2B181 (REV. 11-95) PRINTED IN U.S.A. VOUCHER NO. 06993000246 GROSS 100 10o CITIBANK DELAWARE 62-20 A Subsidiary of Citicorp 311 ONE PENN'S WAY NEW CASTLE, DE 19720 Union Oil Company of California Accounts Payable Field Disbursing UNOCAL PaYone Hundred Dollars And 00 ****************************** 2003568 To the order of STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DR ANCHORAGE, AK 99501 aC] Date Check Amount V 16-JUN-99 *****100.00 Void after six months from above date. 3 q ~. l, 43 & 3 ?," WELL PERMIT CHECKLIST COMPANY dev ~ redrll FIELD & POOL ADMINIS iI~ATION WELL NAME'~',~;'~.,4 Z/')-~"~...~ PROGRAM: exp INIT CLASS _~.,,~ l-,::~/"fi - GEOL AREA ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... APPR' DATE Y N Y N Y N Y N Y N ¥ N Y N Y N ¥ N ¥ N Y N 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate. wellbore separation proposed ............. 23. if diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to _~ (~¢x-) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... serv ~,, wel?~bore se_g ..~ ann. disposal UNIT# /~ ~' ~_~ ON/OFF SHORE GEOLOGY 29. Is presence of H2S gas probable ................. Y 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory~ly] Y N ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, this pla_n (A) will contain waste in a suitab_.b.~iving zone; ....... Y N (B) will not contaminate~.esffwater; or cause drilling was~.te... Y N to surface; ~ ~ (C) will not imp?.~3idmechanical integrity of~ell used for disposal; Y N (D) will not ~'~mage producing formation or impair recovery from a Y N pool; an'd- (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N para req .. GEOLOGY: ENGINEERING: UIC/Annulpr-- COMMISSION: / ,' JDH~ RNC -~ ~ co - ~ ~/~./~.~ Comments/Instructions: c:\msoffice\wordian\diana\checklist