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196-013
Schwartz, Guy L (DOA) 1GKP 0(3 From: Schwartz,Guy L(DOA) Sent: Monday,April 13,2015 10:52 AM To: 'Juanita Lovett' Cc: samantha.carlisle@alaska.gov Subject: RE:Withdraw Sundry#314-220/PTD 196-013 - GP#54 Juanita, AOGCC will withdraw sundry 314-220 as requested. The sundry workscope was to pull and replace an ESP. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Juanita Lovett [mailto jlovett©hilcorp.com] Sent: Friday, April 10, 2015 2:20 PM To: Schwartz, Guy L(DOA) Subject: Withdraw Sundry # 314-220/ PTD 196-013 - GP #54 Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Thank you, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Office: (907)777-8332 ! AWED • Email: ilovett@hilcorp.com 1 XHVZE Pages NOT Scanned in this Well History File 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 COMMENTS: Scanned by: Beverl~"~n~ncent TO RE-SCAN Nathan Lowell Date: ~ ,.-c~(~ /s/~ Notes: Re-Scanned by: Be~,edy Dianna Vincent Nathan Lowell Date: Is~ • OF P"-as • �\��/// `sA THE STATE f � �Iz.� �`� Eac_ G c r7 -_ rr-v "` r 5 i 333 West Seventh Avenue GOVERNOR SEAN PARNElI. Anchorage, Alaska 99501 3572 Main: 907 279 1433 �� Fox. 907.277 7542 SCONED J U L. 2 2 20 4 Ted Kramer o 13 Sr. Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Point 54 Sundry Number: 314-220 Dear Mr. Kramer: 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, i` e-,v Cat y P. oerster Chair DATED thisy of April, 2014. Encl. . . RECEIVED STATE OF ALASKA APR 0 7 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate❑ PuN Tubing 0 = Time Extension❑ Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate❑ Alter Casing 0 Other: Replace ESP 0 ' 2.Operator Name: 4.Current Well Class: 5.Permit to DWI Number: Hilcorp Alaska,LLC Exploratory ❑ Development . 196-013 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20470-00• 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? WA Will planned perforations require a spacing exception? Yes ❑ No 0 Granite Point 54 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018761 Granite Pt/Middle Kenai Oil 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): 14,086 • 10,186 - 13,976 • 10,145 . N/A 11,318(fish) Casing Length Size MD ND Burst Collapse Structural 182' 33" 229' 228' Conductor 247' 26" 294' 293' • Surface 1,073' 13-3/8" 1,120' 1,119' 3,450 psi 1,950 psi Intermediate 3,565' 9-5/8" 3,611' 3,334' 6,870 psi 4,760 psi Production 11,949' 7" 11,994' 9,960' 8,160 psi 7,020 psi Liner 2,474' 5" 14,070' 10,182' 8,290 psi 7,250 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-7/8" 6.4#/L-80 9,240' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A and N/A N/A and N/A 12.Attachments: Description Summary of Proposal E • 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch CI 4 Exploratory 0 Stratigraphic❑ Development 0' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/15/2014 Oil 0' Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature ` Phone (907)777-8420 Date 04/07/14 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �/ kK- 220 Plug Integrity 0 BOP Test EK Mechanical Integrity Test 0 Location Clearance ❑ Other: $ 2_5o6 rs - zd/ Tr RBDMS MAY 1 0 2014 Spacing Exception Required? Yes 0 No C Subsequent Form Required: /Q— `�D�l APPROVED BY Approved by: , COMMISSIONER THE COMMISSION Date: 4., - /C—(' 11/411 -?Ka 417111 4te W4/,, e .l,r vliclill 1 ®� A Submit Form and Form 10-403(Revised 10/2012) Ap o e [`�'_ 11 II o 12 months from the date of approval. Attachments in Duplicate Well Work Prognosis• • Well: GP-54- Nilcorp Alaska,LLC Date: 04/07/14 • Well Name: GP-54 API Number: 50-733-20470-00 Current Status: ESP Producer Leg: #4,SE Corner Slot#3 Estimated Start Date: April 15,2014 Rig: _ Moncla 404 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 196-013 First Call Engineer: Ted Kramer (907)-777-8420(0) (985)-867-0665(M) Second Call Engineer: Dan Taylor (907)777-8319 (0) (907)947-8051 (M) AFE Number: Budgeted Cost: Current BHP: ' 2,000 psi @ 9,875'TVD/12,750' MD 0.20 psi/ft at mid-perf Max Expected BHP: "'2,000 psi @ 9,875'TVD/12,750'MD 0.20 psi/ft(No new perfs) Max.Anticipated Surface Pressure: 0 psi Using 0.435psi/ft SW gradient to surface Brief Well Summary GP-54 is a producer with a combination ESP&Gas-Lift completion.The ESP experienced a down-hole failure April 2014.We plan to pull and replace the ESP. No perforations will be added. Procedure: 1. MIRU Rig. 2. RU wire-line and shift open sliding sleeve at 11,188'. RU and circulate hydrocarbon off the well to production. 3. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. POOH with tubing string and ESP pump laying down the same. 5. PU, RIH with combination Gas-Lift/ESP completion. 6. Land ESP with the bottom of the assembly at+/-11,386'. 7. ND BOP, NU wellhead and test. 8. Turn well over to production. 9. RDMO Rig. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Wellhead Diagram 4. BOP Drawing . II Granite Point Platform Well# GP-54 Final Hileurp Alaska,ILK 3/25/14 API#50-733-20470-00 RKB=43ft CASING AND TUBING SIZE WEIGHT GRADE CONN TOP BTM I D (Ib/ft) (ft) (ft) 294' 26" 33" Outside Conductor 47 229 r o 26" Inside Conductor 47 294 13 5/8" 68 K-55 BTC 47 1,120 • 9 5/8" 47 L-80 BTC 46 73 1,120' 13 3/8' 1-1:19 5/8" 53.5 P-110 BTC 73 3,611 • 7" 29 P-110 KC-BTC 45 5,960 • 1 3,611' l D 9 5/8" 7" 29 L-80 TKC-BTC 5,960 11,994 • 5" 15 L-80 ' SC-KC-BTC 11,596 14,070 TUBING I D 2 7/8" 6.4 L-80 EUE SURF 11,500 JEWELRY DETAIL I D NO. DEPTH Drift ID ITEM 2494' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch III U 2 4723' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch 6664' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch 1 8184' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch 3 9277' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch OLSIMO 10142' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch 11,289ft 5.49 10812' 2.347" SFO-1 Mandrel w/1" Orifice Valve BK Latch 11,3615 1.834 11,4565 411 I 2 11,188' 2.312" 2-7/8" NEXA Sliding Sleeve (Open Up) — Baker 3 11,230' 2.312" 2.31" "X" Nipple 11,596' g s"HMC 4 11,278' ESP (BTM Depth = 11,386') hanger L 11,994' PERFORATION DATA TOP BTM TOP BTM ZONE SPF DATE COMMENTS (MD) (TVD) (TVD) (TVD) . . C-5 11,976 13,970 9,681 10,143 C-5 6 1-24-97 TCP 12,090 12,100 9,734 9,738 C-5 6 2-23-14 E-Line C-5 Max Hole = c-5 Angle=80° — @ 12,354' 5" PBTD=13,976' Granite Point Platform . II PROPOSED Well# GP-54 Final Hileora Alaska,L11 3/25/14 API#50-733-20470-00 RKB=43ft CASING AND TUBING SIZE WEIGHT GRADE CONN TOP BTM I D (Ib/ft) (ft) (ft) 294' 26" 33" Outside Conductor 47 229 26" Inside Conductor 47 294 L D 13 5/8" 68 K 55 BTC 47 1,120 9 5/8" 47 L 80 BTC 46 73 1,120' L D 13 3/8' 9 5/8" 53.5 P-110 ' BTC 73 3,611 7" 29 P-110 KC-BTC 45 5,960 17" 29 L-80 TKC-BTC 5,960 11,994 3,611' I D 9 5/8" . 5" 15 L-80 SC-KC-BTC 11,596 14,070 TUBING I D 2 7/8" 6.4 L-80 EUE SURF ±11,500 JEWELRY DETAIL L D NO. DEPTH Drift ID ITEM ±2494' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch CLQ] 2 ±4723' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch ±6664' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch 1 ±8184' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch V a 3 ±9277' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch DLS r ±10142' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch 11,289n 5.49 ±10812' 2.347" SFO-1 Mandrel w/1" Orifice Valve BK Latch 11,361ft 1.83 11,456ft 4.11 4 2 ±11,188' 2.312" 2-7/8" NEXA Sliding Sleeve (Open Up) Baker 3 ±11,230' 2.312" 2.31" "X" Nipple 11,596' g s"HMC 4 ±11,278' ESP (BTM Depth = 11,386') hanger 4. 11,994' 7 PERFORATION DATA TOP BTM TOP BTM ZONE SPF DATE COMMENTS (MD) (MD) (TVD) (TVD) C-5 11,976 13,970 9,681 10,143 C-5 6 1-24-97 TCP 12,090 12,100 9,734 9,738 C-5 6 2-23-14 E-Line C-5 Max Hole = C-5 Angle=80° @ 12,354' 5" PBTD=13,976' Granite Point Platform GP-54 Current Hiker"'ALi a',I.l.�: 04/07/2014 Granite Point Tubing hanger,FMC-TC- GP-54 B-EC,11 X3 X TC-2 lift 133/8X95/8X7X3 X andsusp,w/3"typeH BPV profile,300-4 pocket,3-K"continuous control line SHTA,Bowen,3 1/8 SM FE X 3"Bowen union top Ill iIMMIs !illi � Valve,WKM-M,3/18 5M FE, ... HWO,DD trim - , R +L) Valve,SSV,WKM-M,3 1/8 .. ... SM FE,w/15"OMNI oper, 'M' EE trim Valve,WKM-M,21/165Mii FE,HWO,DD trim I� nM\ oqpifiC0 r oft Valve,WKM-M,3/18 5M FE, '� HWO,00 trim -• - Adapter,FMC-A-S-EC,11 SM Rot Rg btm X 3 1/8 5M Stdd top,w/300-4 pkt,w/3-K CCL ports,EE material, prepped for BIW penetrator EEill _ 1 -.-AA = -! Completion spool,FMC, III 'I- I U I C-29L,11 SM FE X 13 5/8 SM —�: — API hub,17"in length _ 0 = O O ° - o 0 � ..,- 4,- ..• ..--,H / ?, 1� 1t mom_. _i� rir;l E -�.i. I. = 711.1.im,mot s� .� .� - '2 Unihead,Kvaerner SMS, • whom • Um1�`p- �,O'!• a-I. 3 step system,13 5/8 5M API F ti - Hub top X133/8 BIC casing �1�11i .'1 � B - bottom,w/2-2"LPO, ■ 4-21/16 SM S5O •� _, . - ni= I A=M16,7974 IV' ill I— il 1, .11=1 IIII ; - /33/8" 9 5/8" 3'A or 2 7/8 Granite Point Platform • a GP-54 ESP pull 04/07/2014 Hilrnrp '164'1.113A. -- - vpipplk llII Shaffer 13135/8SMSM II.l. ilIllI.tllei I mom I Emu- iron CIW-U II glill" :1 ...,e Variable 27/8-5 4.67' _— _ © . _ 13 5/8-5000 — = Blind Rams MIM . . -.. - N. Iii Iii Iii Ill iii .1111.111.11 1 Choke and Kill Valves I2 1/16 SM w/Unibolt connections for 1 ,'i MIN.! Ill III ip, . hoses 1 N r, rg 13 5/8-5000" i W�r1 �- III Iii mail lil g IIIII I.1 III III Riser,13 5/8 5M FE X 13 5/8 5M API#13 hub 17.00' Ild Ell Crossover spool 1.75' 13 5/8 SM API hub X 11 5M FE iii III lit III ii 18.31' Wellhead to deck , STATE OF ALASKA RECEIVED ALA_ k OIL AND GAS CONSERVATION COMA .ON • REPORT OF SUNDRY WELL OPERATIONS APR 0 1 2014 1.Operations Abandon ElRepair Well ElPlug Perforations 0 Perforate E] Other Other L� Performed: Alter Casing❑ Pull TubingEl Stimulate-Frac ❑ Waiver❑ Time Extension❑ L (a--S-t) Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 196-013 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service❑ 6.API Number: Anchorage,AK 99503 50-733-20470-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018761 • Granite Point 54 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): „ Granite Pt/Middle Kenai Oil 11.Present Well Condition Summary: Total Depth measured 14,086 feet Plugs measured N/A feet true vertical 10,186 feet Junk measured 11,318 feet Effective Depth measured 13,976 feet Packer measured N/A feet true vertical 10,145 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural 182' 33" 229' 228' Conductor 247' 26" 294' 293' Surface 1,073' 13-3/8" 1,120' 1,119' 3,450 psi 1,950 psi Intermediate 3,565' 9-5/8" 3,611' 3,334' 6,870 psi 4,760 psi Production 11,949' 7" 11,994' 9,960' 8,160 psi 7,020 psi Liner 2,474' 5" 14,070' 10,182' 8,290 psi 7,250 psi Perforation depth Measured depth 11,976-13,970 feet h 2 �r 1 f, True Vertical depth 9,681-10,143 feet WANED ANED MAYg ZtU1`f Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.4#!/L-80 11,278'(MD) 9,240'(TVD) Packers and SSSV(type,measured and true vertical depth) N/A N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDM s4MAY 14 2014 Treatment descriptions including volumes used and final pressure: ' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 435 154 0 650 71 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El Service 0 Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil 12 Gas 0 WDSPL❑ GSTOR 0 WINJ ❑ WAG El GINJ El SLAP El SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Numbey or N/A if C.O.Exempt: 313-124 • Contact Dan Taylor Email dtaylor@hilcorp.com Printed Name Dan Ta Title Operations Engineer • Signature .... .--APhone (907)777-8319 Date 3/31/2014 $ -2(-/'-f Form 10-404 Revised 10/2012 1 ,mac Submit Original Only Granite Point Platform Well# GP-54 ir4eorp Alaska,i,i,c; Completed: 3/25/14 API#50-733-20470-00 RKB=43ft CASING AND TUBING SIZE :lb/ft) EIGHTGRADECONN TOP BTM (ft) (ft) 294' 26" 33" Outside Conductor 229 26" Inside Conductor4747 294P [ 13 5/8" K-55 BTC 47 1,120 9 5/8" 47 L 80 BTC 46 73 1,120' 13 3/8' 9 5/8" 53.5 P-110 BTC 73 3,611 a 7" 29 P-110 KC-BTC 45 5,960 1 3,611' iml 95/8" 7" 29 L-80 TKC-BTC 5,960 11,994 5" 15 L-80 SC-KC-BTC 11,596 14,070 TUBING • 2 7/8" 6.4 L-80 EUE SURF 11,278 JEWELRY DETAIL NO. DEPTH Drift ID ITEM 2494' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch 2 4723' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch 6664' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch 1 8184' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch Am 3 9277' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch DLS 10142' 2.347" SFO-1 Mandrel w/1" Press. Valve BK Latch 11,289ft 5.49 10812' 2.347" SFO-1 Mandrel w/1" Orifice Valve BK Latch 11,361ft 1.83 11,456ft 4.11 4 2• 11,188' 2.312" 2-7/8" NEXA Sliding Sleeve (Open Up) Baker 3 11,230' 2.312" 2.31" "X" Nipple 11,596' 5 HMC hanger 4 11,278' ESP (BTM Depth = 11,386') 11,994' 7" PERFORATION DATA TOP (ft) BTM (ft) ZONE SPF DATE COMMENTS 11,976 13,970 C-5 6 1-24-97 TCP C-5 12,090 12,100 C-5 6 2-23-14 E-Line C-5 Max Hole = C-5 Angle=80° — @ 12,354' S„ PBTD=13,976' Hilcorp Alaska, LLC Hih.urpWell Operations Summary Well Name API Number •Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 Daily Operations: 12/20/13-Friday Finish r/d rig watch system,pull doghouse off subbase,r/d circulating lines from mud manifold&remove manifold,r/d all service lines except break- water lines from master skid to sub-base,r/d rear cellar wind wall tarps&frames,r/d panic line from choke manifold,r/u equalizer sheave bridle lines,remove tugger f/ODS floor,remove front lower wind wall/floor sections from master-skid,r/u jacks t/skid sub-base. Housekeeping,rolling up electric cables&tie off,clear unnessary eq f/south drill deck. 12/21/13-Saturday R/u skid power pack,unable to stroke jacks,troubleshoot&repair,skid rig west&install rear clamps t/master-skid,install tuggers t/skid beam brackets,hang pullover line t/crown,pull mud-cross from cellar,cont clear south drill deck,skid rig east to back side of leg 3,tq clamps,(tq gun failed just over half way through process get one coming from vendor)move drill line spooler,roll up&move skid power pack. Spot pits in front of sub- base,clean decks,spot derrick stand,clean&clear center deck passage. Received new tq wrench&finished tq skid beam clamps. 12/22/13-Sunday Cont housekeeping,sort rigging,complete Derrick inspection&walk around thaw air line to clutch, lay derrick over t/stand,r/d derrick board, remove landings,spot at welding shop for winterization. Install block cradle to derrick,r/u&unstring blocks,r/d winch lines&power swivel lines. 12/23/13-Monday R/d Bridle lines,l/d blocks,equalizer&block cradle,break off upper derrick section w/crown&l/d,blow down break water lines&r/d,unpin lower& mid section of derrick&l/d,load boat w/derrick sections&eq to Bruce for storage,move pits,r/u jacks to subase&skid west toward center deck. 12/24/13-Tuesday Finish skidding west,r/d"A"leg's,pull roof from d/w skid,prep&pull draworks skid from master skid,set on blocks&start welding repair,backload boat,remove north stairs&landing,remove north roof panels,pull rear strongback beam. 12/25/13-Wednesday Rigging up. 12/26/13-Thursday Rigging up. 12/27/13-Friday Rigging up. 12/28/13-Saturday Rigging up. 12/29/13-Sunday Rigging up. 12/30/13-Monday Rigging up. 12/31/13-Tuesday Rigging up. 01/01/14-Wednesday Rigging up. 01/02/14-Thursday Function test blind rams. MU test jt&RIH.Function test BOPE-good.Fill pits w/FIW. Continue with rig up. Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 01/03/14-Friday Finished RU of all equipment and winterization. Tested annular preventer 250 psi low and 3500 psi high. Tested pipe rams and manifold valves to 250 psi low and 5000 psi high. Lou Grimaldi,AOGCC Inspector,witnessed test. Seals on BPV or hanger gave up,could not continue testing BOP's. Attempted to pull running tool/test joint, joint broke apart. Locked connection and let set for 1 hr to set up. Backed out test joint. Test sub between running tool and test broke,attempted to repair and could not make any progress. 01/04/14-Saturday HSM. Attempted to pull test joint,test joint backed out at 4-1/2 IF connection above running tool. Drained BOP stack,removed clamp on riser/wellhead. PU Bop's/riser,removed running tool from top of tbg hanger.Landed BOP/Riser back on wellhead. MU clamp and torqued up clamp bolts.Pressured up on annulus to 400 psi,could see fluid coming up inside hanger neck above BPV. Could not tell if dart seals or BPV body seals were leaking. MU Test joint and landed test joint in top of hanger,loaded BOP/riser with clean fluid,pressure up against TIW,Pipe Rams,and both inside manual valves on flow cross,pressured up to 250 psi,charted for 5 min,tested good. Attempted to pressure up to test,could not pressure up.Talked over with Lou Grimaldi,AOGCC Rep,decided to pressure up on annulus to 2500 psi and get a high test against clamp,tested and charted clamp seal for 30 mins at 2500 psi.Tested good. Bled pressure off annulus and BOP's,removed test joint. Pulled Dart out of BPV. Pulled BPV,redressed both and landed them back in hanger.Tested blinds rams to 250 psi low and 5000 psi high,tested good. Bled pressure off,opened blinds,installed test joint,loaded test joint,closed TIW,Pipe rams,both inside manual flow cross valves and test 250 psi low and 5000 psi high,tested good. Closed both HCR valves and open both manual valves and tested 250 psi low and 5000 psi high. Tested good. Performed accumulator test,and gas detection test with inspector. All tests good. Pulled test joint.Removed dart out of BPV,removed BPV. MU Pack-off plate retrieving tool. RIH and engaged pack- off plate. PU to 76K on blocks. Pens sheared and POOH w/pack-off plate. /). Cl f 01/0-V - unday HSM.MU Tubing hanger retrieving tool,landed RT in top of hanger. POOH W/Hanger with 47k up weight. Hung 3-1/2"Buttress in slips,broke off tbg hanger. MU Pump in sub and TIW valve,circulated 120 Bbls of filtered inlet water down tbg out annulus to ensure tbg clean to run camera.MIRU E- Line Unit and camera. RIH to 11,396'ELM to top of fish,fish covered with fill. POOH W/E-Line.RDMO.Laid down Pump-in sub and TIW.Started PU singles,3-1/2"PH-6 WS. As of 6 pm we had TIH W/40 joints.Continue to Strap and TIH W/3-1/2"PH-6 WS to bottom,total of 235 joints,tagged top of fish at 11,326'. RU power swivel,and started circulating filtered inlet water. .1-014.4 .- HSM. / 114 HSM.Continued circulating filtered inlet water. Circulated total of 620 Bbls of filtered inlet water down annulus out tbg to production. MIRU E-Line Unit with down hole camera. RIH,attempted to video top of fish,side image was as clear,bottom image was not.Camera appeared to have oil on lens.Top fish @ 11,310'ELM.POOH,did have oil film on bottom camera lens.Cleaned camera and RBIH to bottom,attempted to take images again, appeared to be debris falling on top of fish,attempted to pump filter inlet water across camera to clean up picture. Lost all visibility once started pumping,pumped for 20 mins from 1/2 to 1-1/2 Bbls,would not clean up. POOH W/camera.RDMO E-Line Unit.MU Power swivel on 3-1/2"WS. Checked out torque tolerances down hole. Was able to turn @ 5K with 80 RPM's,see no need for down hole motor to run mill. RD Power swivel. Started SOOH W/3-1/2"WS.Continue SOOH W/117 stands of 3-1/2"PH-6 WS,laid down total of 27 joints of 3-1/2"buttress kill string. 01/07/14-Tuesday ,~ HSM.Continue TOH laying down 3-1/2"Buttress kill string,laid down total of 129 joints onto flying pipe rack.MU wear bushing running tool. RIH and set wear bushing in wellhead,released of running tool. POOH W/landing joint.MU BHA#1,6"Concave Mill,2-5"Boot baskets,2-5"magnets, Bumper Jar,oil jar,(6)4-3/4"drill collars,Total Length 240.35'.TIH W/117 stands of 3-1/2"PH-6 WS,started PU singles off deck,PU total of 122 singles of 3-1/2"PH-6 WS.Tagged top of fish @ 11,321'. MU power swivel on 4 ft pup,hooked up pump lines and bell nipple.PU weight of pipe and power swivel is 172k,down weight of WS is 110k,Rotating weight 130K. Kicked pumps on @ 2BBIs/min started milling on fish,pump pressure around 400 psi. Milled for approx 2 hrs,made 8-10 inches,stopped milling and walked pump up to 4.8 Bbls/min,circulating bottoms up to ensure clean @ 615 psi. Hilcorp Alaska, LLC Hileorp Alaska,LL( Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 01/08/14-Wednesday HSM.Circulated 4.8 Bbls per min for 90 min. Approx.440 Bbls after stopped milling. RD Power swivel and pump lines.SOOH W/3"WS,SB drill collars,laid down jars,magnets,and boot basket. Broke out mill. Visible that something down hole is rotating.MU Mule shoe on 3"WS.TBIH W/ 187 stands and PU 7 singles of deck. TIH to bottom,tagged TOF @ 11,322'.Circulated 5 Bbls of diesel,10 gallons of rig wash and 945 Bbls of filtered inlet water down the annulus out tbg to production @ 2 Bbls/min,caught samples throw-out process. Shut down pump. MIRU E-Line and Down hole camera.Pumped 30 bbls down the tubing for pad and started in hole continuously pumping 1 bbl/min. 01/09/14-Thursday HSM.Finished circulating hole clean,approx.850 Bbls @ 2 Bbls/min. RU E-Line Unit and camera.Checked camera and light on surface,all looked good. RIH to 11,322',could not see any images,all black. While going in hole noticed drilling mud on rig floor from E-Line pack-off,was informed of a caliper log previously run with mud problems.POOH W/camera,camera had mud film from top to bottom and on lenses. Cleaned camera and pumped 100 Bbls flush down tbg to clear of muddy water.MU new camera and attempted to go back in. Run camera down to 3,500 ft with clear picture of inside of tbg. While running in hole attempted to clean E-Line with pressure washer. Stopped at 3,500 ft because of cloudiness,set for 1 hr to see if it would clear up,no change.Kicked pump on at 1 Bbls/min and lost all ability to see. POOH W/camera again had film of mud on camera.RD E-Line and camera.Hooked circulation lines back up and Circulated 3 Bbls per min,approx.650 Bbls down tbg out casing to GP tank farm. Shut pump down at 5 pm.RU E-Line Unit and camera and RIH. RIH to bottom @ 11,320',encountered debris(mud)piled up in front of fish. Attempted several times to get closer and recover better picture.Each time we moved had to sit and wait for dust to settle back out.POOH,no pictures of fish. RDMO E-Line unit. Started SOOH W/3"PH-6 WS,SOOH W/51 stands.Rig manifold and turbo got hot,shut down for 30 mins to let cool. Tried to pull again,SOOH W/2 stands and got hot again. Shut down for 1 hr to let cool. Tried again,got confirmation of temp up to 965 degrees,SOOH W/7 stands and temp shot up above 1100. Fuel alarm going off on ECM panel,shut down completely at 5:30 am. 01/10/14-Friday "4 HSM.Shut Rig down til 8 am to let cool off.Unhooked brake assist.Continued SOOH W/3"PH-6 WS,SOOH WI Remaining 119 stands,laid down Mule Shoe.Rig manifold and turbo never got hot again. SOOH.MIRU Slick line Unit. MU 3"Pump Bailer,RIH,tagged top of fish @ 11,342'wlm.Worked bailer several times.POOH.Recovered full bailer of metal shavings and mud debris. RBIH,tagged same depth,worked bailer several times,POOH. Recovered very little sample in bailer. MU 4"Rare earth magnet.RIH,tagged bottom at 11,342'.WT several times,POOH. Recovered a hand full of fine shaving.MU 4"LIB,RIH and tagged bottom @ 11,342'wlm,POOH,no picture on LIB. RBIH W/same LIB,stroked bottom harder and POOH,LIB had metal marks,but nothing significant could be determined. MU BHA#4,Tubing spear dressed with 3-1/8"grapple,Drain Sub,Bumper jar,oil jar, 6 drill collars and accel jars. TIH W/BHA and total of 179 stands of 3"PH-6 WS,Tagged bottom with spear @ 11,322'. Worked spear up and down for approx.1 hr.could not get any over pull or drag while working tool. Started SOOH,SOOH W/63 stands of 3"PH-6 WS. 01/11/14-Saturday HSM.Continued SOOH W/3-1/2"PH-6 WS,laid down spear,no determining factor on spear visible.MU BHA#5,6"OD X 4-7/8"ID Shoe,1jt of 5" wash pipe,Double boot baskets,stabilizer,double magnets,bumper jar,oil jar,(6)4-3/4"drill collars,total length 276.85'. TIH W/BHA on 178 stands of 3-1/2"PH-6 WS.RU Power swivel and pump lines. MU on 3-1/2"PH-6 WS,tagged top of fish with burn shoe,set torque to 8500.PU off fish, started circulating @ 3 Bbls/min rate.Up weight of BHA 5 and swivel is 166k,down weight of 96K,Rotating weight of 130 K. Tagged top of fish @ 11,322'at 3 am and began burning over fish,took approx.1 hr to make it through first 2 ft, went fairly easy next 21 ft.tagged top of packer @ 11,345'. Started circulating hole clean. Hilcorp Alaska, LLC HincurpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 ds 01/12/14-Sunday HSM.Finished circulating bottoms up,total 650 Bbls circulated at 4.4 Bbls/min. SOOH W/total of 178 stands of 3-1/2"PH-6 WS,SB 6 drill collars, laid down jars,laid down 1 jt of wash pipe and burn shoe. Shoe worn to 50 percent.MU Test plug on test joint,landed plug and began testing Bop's. Tested annular to 250 low 3500 high,tested bop's and valves to 250 low and 3000 high,Tested and recalibrated Gas detection system,performed tests on accumulator,All tests good.Witness waived by Jim Regg,AOGCC. Pulled test plug.MU BHA#6:5 3/4"OD Bull dog Box tap,safety joint, pump out sub,bumper jar,and accel jar. TIH W/BHA 5 on 178 stands of 3-1/2"PH-6 WS.MU Power swivel,kicked pump on @ 2 bbl/min rate @ 100 psi pump pressure.Up weight 166 K,down weight 96K,rotating weight 130K,sat down on top of fish @ 11,324',engaged fish,jarred down on top of fish,put torque in pipe to tighten down on fish with box tap.PU on WS and had 4k over pull,appears to have caught fish,to ensure fish,kicked pump on @ 1 bbl/min,pressured up to 500 psi before shutting down pump. 01/13/i4-Monday " HSM.RD Power swivel and pump lines.SOOH W/3-1/2"WS,laid down accel jar,SB drill collars,laid down bumper/oil jars,laid down pump out sub, safety joint and bull dog tap,recovered 7 inch piece of 3-1/2"tbg.MU BRA#7,6"OD,Overshot with flat bottom shoe ahead of it loaded W/3.5 grapple,pump out sub,bumper/oil jars,6 Drill collars,and accelerator jars. TL-231.14'.TIH to bottom with 3-1/2"PH-6 WS and BHA 7.TIH Total of 178 stands. Tagged top of fish @ 11,324'.RU power swivel,dressed of top of fish and swallowed at same time.Swallowed approx.5.5 ft.Down to 11,329'. Attempted to POOH,had 45K over pull and acted like we had fish. We attempted to jar down and swallow more of the fish several times, getting over pull every time.RD power swivel.SOOH W/178 stands of 3-1/2"PH-6 WS,laid down jars,SB Drill collars,laid down overshot. No fish recovered. Broke down overshot,there were no marks in mill control element or the grapple. MU BHA#8:Overshot W/upper extension dressed with 3.5 grapple,pump out sub,Bumper/oil jars,6 drill collars,and accel jars.TL-229.90'. TIH W/156 stands of 3 1/2 PH-6 WS and BHA 8. 0 1`4/ 4 ''uesdaY nr t,. HSM.Continued TIH\tw/Remaining 24 stands of 3-1/2"PH-6 WS. Tagged top of fish @ 11,322'. MU Power swivel,PU weight of 172K,Sat down on fish with overshot and engaged grapple at 11,326'.PU to 180,appeared to have fish,jarred down on fish to ensure grapple set good,PU to 200k. Started working jars from 200K-230K,jarred up on fish for approx.1 hr,fish started moving up hole dragging 30-50k over. SOOH W/180 stands of 3- 1/2"PH-6 WS,laid down accel jars,SB Drill collars,laid down bumper/oil jars,Laid down overshot with fish,total length of fish,41.6 ft,21.6 of tbg and 20 ft of seals.MIRU Slick-line Unit. RIH W/3.5 Rare Earth magnet,on 4.5 centralizer,tagged top of packer @ 11,350'wlm,POOH. Recovered 8" piece of 3.5 tbg. RBIH W/3.5 magnet,tagged top of packer same,POOH,Recovered 2 pieces of banding material and several thumb sizes pieces of metal. RBIH W/same,tagged same,POOH,recovered small finds/metal shavings. RBIH W/5"LIB,tagged TOP @ 11,351'.POOH. No visible marks. MU BHA#9,5-3/4"HT,6"OD X 4.5 ID Packer Shoe,Double boot baskets,stabilizer,double magnets,bumper jar,oil jar,(6)4-3/4"drill collars,acc. Jar, total length 258.94'. TIH W/BHA on 96 stands of 3-1/2"PH-6 WS. 01/15/14-Wednesday ` HSM.TIH w/remaining 84 stands of 3-1/2"PH-6 WS.MU Power swivel with single from deck.Hooked up pump lines. PU Weight 160K. Tagged top of packer @ 11,345'.Landed WS 2'off top of packer.Displaced filtered inlet water with diesel to production.Pumped 480 Bbls @ 3.3 Bbls/min down tbg out the annulus. PU weight 175K,Down weight 106 K,Rotating weight 134K. Started to burn over packer.Torque running around 8700 W/123k HKLD,2-3 K down. Burned on packer for approx.6 hrs. Burned 3'down to 11,350'.RD Power swivel and pump Lines. SOOH W/180 stands of 3-1/2" PH-6 WS.Laid down accel jars,SB Drill collars,bumper/oil jars,double magnets/boot baskets,and burn shoe. Shoe worn 85 percent. Hilcorp Alaska, LLC HiIcor!Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 01/16/14-Thursday HSM.MU BHA#10,5-3/4"HT,6"OD X 4.5"ID Packer Shoe,double boot baskets,stabilizer,double magnets,bumper jar,oil jar,(6)4-3/4"drill collars,acc.jar,total length 259.09'. TIH W/BHA on 180 stands of 3-1/2"PH-6 WS.MU Power swivel with single from deck,hooked up pump lines, broke circulation to pits.Tagged packer @ 11,350'.PU weight 175K,down weight 106K,and Rotating weight 134K. Started to burn over packer. Torque running around 8700 W/123k HKLD,2-3 K down on top of packer. Started burning over packer-stopped making hole after making first 18 inches.Turned pump off and burned over until started making hole again. Made approx.2.5'total and packer started moving down hole.Gas detection detected 4000 parts at pits after packer started moving. PU 5 more singles chasing to bottom.Pushed packer down to 11,576'.Circulated clean. 01/17/14-Friday HSM.Pushed packer down to liner top at 11,576'.Continued to burn over packer,while burning over tubing started to pressure up,attempted to PU off of packer,to recover circulation,could not recover circulation.Pressured up to 3400 psi on tbg. Shut pump down and bled pressure off tbg,laid down 1 joint of 3-1/2"PH-6 WS. MIRU E-Line Unit. RIH W/GR/CCL and 13'perforating gun. Located first joint above BHA and perforated 10 holes in joint. RDMO E-Line Unit and equipment.SOOH W/182 stands of 3-1/2"PH-6 WS.Laid down single with holes. 01/15/14-Saturday „...,o HSM.SB Drill collars,laid down bumper/oil jars,laid down burn shoe,recovered segment slips,packer element,and slip ring from packer.MU BHA #11,Short catch overshot loaded with 4.5 basket grapple,bumper jar,oil jar,(6)4-3/4”drill collars,acc.jar,total length 225.83'. TIH W/BHA on 182 stands of 3-1/2"PH-6 WS. PU 3 singles off deck. MU power swivel to engage and latch fish in overshot.PU weight 180K,Down weight 104K. Kicked pump on @ 2.8 Bbls/min with 170 psi circulating pressure,sat down on fish. Pump pressure climbed up to 460,shut pump down. Jarred down on fish a couple of times and attempted to PU,could not latch fish. RD Power swivel and pump lines. SOOH W/183 stands of 3-1/2"PH-6 WS.Laid down 1 single,accel jars,SB Drill collars,bumper/oil jars,overshot,grapple,top sub.MU BHA#12,4.75 OD X 2.75 ID Box Tap,Pump out sub,bumper jar,oil jar,(60 4-3/4"drill collars,acc.jar,total length 227.81'. TIH W/BHA on 30 stands of 3-1/2"PH-6 WS. 01/19/14-Sunday HSM.Continued TIH to bottom.TIH W/total of 183 stands of PH-6 WS.PU power swivel and 1 single joint off cat walk. Hooked up pump lines. PU weight 163K,DW 104K,Rotating weight 132K. Kicked pump,2.8 bbls/min @ 170 psi circulating pressure.Sat down on top of fish @11,576',pump pressure went to 730,shut pump down. Kicked power swivel on and put 8700#'s of torque on box tap.PU on WS,up to 200K,waited for jars to go off. As soon as jars went off,lost over pull and fish come off.Went back down and repeated process.PU again same 30K over pull,fish come off when jars went off. Repeated process to latch.After multiple attempts we were unable to latch the fish.RD power swivel and pump lines.Laid down single.SOOH W/183 stands of 3-1/2"PH-6 WS.Laid down accel jars,SB Drill collars,bumper/oil jars,5-3/4"Box Tap.PU test joint and test plug,set test plug in wellhead. Tested Annular to 250 psi low and 2500 psi high. Tested BOP and valves to 250 psi low and 5000 psi high. Tested gas detection system,all tested good. Witness of test waived by Jim Regg,AOGCC. 01/20/14-Monday r fi '' HSM.MU BHA#13,5-3/4"HT,5-3/4"OD X 4.5"ID Packer Shoe with 5'extension,4.75"Mud Motor,Double boot baskets,double magnets,bumper jar,oil jar,(6)4-3/4"drill collars,acc.jar, total length 280.92'.TIH W/BHA and total of 182 stands of PH-6 WS. PU power swivel and 1 single joint off cat walk.Hooked up pump lines. PU weight 163K,DW 104K,Rotating weight 132K. Kicked pump,4.5 bbls/min @ 654 psi circulating pressure.Sat down on top of fish @ 11,576'.PU slightly to burn over packer.As shoe would burn off,PU and re-tag and sat down jar weight on shoe to continue burning.Repeated process 7.5 hrs,made approx 3 ft,total depth 11,579'.RD Power swivel and pump lines.Laid down single. SOOH W/103 stands of 3-1/2"PH-6 WS. Hilcorp Alaska, LLC HileorpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 01/21/14-Tuesday HSM.SOON W/remaining 79 stands of 3-1/2"PH-6 WS.Laid down accel jars,SB Drill collars,bumper/oil jars,double magnets,Double boot baskets, 4.75 Mud Motor,5-3/4"OD X 4.5 ID Packer Shoe with 5'extension. Cleaned rig floor,magnets,and boot baskets.MU BHA#14,5"Overshot loaded with 4-3/8"grapple and plain control,3"pump out sub, bumper jar,oil jar,(6)4-3/4"drill collars,acc.jar, total length 229.90'.TIH W/total of 182 stands and 3 single joints of 3"PH-6 WS. Tagged top of fish @ 11,576'.PU weight 180K,down weight 104K,and rotating weight 132K. Sat down over fish,pump pressure jumped up to 360 psi,shut pump down,PU 20K over string weight,had fish latched,jarred down several times to ensure grapple set all the way.PU and started attempting to get fish moving,jarred on fish @ 50 K over string weight for 2 hrs. RIH W/GR/CCL,tagged last drill collar connection @ 11,522'elm,attempted to work through with no success. POOH W/E-Line to PU on WS. 01/22/14-Wednesday 5 rii;',y w �a HSM.POOH W/CCL. RDMO E-Line Unit.RU Power swivel,put 8800#'s of torque in WS,bumped down on jars on top of fish and released grapple. PU and laid down single joint of 3-1/2"PH-6 WS and RD power swivel.SOOH W/183 stands of 3-1/2"PH-6 WS. Laid down accel jars,SB Drill collars, bumper/oil jars,pump out sub. Redressed over shot with new grapple and control.MU BHA#15,5-3/4"Overshot loaded with 4-3/8"grapple and plain control. TIH W/BHA,1 single perforated joint,183 stands of 3-1/2"PH-6 WS,PU(3)3-1/2"singles,and 4 jts of 2-7/8"PH-6 WS. Stripped and cut drill line,half way in hole with tbg. 01/23/14-Thursday r._ ' , ` HSM. PU 174 K,DW 94 K. Sat down on top of packer @ 11,576'.Engaged grapple and PU to 20K OP,sat back down to ensure grapple set. PU to 210K and set pipe in the slips.MIRU E-Line Unit.RIH W/CCL and weight bar,(10 ft total)to 11,584'ELM. POOH. RBIH W/CCL/weight bar(4 ft total), attempted to knock through tight spot.RDMO E-Line Unit.MIRU Slick-line Unit. RIH W/1.8 swedge to 11,587',worked tools jarring on tag,tag not sticky and not making any hole. POOH. RBIH W/1.5 DD bailer to 11,587',worked tools several times,POOH,no recovery.RDMO Slick-line unit.MU Power swivel,put 4500#'S Torque in WS,stacked out on fish and grapple released from fish. POOH and laid down single joint of 2-7/8"WS. RD Power swivel and pump line,laid down 3 more singles of 2-7/8"PH-6,laid down 1 single of 3-1/2"PH-6 WS. SOOH W/183 stands and 1 perforated single,laid down overshot.MU BHA#16,5-3/4"HT,5-3/4"OD X 4.5 ID Packer Shoe with 5ft extension,4.75 Mud Motor,Double boot baskets,double magnets,bumper jar,oil jar,(6)4-3/4"drill collars,acc.Jar, total length 283.37'. TIH W/BHA 16 and total of 63 stands of 3-1/2"WS. 01/24/14-Fridayw� ` Cont.TIH w/BHA 16,t/11,565'. P/U swivel,&single,up wt 180,do wt 104,circ 180 gpm,600 psi,tag tof @ 11.577'. Mill t/11,585'w/4.5"ID burn shoe. L/D swivel POOH w/3-1/2"WS. LD BHA finding 2.4'packer mandrel inside of shoe. P/U BHA#17,washpipe extension 5-3/4",Pump out sub, Bumper jar,Oil Jar,6-Drill Collars,ACC Jar,X-over 3-1/2"IF X 2-7/8"PH6. TIH w/80 Jts 2-7/8"PH6. 01/25/14-Saturday HSM.TIH W/BHA#17,TIH total of 80 jts of 2-7/8" PH-6 P110. MU Crossover 2-7/8"X 3-1/2",TIH W/143 stands of 3-1/2"PH-6 WS. PU Power Swivel and 1 single Kelly joint.PU-165K,DW-98K,Rotating weight 149K. Kicked pump on @ 2 Bbls/min,circulating pressure 105 psi,sat down on fish, pump pressure come up to 225 psi,shut down pumps. PU to 170 K,jarred down several times on fish to ensure grapple engaged. PU to 188 K,jars went off,PU to 200K fish still latched,PU to 220K. PU to 230L,(65K over pull),jars went off and dropped fish.Repeated process 5 times engaging and loosing fish.Jarred on fish from 30K-70K over pull,could not pull fish. RD Power swivel and pump line,laid down Kelly joint.SOON W/3-1/2" WS,total of 143 stands. Made up 7"storm packer on remaining 40 stands of 2-7/8"PH-6 WS. PU 4 stands of 3-1/2"and set storm packer 245 ft below surface,backed 3-1/2"out of setting tool,SB 4 stands,drained stack to proceed with well head swap. • Hilcorp Alaska, LLC HiIcorpAlaska,l..LC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 Daily Operationst � - �� s�' 01/26/14-Sunday HSM.Pulled false floor from rig floor,pulled drip pan below false floor,removed bell nipple and flow lines to pits.MU wear bushing pulling tool on test joint. Latched wear bushing and POOH. Broke clamp off riser and well head.Closed Bop's and locked pins in. PU Bop's,flow cross and riser from wellhead. MU new wellhead adapter,installed on top of old wellhead and installed clamp,torqued clamp down,sat down on new adapter with riser and bop's. Installed top clamp, torqued top clamp,open pipe rams and blind rams on bop stack. PU test joint and test plug.Set test plug in wellhead.Tested Annular to 250 psi low and 2500 psi high. Tested Bop and valves to 250 psi low and 3000 psi high.Tested gas detection system. Tested 2-7/8"pipe rams as well as 3"pipe rams. All tested good,witness was waived by Jim Regg,AOGCC.POOH W/test plug. Flipped test plug over. MU wear bushing on test plug,set wear bushing in wellhead. POOH W/test plug. Installed halls head rubber assembly on annular,drip pan,false floor and panel,storm packer setting tool on 4 stands of 3"PH-6 WS. RIH,screwed back into top of packer. Attempted to test bottom clamp against storm packer with no success. 01/27/14-Monday HSM.Screwed back into top of packer. Test bottom clamp on old wellhead to 2500 psi and chart to ensure well control. Unable to get good test at first,packer was leaking,had to pressure up on drill pipe and annulus to get good test. Void test of Bop's and well.PU and released storm packer. SOOH W/4 stands of 3-1/2"PH-6 WS. Laid down storm packer and pup joint,laid down crossover to 2-7/8".SOOH WI remaining 40 stands of 2- 7/8". Laid down accel jars,SB drill collars,bumper/oil jars, and burn shoe.Grapple from shoe shows signs of being over fish,grapple's threads were pulled.Cleaned rig.MU BHA#18,5-3/4"skirted mill,NOV mud motor(2)5"Boot baskets,(2)5"magnets,Bumper Jar,oil jar,(6)4-3/4"drill collars, Total Length 258.35'. TIH W/BHA 18,total of 40 stands of 2-7/8"PH-6 WS and total of 29 stands of 3-1/2"PH-6 WS. 01/28/14-Tuesday Cont.TIH f/4,559',t/11,560'. PU single,install halls head element,p/u swivel,up wt 164,dn wt 94. RIH t/tag @ 11,578',p/u cir 4.2 BPM,610 psi. Mill f/11,578't/11,580',wob 2-4,diff psi 150-200psi,@ 11,580'motor stalling,unable to make progress,hung once off btm pull 40k over to free. R/d swivel,pull halls head element,I/d single. POOH standing back 3-1/2"&2-7/8"ph-6. LD BHA,find wear inside of skirt on one half,wear pattern to outside of mill resulting in a ledge.Clean out boot baskets&magnets recovering fine shavings 34 lbs. R/U wire line and RIH w/magnet. 01/29/14-Wednesday RIH w/3.75 magnet on wireline.Return metal shavings&some 3"metal slivers. Re-run returning same.P/U BHA#19,6"Concave mill,Mud motor, Double pin sub,2-Boot basket's,Double box sub,2-string magnet's,Bumper jar,Oil Jar,6-Drill Collars,ACC Jar,X-over 3-1/2"IF X 2-7/8"PH6,=275'. TIH w/80 jts 2-7/8"PH-6,xo,3-1/2"ph-6 ws,t/11,556'. P/u single. Install halls head element. P/u swivel,up wt 170,dn wt 100. RIH tag @ 11,580', p/u circ 4.5 bpm,680 psi. Mill f/11,580't/11,591',wob 1-2k,diff psi 150-250. 01/30/14-Thursday Cont.mill f/11,591't/11,592 circ 4.5 bpm,680 psi, wob 2-4k,diff psi 200-350 CBU. L/d swivel,pup jt,single&pull element f/halls head.POOH f/11,592't/11,432'encounter 30-40k drag coming up hole.R/U CBU @ 4.8 BPM 740 psi. Cont.POOH. L/D BHA#19,recover 33#shavings f/magnets &boot baskets. Clean&clear floor. P/U BHA#20,Wave wash shoe,Top Bushing,Double pin,2-Boot basket,double box 3-1/2"IF X 3-1/2"REG, Bumper jar,oil jar,6-Drill Collars,ACC Jar,X-over,3-1/2"IF X 2-7/8"PH6=241.66'. TIH w/80 jts 2-7/8"ph-6.Cont.TIH w/3-1/2"ph-6 t/11,585'. P/U single,install halls head element,p/u swivel,Break circ.@ 4bpm,@ 380psi.Close annular.Rev.CBU @ 3.5 bpm,540 psi,wk dn t/11,588' pressure up t/850psi,string packed off,attempt to clear tubing. 01/31/14-Friday F t« R/u e-line. RIH w/hole punch,punch holes in btm jt of 2-7/8"tubing @ 11,329'. POOH w/e-line&r/d. POOH w/BHA#20 f/11,585'and L/D. Everything from jars down plugged w/metal cuttings.L/D shot joint.P/U BHA#21- Wave wash shoe 5-3/4",Top Bushing,Bumper jar,Oil Jar,6-Drill Collars,ACC Jar,X-over,3-1/2"IF X 2-7/8"PH6=226.53'.TIH w/79 Jts 2-7/8"PH6 t/2,684'.Cont.t/tih w/3-1/2"ph-6 t/11,569'. P/U single install halls head element.P/U swivel CBU @ 3.5 bpm,220 psi.Wash down t/11,592'@ 3.5 bpm,250 psi,had pressure increase t/400&climbing. Halls head element failed. S/D pump- closed annular. Bring pump back on @ 3.5 bpm,300 psi CBUx2. Hilcorp Alaska, LLC HilcorpAlaska,1.1,C Well Operations Summary Well Name API Number _Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 Dal; ik.;_ $ 02/01/14-Saturday Cont.CBU stepping rate up t/4.5 bpm,500 psi. C/O halls head element,wash down t/11,592'pressure increased-halls head element started leaking. P/U&line up circ down tubing. Wash down t/11,594'-up wt 172,dn wt 102,circ 5 bpm,650 psi,CBU x2,@ 4.5 bpm,500 psi. Shut down. U-tubing up tubing-cont CBU. R/D swivel,halls head element. R/U t/POOH&L/D pipe. POOH,vac,clean&L/D 100 jts 3-1/2"PH-6 ws t/8,474'. Cont.POOH standing back. Clean&clear floor. M/U 3-1/2"test jt. Pull wear ring,install test plug,fill stack&manifolds. Test BOPE as per Hilcorp& AOGCC regulations,witness waived by Jim Regg @ 17:31 on 1-31-14. Test BOPE 250 low/3000 high,test Annular 250 low/2500 high. Test with 3- 1/2". 02/02/14-Sunday Cont.test BOPE as per Hilcorp&AOGCC regulations,witness waived by Jim Regg @ 17:31 on 1-31-14. Test BOPE 250 low/3000 high,test Annular 250 low/2500 high.Test with 3-1/2"&2-7/8"tj. Had 1 f/p on annular w/2-7/8"tj. Cycled annular&refolled stack-retest good.Pull test plug, install wear bushing,pull drip pan,install 13-5/8"x 7-1/16"flange t/annular w/halls head spool. Install drip pan,flow nipple,floor beams&panels. R/U wireline,run 3.75 magnet,bring back hand full of metal slivers,run 2x more bringing back same,run 4.75 LIB coming back w/2 dimples on edge, run 3"pump bailer bring back 2"remnant of possible w/I tool fish neck. Run#6 3"pump bailer retrieving 1/2 bailer full of sludge&small metal pieces,run#7 LIB coming back with light half moon mark. R/D wireline. P/U BHA#22- Overshot,Pump out sub,Bumper jar,Oil Jar,6-Drill Collars, ACC Jar,X-over 3-1/2"IF X 2-7/8"PH6=224.36'. TIH 39 stands-7/8"PH-6,P/U 102 jts 2-7/8"PH-6 t/5,960'. TIH w/OVERSHOT assembly t/6,516'. 02/03/14-Monday _,. Cont.TIH t/11,556'.Install halls head element,p/u swivel,CBU. Spot 3-20 bbl NXS lube pills in 3-1/2"x 7"annulus. P/U 5'pup jt,single&10'pup, up wt 150,dn wt 86. RIH&latch fish @ 11,592'set down 15k,p/u t/160,5/0 t/70k,pull t/182 hold t/fire jars,repeat same,stage up t/235k pull firing jars,cycle 109x,made 18". Let jars cool,cont.jarring fish-started moving up hole,pull dragging 40k up t/11,545'. L/D 10'pup,single&swivel, cont pull up hole.Dragging 30-50k over t/11,540'(w/TOF)pull t/235 w/no movement up,slack off.Cont/working string,pulling up t/235k no movement,cycling 5-10x.Jar moving wk string up t/11,535'. Change out working jt.Cont.jar up @ 260k,made 1' t/11,534'w/wk string. 02/04/14 TueSdiy s g 41' �ii�l ps a r Derrick inspection.Pull up t/260k lock down brake,service rig. Jar down on fish,attempt to move down hole.Wk 160 t/75,no go. Jar up on fish,pull t/250k,(100kop)re-cock jars,repeat process,no movement. P/U swivel,put tq in work string&work down t/release grapple. Grapple released after several attempts. L/D swivel. POOH.Stand back collars. L/D BHA. 02/05/14-Wednesday Cont.work on rig hydrostatic brake.Re-install.P/U BHA 6"Concave mill,Mud motor, Double pin 3-1/2"IF X 3-1/2"reg, 2-Boot basket,Double box 3-1/2"REG X 3-1/2"IF,2-Inline magnet,Bumper jar,Oil Jar,(6)4-3/4"Drill Collars, ACC jar,X-over 3-1/2"IF X 3-1/2"PH6=273.42'. TIH w/5,636' 2- 7/8"PH-6,cont TIH w/3-1/2"PH-6 t/11,481'. P/U 2-singles.Install halls head element.PU swivel.Pump 4.5 BPM,710 psi,up wt 145,dn wt 97,Rih tag @ 11536',mill w/1-2 wob,200psi diff,mill f/11536'. 02/06/14-Thursday Pump 4.S BPM,710 psi,up wt 145,dn wt 97,mill w/1-2 wob,200psi diff. Mill f/11,536'- 11,542'.CBU,make connection. Cont.milling @ 4.5 BPM, 710 psi,pump tandem hi vis sweeps. Halls head element leaking. SD pump,PU off btm. Pull heavy off btm,40k over,temp hung up,jar free. CBU. Cont.milling @ 4.8 bpm,850 psi,t/11,566'. 02/07/14-Friday : Cont.milling f/11,566't/11,576'pump 4.5 bpm,720 psi,wob 2-6,started losing fluid @ 1BPM while pumping,CBU,lost 52 bbls. Filled hole 4 bbls. Cont.milling f/11,576't/11,5783'pump 4.5 bpm,720 psi,wob 2-6,no fluid loss,Pump 25 bbl sweep,CBUx2 @ 4.5 bpm,650 psi. L/D 2 singles,pull halls head element,I/d swivel,POOH t/10,083'. 14 Hilcorp Alaska, LLC Hilcorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013{ 3/1/2014/ �`r.��' t!. , rif phi 11' '._" I I IJ1dI1I 111I��II�����1 02/08/14-Saturday �� Cut drill line&service rig.Cont.POOH f/10,083'. LD 6"concave mill BHA,mill 100%worn&cored,magnets&junk baskets full.P/U BHA#24, Overshot with 3-1/2"Basket grapple,pump out sub,Drilling Jar,6-Drill Collars,ACC jar,X-over=233.90'.TIH w/180 Jts 2-7/8"PH6,t/5,869',cont TIH w/3-1/2"PH-6 t/11,566'. P/U single,install halls head element,p/u swivel,Up wt 140,dn wt 96,Pump 3 bpm,230 psi.RIH t/tag tof @ 11,583', pressure increased,s/d pump,engage grapple,set down 15k,p/u t/200 jar,cont.jarring @ 240k,no movement.R/U wireline,RIH w/1.75 magnet t/ 11,592'WLM,bringing back fine metal shavings. RIH w/2"pump bailer. 02/09/14-Sunday _ POOH w/2"pump bailer,bringing back mostly fluids and small amount of metal shavings. P/U 1.75" spear RIH tag @11,592'beat down,no luck no over-pull coming off bottom.R/D wireline. P/U swivel,jar down @ 60k no go,release grapple, r/d swivel.Pull 10 stands,p/u storm packer,damage in halls head,L/D same,POOH f/10,883'. L/D BHA,clear floor,pull floor panels,beam&drip pan,remove flow nipple,re-install drip pan,beams& floor panels. M/U test jt,pull wear bushing,set test plug.Test ROPE as per Hilcorp&AOGCC regulations,witnessed by AOGCC inspector Jeff Turkington,test BOPE 250 low,3000 high,test Annular 250 low,2500 high Test with 3-1/2"&2-7/8"tj,had 1 f/p on super choke panel,ice plug in air line.Pull floor panel assembly and install halls head assembly. Q2/10/14Monday V :_ Re-install drip pan,flow nipple,floor beams,floor panels.Blow down choke&mud manifold.P/U BHA#23,6"Concave mill,Mud motor,Double pin xo,2-Boot basket's,Double box xo,2-Inline magnet,Drilling jar,6-Drill Collars,ACC Jar,xo 3-1/2"IF X 2-7/8"PH6=282.86'.TIH 180 JTS 2-7/8"PH6 t/5,918'. Cont.TIH 3-1/2"PH-6 t/11,553'.P/U 2-single,install halls head element,p/u swivel. Tag fill @ 11,579',tag fish @ 11,583',up wt 140,dn wt 96,rot wt 112,pump 4.7 bpm,650 psi,wob 1-3. Mill t/11,595',CBU,rot&recp.rot wt 112,pump 5 bpm 670 psi. Pull 2 singles.L/D swivel. POOH t/10,976'dragging 35k over. LO Cont.POOH f 10,976'. L/D BHA mill 50%wear.P/U BHA#24- 5-3/4"Wavy btm shoe w/catch#r,wash pipe ext.,top bushing,drilling jar,(6)-4- 3/4"drill collars,acc.jars,xo=238.16'.TIH w/180 jts 2-7/8"PH-6 t/5,874',cont TIH w/3-1/2"PH-6 t/11,509'up wt 140,dn wt 96.P/U swivel,install halls head element,wash t/tof @11,595'. Start CBU when tubing plugged up,attempt to clear,no go. L/D swivel&stand by for e-line t/punch holes. R/U e-line,RIH t/11,285'wlm,punch holes in jt 2-7/8"tubing. /1 �} e iiQ,i , 2/14 Wedne•] 4MIng"110 , h-}�"n lilt '€ '�Y � l;�" Itl _ i;�� i �, -�i ;Yi y;:�'^�'_,,. (l P R4 4 POOH w/e-line&R/D.POOH f/11,564'. L/D BHA,finding plugged off from jars t/catch in shoe(19'),recover 289 lbs metal shavings. P/U BHA#25, PILOT TYPE MILL,BIT SUB,EXTENSION,STOP SUB, CROSS-OVER 3-1/2"IF X 2-3/8"REG,NON-ROTATING STABILIZER,DOUBLE PIN 3-1/2"REG X 3- 1/2"IF, MUD MOTOR,DOUBLE PIN 3-1/2"REG X 3-1/2"IF,2-BOOT BASKET,DOUBLE BOX 3-1/2"IF X 3-1/2"REG,2-IN-LINE MAGNET'S,DRILLING JAR,(6)4-3/4"DRILL COLLARS, ACCEL.JAR,CROSS-OVER 2-7/8"PH-6 X 3-1/2"IF=296.91'. TIH t/11,568'. Install halls head element. P/U swivel. Unable t/start power pack for swivel,bring out Moncla mechanic. Yhursd E heli IN' $i" TIK Cont.wk on Moncla swivel.Mechanic on weather hold.Backup swivel arrived,servicing unit&setting up.Power swivel up&make connection. Start milling @ 13:30,circ @ 4.5BPM,560psi,up wt 140,dn wt 96,WOB 1-2. Mill appears to be stopped @ 11,603',CBU x2 @ 4.5 bpm,635 psi. L/D swivel. Pull halls head element. Start POOH. Qt/1 '!''fitiday' li'I+x ; oylll POOH w/Pilot mill BHA#25. L/D(6)4-3/4"drill collars.P/U BHA#26-4.25"bladed junk mill,3-1/8"mud mtr,xo,oil jar,(6)3-1/8"drill collars, accel.jar,xo=213.87',70 jts 2-7/8"PH-6 tubing,xo,double pin,2-boot baskets,double box,2-string magnets,xo=2434.61',110 jts 2-7/8"PH-6,xo, =5879.65'.TIH t/11,576'w/3-1/2"ph-6. P/U single,install halls head element. P/U swivel,up wt 136,dn wt 86,pump 3 bpm,400 psi. Tag tof @11,603'mill t/11,608'. Hilcorp Alaska, LLC Hileorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 . 44qi, 02/15/14-Saturday ,. Cont.milling w/4-1/4"junk mill assy f/11,608',t/11,609',stopped making headway. L/D swivel,POOH. L/D BHA.Mill worn on outer range w/ rounded shoulder.R/U wireline. RIH w/5.5"LIB,Tag @ 11,612'WLM,bringing back 5"impression appearing to be liner top. RIH w/3.72"swedge t/ 11,628'bobble @ 11,612'. RIH w/3.99 LIB t/11,628'WLM no distinct markings. R/D wireline.P/U BHA#26-4.25"bladed junk mill,3-1/8"mud mtr,xo,oil jar,(6)3-1/8"drill collars,accel.jar,xo=212.92',70 jts 2-7/8"PH-6 tubing,xo,double pin,2-boot baskets,double box,2-string magnets, xo=2333.66',110 jts 2-7/8"PH-6,xo=5878.70'. TIH t/11,577'w/3 1/2 ph-6. 02/16/14-Sunday HSM. MU Power swivel and Pump lines on single joint. PU Weight 136K,Down weight 88 K. Started circulating 3.5 Bbls per min @ 450 psi,Rotating @ 3200 ft Lbs of torque.Tagged top of fish @ 11,609',Milled down to 11,610'and broke through hard spot. Worked single joint down to 11,637'. RD Power Swivel. Continue to PU singles and moved down hole to 11,968 ft. Milled down to 11,972 ft. RD Power swivel and pump line. Installed clamp on derrick and goose neck,change shackles on power tong cable/cylinders,slipped and cut drill line,serviced rig.Laid down 10 joints of 3-1/2"PH-6 WS.SOON W/remaining 179 stands of 3-1/2",and 90 stands of 2-7/8"PH-6 WS.Laid down mill,magnets,and boot baskets,boot baskets full of debris and magnets covered in metal shavings.MIRU Slick line Unit. RIH W/3"Rare Earth magnet,tagged top of fish @ 11,979'wlm. POOH. Recovered hand full of metal shavings and grit. RIH W/3"Pump bailer. Worked Pump bailer multiple times off bottom,appeared to make 3 ft. POOH. Recovered bailer body full of metal shavings and pipe dope. 02/17/14+ 0nda x 7 7 . i '17111111 1711,111'116;[;,;'1,,,',0 i4�I((IIIi��II�JU HSM.Continued with Slick-line operation. RIH W/3"Pump bailer. Worked Pump bailer multiple times off bottom,appeared to make 1 ft.POOH. Recovered bailer body full of metal shavings,pipe dope and 2,half dollar sized pieces of rubber. RIH W/same 2 more times,appearing to make a foot each run,down to 11,984'.RBIH W/3"drive down bailer,worked tool several times.POOH.No recovery in bailer body. RBIH W/4"LIB,tagged top of fish @ 11,979'wlm,stroke tool and POOH. Recovered no determining picture on face of LIB. RDMO slick line and equipment.RD rig floor and halls head rubber adapter. PU test joint and test plug. Pulled wear bushing,set test plug in wellhead.Loaded BOP equipment and stack with fresh water,started testing BOP's.Tested Annular with 2-7/8"and 3"to 250 low and 2500 High,tested pipe rams,2-7/8"and 3"to 250 low and 3000 high, tested all other valves to 250 low and 3000 high. Tested gas detection systergand accumulator. All tested good with a fail/pass on 2-7/8"annular . high test.Witness of test waived by Jim Regg,AOGCC.Pulled test plug,installed wear bushing. Installed Hall's head adapter and rig floor.Made ready to TBIH.MU BHA#28,4-1/4"Tapered Mill,NOV mud motor,WTF Oil Jar,(6)3-1/16"Drill collars,WTF Accel jar,35 stands of 2-7/8"PH-6 WS,2-5" Boot baskets,2-5"magnets.55 stands of 2-7/8"PH-6 WS.Total Length of BHA 5879.14'. TIH W/BHA 28,and a total of 90 stands of 3-1/2"PH-6 WS. 02/18/14-Tuesday HSM.MU Power swivel and pump line. Installed halls head rubber.Tagged top of fish @ 11,971'.PU weight 136K,Down weight 86K,Rotating weight 110K,kicked pumps on @ 3.2 Bbls/min @ 470 psi circulating pressure,motor torque @ 3200 Ftlb. Started milling hard spot @ 11,974',milled for 2 hrs making 8 more feet before breaking through.PU 6 more singles while washing down,total depth of 12,133'. Each PU up weight increased. Decided to stop and SOOH.Attempted to SOOH and had to rotate and jar out first 5 joints,next 7 joints jarred out,laid down total of 16 joints of 3" PH-6 WS. SOOH W/3"and 2 7/8 WS. Laid down boot baskets and magnets. SB 35 stands of 2 7/8.Laid down accel jars. SB Drill collars. Laid down oil jars,mud motor and tapered mill.MU BHA#29- 2-7/8"PH-6 Mule shoe,40 stands of 2-7/8"PH-6 WS,4'Drilling Jar,50 stands of 2-7/8"PH-6 WS. Total Length of BHA 5674.80'. TIH W/BHA 29,and a total of 100 stands of 3-1/2"PH-6 WS. MU Power swivel,kicked pump on to obtain circulation down tbg out annulus,once circulation obtained changed direction of flow to reverse circulate @ 3.8 Bbls/min,started to come down with WS. WS plugged up.Jarred down multiple times to unstop WS,began circulating again. After obtaining circulation,circulated full casing volume before moving pipe. Recovering metal and grit at shakers. 14 Hilcorp Alaska, LLC Hieorp Ala.ka, Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 HSM.Started washing from 12,085',Pumping @ 3.5 Bbls/min at 430 psi.Washed down to 12,106'and WS plugged off,attempted to pump and jar plug free.No success.SOOH,W/3 1/2 WS and 50 stands of 2 7/8 WS. Found Drilling jar was plugged,attempted to remove plug,removed bottom 3 ft and could not get metal out. Laid down drilling jar and TBIH to bottom with mule shoe.MU Power swivel and started washing at 12,082',pumping 4.8 Bbls/min @ 570 psi,washed down to 12,095'and pump pressure come up to 1100 psi.Let circulate for 2hrs,pressure never came back down. Attempted to wash down 10 more ft and WS plugged off again.Attempted to jar down to free plug with no success,swapped direction of flow and pumped plug out of WS.Swapped flow back down annulus out WS and attempted to circulate metal debris out wellbore. Started SOON W/3 1/2 WS. Rd power swivel,laid down 1 single,pulled halls head rubber.SOON W/total of 24 stands of 3 1/2 WS. 02/20/14=Thursday HSM.Finished SOON W/2 7/8 WS.MU BHA#31-2 7/8 PH-6 Mule shoe,40 stands of 2 7/8 PH-6 WS,4 1/4 Drilling Jar,50 stands of 2 7/8 PH-6 WS. Total Length of BHA 5674.80'. TIH W/BHA 31,and a total of 100 stands of 3 1/2 PH-6 WS. MU Power swivel on single from deck,started seeing weight @ 12,085'. Ran joint down to 12,114'. MU Single off deck. Kicked pump on @ 4.8 Bbls/min at 600 psi circulating pressure down the WS out the casing,rotating @ 3700 Ft Lbs of torque,took approx.2 hrs of working joint up and down to get joint all the way in the hole. Torqueing from 3700-5100 Ft Lbs.Got joint on bottom and pumped a 40 Bbls sweep,circulate 2 full volumes,sweep come to surface already broke down,recovered small amount of metal,EOT @ 12,145'.Shut pump down and MU single off deck.EOT @ 12,176'kicked pump back on,no rotation and ran joint in hole no problem,mixed 20 Bbls high visc pill,circulated down WS out annulus,2 full volumes,again sweep came back broke down before reaching surface.Very little metal/debris recovery. EOT @ 12,176'. 02/21/14 Yi �m xt� 16(iil) iI HSM.Stopped circulating due to no recovery to shakers. SOON W/2 7/8 WS and 3 1/2 WS.Laid down 2 7/8 Mule shoe.MU BHA#32,4.25 OD Piranha Mill,40 stands of 2 7/8 PH-6 WS,4 3/4 Drilling Jar,50 stands of 2 7/8 PH-6 WS.Total Length of BHA 5674.16'. TIH W/BHA 32,and a total of 105 stands of 3 1/2 PH-6 WS. MU Power swivel on single from deck,started seeing weight @ 12,186'.Engaged power swivel and pump,Rotating @ 4000 Ft Lb of torque,Circulating 4.5 Bbls/min @ 560 psi.DW:88K,PUW-126K,ran through tag spot easily down to 12,207'.MU Single off deck,TIH to 12,239',no pump or rotation with no problem.Laid down Power swivel. TIH W/9 stands from derrick,total of 180 jts of 2 7/8 and 230 jts of 3 1/2, tagged hard @ 12,790'.MU power swivel,attempted to mill through tag,DW-87K,PUW-127K,torqueing up from 3800-5400 Ft Lb's. Attempted to mill through tight spot for 90 mins with no success,continually torqueing up power swivel.Shut Power swivel/pump down. Laid single on deck. RD power swivel and started SOON. SB 9 stands and WS started to stick,worked next 3 stands from 145K-200K to get free,once above 12,186'had no more problems. SOON W/total of 29 stands of 3 1/2 PH-6 WS. 02/22/14 Saturday HSM.SOON W/2 7/8 WS and 3 1/2 WS.Laid down 4.25 OD Piranha Mill. MIRU Slick line Unit. RIH W/3.60 Rare Earth magnet,3.71 centralizer and roller bogies,sat down @ 12,092'wlm,worked magnet up and down several times,no over pull,POOH.Recovered 2 large pieces of metal(3"X 1.5"). RBIH W/same,tagged up at 12,077'worked magnet same,no over pull,POOH,recovered very little debris.RBIH W/3.60 Rare Earth Magnet and centralizer left the rollers off,RBIH and tagged up @ 12,087',worked magnet off bottom several times,no over pull.POOH,recovered small amount of shavings.RBIH W/2.74 gauge ring on roller bogies,sat down @ 12,078'. Attempted to work past this spot with no success. POOH,RBIH W/same GR without the rollers,sat down @ 12.078',POOH. RDMO Slick line unit.MU BHA#33- 2 7/8 PH-6 Mule shoe,40 stands of 2 7/8 PH-6 WS,4 3/4 Drilling Jar,50 stands of 2 7/8 PH-6 WS.Total Length of BHA 5674.16'. TIH W/BHA 33,and a total of 109 stands of 3 1/2 PH-6 WS.Started washing down from 12,835'down to 12,856'. Circulating down tubing out annulus @ 4.5 Bbls/min @ 470 psi.DW-97K,PUW-143K.Once pipe moving easy, started circulating down the annulus out the WS,we reverse circulated 2 full volumes to clean up. Washed down to 12,949',and again reverse circulated 2 volumes. Continued to wash down to 13,020'and broke through,reverse circulated 2 volumes at this point.After circulating,Continued to TIH W/stands from derrick and 4 singles of rack to accomplish total depth of 13,971'. Again once on bottom,circulated 2 full volumes to ensure whole clean. I • Hilcorp Alaska, LLC Hi!corpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 # €fie o 02/23/14 Sunday j:",.;. t HSM.Finished circulating 2 full annular volumes to ensure hole clean.SOOH W/107 stands of 3 1/2 PH-6 WS,50 stands of 2 7/8 PH-6 WS.Laid down drilling jars and SB remaining 40 stands of 2 7/8.Laid down 2 7/8 Mule shoe.ND Halls head adapter and flow nipple. Nippled up shooting flange for lubricator. MIRU E-Line Unit. RU lubricator and tested to 1200 psi. RIH W/GR/CCI and 20 ft perforating gun. RIH down to 12,180',weight changed so stopped,logged up to 12,000',decided to log from top of liner top.Logged from 11,976'-12,200'. PU to desired depth of 12,080'.Perforated 12,090'-12,100'with 6 spf,60 degrees phasing.Performed pressure gradient test on formation 2000 psi leak off for 3 min,5 min,10 min,formation shows no sign of taking fluid. POOH,RDMO E-Line Unit. ND shooting flange. NU halls head adapter and flow nipple.MU BHA#34,Tri-point 5" packer,90 stands of 2 7/8 PH-6 WS,BHA total length 5645.85'. TIH W/BHA#34. 02/24/14-Monday 2 441. HSM. Continued TIH to land 5"test packer @ 11,700'.Set packer with 10K down,loaded annulus and tested/charted 7"and liner top to 2500 psi for 30 mins.Released Packer W/10K over pull. SOON W/94 stands of 3"PH-6 WS and 90 stands of 2 7/8 PH-6 WS. Laid down Tri-point test packer.RD rig floor and halls head rubber adapter. PU test joint and test plug,pulled wear bushing,set test plug in wellhead. Loaded BOP equipment and stack with fresh water,started testing BOP's.Tested Annular with 2 7/8 and 3 1/2 to 250 low and 2500 High,tested pipe rams,2 7/8 and 3 1/2 to 250 low and 3000 high,tested all other valves to 250 low and 3000 high. Tested gas detection system and accumulator. All tested good.Test waived by Jim Regg,AOGCC.Pulled test plug,installed wear bushing. Installed Hall's head adapter and rig floor.Made ready to TBIH.MU BHA#35,6"Tri Cone bit, 6"Casing Scrapper,and 90 stands of 2 7/8 PH-6 WS and 92 stands of 3"PH-6 WS and 1 single joint. Tagged top of liner at 11,596'. 02/25/14-Tuesday HSM. TOH laying down WS. Laid down and cleaned total of 224 jts of 3"PH-6 WS. Lay down and clean total of 180 jts of 2 7/8 PH-6 WS. Sent WS to the beach,received 2 7/8 8Rd production from beach,while waiting on boat performed rig maintenance and cleanup of rig floor and equipment. 02/26/14-Wednesday .— HSM.Continued cleaning rig and equipment. Greased and serviced rig.Racked and tallied 375 jts of 2-7/8 8Rd production tbg.TIH W/350 joints of 2- 7/8 8 RD. SOOH W/175 stands left 10 single on pipe racks. Prep rig and equipment to run Gas lift/submersible pump. 02/27/14`=,Tursday HSM.Continued to prep rig and equipment to run ESP and gas lift completion.MU ESP and TIH 58 stands of 2-7/8 8Rd tbg with ESP,X-nipple,Sliding Sleeve,and 3 gas lift mandrels. Est.EOT @ 4,080 ft. 02/28/14 Friday ;oiiil1.Il' HSM.Continued TIH W/ESP and gas lift design.TIH W/total of 108 stands,EOT @ 7,446'. Tested wire every 1200 ft while TIH. TIH W/TOTAL OF 344 JTS OF 2-7/8 8 RD,EOESP @ 11,517 ft,used total of 194 Canon Clamps.MIRU Slick line unit.RIH W/2"GS and PX Plug,set in X-Nipple @ 11,376 wlm, attempted to set plug with no success.POOH,inspected plug and noticed one key would not move,changed plug body and RBIH,set PX plug @ 11,376".Sheared off and POOH.MU Prong for plug.RIH down to 11,375 and attempted to set prong with no success.POOH,found dogs on SB running tool did not release prong,changed out SB tool and RBIH W/prong.RIH and set prong at 11,375',sheared off and POOH. Hilcorp Alaska, LLC Hik•orp Alaska,l.LC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP-54 50-733-20470-00 196-013 12/20/2013 3/1/2014 03/01/14Saturday HSM.Continued Slick-line operation.POOH W/2"SB,after setting prong.RU test equipment and tested tbg to 2500 psi,charted for 10 mins.RBIH WI shifting tool and shifted sliding sleeve open.POOH,RDMO SL unit. Run ESP cable and flat pack equipment through tubing hanger.Removed lines from hanger,made adjustment to ESP depth. Laid down 4 joints of 2-7/8 8 Rd tbg. Est EOESP @ 11,386.76'.Reconnected lines through tbg hanger, landed hanger in wellhead.PU weight 116K,DW 87K.ND annular,double gate,flow cross,riser and riser flange.NU Wellhead. Connected electric lines to ESP port in top of wellhead. Installed valves on wellhead. Rig down. • Schwartz, Guy L (DOA) From: Daniel Taylor <dtaylor@hilcorp.com> Sent: Thursday, November 07, 2013 1:40 PM To: Schwartz, Guy L(DOA) Subject: RE:GP-54, Sundry:313-124, PTD: 196-013 Attachments: 2013 GP 54 Updated Procedure.docx;GP-54 ESP WO 2013 Proposed.docx Guy, Please see the updated attached procedure for GP-54 and the Proposed well diagram. There is currently no communication to the perforations. May we install the ESP completion and then provide a No-Flow test? Thank you. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@ alaska.gov] Sent: Wednesday, September 25, 2013 2:31 PM To: Daniel Taylor Subject: RE: GP-54, Sundry: 313-124, PTD: 196-013 Dan Not quite... I need a revised procedure that includes testing the casing and a no flow test. We can likely forego re- submitting the sundry however. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Daniel Taylor [mailto:dtaylor©hilcorp.com] Sent: Wednesday, September 25, 2013 2:21 PM To: Schwartz, Guy L(DOA) Subject: GP-54, Sundry: 313-124, PTD: 196-013 Guy, Please see the attached proposed schematic for GP-54. The original Sundry that was approved 5-15-13 had a gas lift completion. We would like to change that completion to a packerless ESP. Will this e-mail suffice as sufficient documentation? Thank you sir. 1 Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 2 rn) IC/6' - Granite Point Platform GP-54 Thursday, November 07,2013 Revised WO Procedure 1. Move Moncla Rig 301 over Leg#4,GP-54 2. Install gas detection system. cLJ 3. Load pits with 6%KCL. �� /70'4 a. WO fluid will be 6%KCL until breaking through fish. S�/ b. WO fluid will be diesel thereafter. 4. Nipple down tree. a. Set BPV. b. Nipple down tree. 5. Nipple up BOP. 6. Make up landing joint. a. Pull BPV. b. Set 2-way check in hanger. 7. Space out test joint. 8. Test BOPE per test procedure. a. Notify AOGCC 24hrs before pending BOPE test. b. Test all BOPE per AOGCC guidelines to 250 psi LOW and 3,000 psi HIGH. c. Annular tested to 250 psi Low/ 1,500 psi High. d. Record pressures. 9. Pick up milling assembly and work string. 10. Trip in hole to top of tubing stub and junk at±11,334ft. a. Mill junk. b. Pull out of hole. 11. Pick up packer milling assembly. 12. Trip in hole to top of 7"HSE BWD Permanent packer 18' Seal Bore Extension at±11,381ft. a. Burn over packer. b. Circulate bottoms up to remove cuttings. c. Pull out of hole. 13. Pick up and run in hole with overshot. a. Engage packer b. Pull out of hole 14. Pick up and run in hole with 7in cleanout assembly. a. Clean 7in casing. b. Pull out of hole. 15. Pick up and run in hole with 5in clean out assembly. a. Clean 5in liner. b. Pull out of hole. 16. Pick up and run in hole with 5in test packer to 11,700ft. a. Test casing to 1,500psi. b. Hold 30min and chart. c. Release packer and pull out of hole. 17. Run in hole with ESP completion, capillary string, and clamps. a. Set ESP above liner hangar at*11,500ft. 18. Land hangar. 19. Nipple down BOP stack and nipple up tree. a. Test tree to 5,000psi. 20. Turn well over to production. ' • Oot.' I j /j THE STATE Alaska Oil and Gas ° fALSKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue *,h ALA`�Y' Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 SCANNED MAY 1 2013 Ted Kramer ®C 3 Senior Operations Engineer f Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granit Point Platform 54 Sundry Number: 313 -124 Dear Mr. Kramer: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, / - - )ji. e Cathy Prir Chair DATED this J? day of May, 2013. Encl. ' 90 RECE I V E NI STATE OF ALASKA 01 ;‘� f 2 $ .! 2'34 ALASKA OIL AND GAS CONSERVATION COMMISSION �' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ' '' ° "� 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well I9 s Change Approved Program ❑ Suspend El Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: • Hilcorp Alaska, LLC Exploratory ❑ Development El • 196 -013 d 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 20470-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? WA t~7V? i " w• Will planned perforations require a spacing exception? Yes ❑ No Z Granite Point 54 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018761•• Granite Pt / Middle Kenai Oil - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14,086 . 10,186 . 13,976 10,145 N/A 11,318 (fish) • Casing Length Size MD TVD Burst Collapse Structural 182' 33" 229' 228' Conductor 247' 26" 294' 293' Surface 1,073' 13 -3/8" 1,120' 1,119' 3,450 psi 1,950 psi Intermediate 3,565' 9 -5/8" 3,611' 3,334' 6,870 psi 4,760 psi Production 11,949' 7" 11,994' 9,960; 8,160 psi 7,020 psi Liner 2,474' 5" 14,070' 10,182' 8,290 psi 7,250 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11,976' - 13,970' 9,681' - 10,143' 3 -1/2" 9.2# N -80 IBT 4,051' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Packer: HES BWD and SSSV: N/A Packer: 11,381' (MD) 9,918' (TVD) and SSSV: N/A 12. Attachments: Description Summary of Proposal D • 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch G • Exploratory ❑ Stratigraphic ❑ Development IR * Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/1/2013 Oil 0• Gas El WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG El Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramert hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature –12/ #1-'1. '— Phone 907 777 -8420 Date 3/11/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313...(2_ Li Plug Integrity ❑ BOP Test / Mechanical Integrity Test ❑ Location Clearance ❑ Other: .)E 5 21 psi, i• � o P /cSf- ( Edon p 5'. ), O ptrw� - :c s Coh.,' -i 4 5 f - • c -re-4.4, ' j C t ►'t, S Lt ; !'►'\. / 0 C/�} b V /1.oCG c . Spacing Exception Required? Yes ❑ No i Subsequent Form Required: /6_ Y Jl - RBDMS MAY 16 201 J ^e APPROVED BY F 4 Approved by: / j ! COMMISSIONER THE COMMISSION Date: ()RIG Submit Form and a �� i / Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,I .. • • Well: GP -54 Hilcorp Alaska, LLC Date: 03/07/2013 Well Name: Granite Point 54 API Number: 50- 733 - 20470 -00 Current Status: SI Gas Lifted Producer Leg: 4, SE Corner Slot #3 Estimated Start Date: May 1, 2013 Rig: Moncla Reg.Approval Requested? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 196 -013 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Reid Edwards (907) 777 -8421 (0) Pressures: Current BHP: — 2,000 psi @ 9875' TVD/ 12750' MD .20 psi /ft., at mid -perf Max. Exp'd BHP: — 2,000 psi @ 9875' TVD / 12750' MD .20 psi /ft. (no new perforations) Max. Anticipated Surface Pressure: 0 psi Using 0.435psi /ft. SW gradient to surface Well Status: GP - 54 is a gas lifted horizontal producer which was $I after a shallow tubing part was discovered in November 2005. A workover was attempted with the Cudd hydraulic pulling unit in April 2006 and failed after a radial torch cutter was lost while attempting to cut the tubing near the packer. After failure to mill the fish during a second workover attempt in 2007, a down hole camera run and found the cutter to be wedged next to the remaining tubing stub. Workover operations were then suspended until a plan to "wide jrack the well could be formulated. It is now believed that this proposed project can be successful by utilizing a workover rig as opposed to a horsepower limited hydraulic work over unit which was used during the two previous attempts. Work Plan: Use the Moncla offshore rig to dress off tubing stub to install a lead overshot seal or if unsuccessful dressing off the top of fish, mill and fish out the remaining tubing stub and packer, clean out to PBD and re -run the gas lift completion. Procedure Summary: Jj eo l sr c0°° p S 3000 r s . 1. ND Tree, NU BOP and Test (Note: Notify AOGCC 24 ours in advance to witness BOP test). 2. Pull kill string -- cit KwG 6y P 3. RIH and fish / mill tubing stub. If proper clearance is gained to run lead overshot seal, go to step 6. 4. Mill over and pull packer. 5. Clean out well to PBD. / 6. RIH with Test Packer and Pressure test casing to.si for 30 minutes. !G 7. RIH with new gas lift co pletion and set packer at 11380' MD ( +1 -) or lead overshot seal at 11,318' . 8. Pressure Test Tubing ! / j' /SDI), s 9. RIH to pull dummies and set valves 10. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics 4. Wellhead Diagram • • . n GRANITE POINT PLATFORM SCHEMATIC GP #54 Hilcorp Alaska, l.I.0 Suspended 4/26/06 RKB = 115'; 43' Rig Floor to Wellhead Kvaerner SMS Wellhead LI CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 33" Outside conductor 47 229 26" Inside Conductor 47 294 13 -3/8 68 K -55 BTC 47 1,120 9 -5/8 47 L -80 BTC 46 73 9 -5/8 53.5 P -110 BTC 73 3,611 L , 7" 29 P -110 KC -BTC 45 5,960 7" 29 L -80 TKC -BTC 5,960 11,994 5" 15 L -80 SC -KC -BTC 11,596 14,070 Baker 5" HMC liner hanger @ 11,596' JEWELRY DETAIL NO.ITEM DEPTH 1 3 % ", 9.2 ppf, N -80 IBT Mod, Bvld Std Cplgs, Kill String 4051' Jet Cut 3 'A, 9.2 u ppf, Tubing riI °r � @11,318' ELM - 5 5 HES Seal Assembly with Nitrile /Flourel 11,345- 11,365' >< >K 6 molded seals ELM 6 HES BWD Permanent Packer 11,381' DPM 18' Seal Bore Extension ® 7 4.4' Millout Extension 7 HES "X" Nipple ID = 2.813" 11,437' 8 8 Wireline Muleshoe Re -entry Guide 11,471' TOL @ 11,596' z � 1. Fish is the remains of a rotary torch (original length 21'), fill, and milling P debris e 2. Tbg recovered to date strapped 11306'. Torch cut is at 11318 ELM. r 3. Packer was set on Eline. Add 34.48' to original ELM to get DPM. f 4. Remaining tubing stub is 20' c /o, 6.10' pup, 0.79' locator, 18.76 seal o assy r a C -5 SAND t i o PERFORATION DATA n TOP BTM ZONE SPF DATE COMMENTS s 11,976 13,970, C -5 6 1/24/97 TCP PDTD = 13,976' MAX HOLE ANGLE = 80 @ 12,354' Updated by: JLL 03/07/13 • • , 14 GRANITE POINT PLATFORM PROPOSED GP #54 Hil q, I I1 Last Completed: Future RKB = 115'; 43' Rig Floor to Wellhead Kvaerner SMS Wellhead CASING AND TUBING DETAIL L ' 1 SIZE WT GRADE CONN TOP BOTTOM 33" Outside conductor 47 229 26" Inside Conductor 47 294 ,2 13 -3/8 68 K -55 BTC 47 1,120 9 -5/8 47 L -80 BTC 46 73 3 9 -5/8 53.5 P -110 BTC 73 3,611 L \ 7" 29 P -110 KC -BTC 45 5,960 4 7" 29 L -80 TKC -BTC 5,960 11,994 5" 15 L -80 SC -KC -BTC 11,596 14,070 Baker 5" HMC liner hanger @ 11,596' 5 JEWELRY DETAIL NO. DEPTH ID ITEM 6 ±2,751' GLM - ±5,192' GLM 7 ±7,152' GLM ±8,655' GLM 8 1 - ±9,790' GLM — 9 i/ " ±10,278' GLM III 4-b� ±10,767' GLM ±11,256' GLM Wa 10 9 ±11,380' Packer 10 ±11,437' HES "X" Nipple Wireline Muleshoe Re -Entry 11 11 ±11,741' Guide TOL @ 11,596' 1. Fish is the remains of a rotary torch (original length 21'), fill, and milling P debris e 2. Tbg recovered to date strapped 11306'. Torch cut is at 11318 ELM. r 3. Packer was set on Eline. Add 34.48' to original ELM to get DPM. f 4. Remaining tubing stub is 20' c /o, 6.10' pup, 0.79' locator, 18.76 seal o assy r a C -5 SAND t i o PERFORATION DATA n TOP BTM ZONE SPF DATE COMMENTS S 11,976 13,970, C -5 6 1/24/97 TCP L T PDTD = 13,976' MAX HOLE ANGLE = 80° @ 12,354' Updated by: JLL 03/07/13 • • Granite Point Platform Rental BOP 03/11/2013 NiImrp :%Inrka.l.1.C; Granite Point Platform 2013 Workovers BOP Drawing (Moncla) iii Ili 111 iii I. 4.54' Hydril III iii 111111111 iii 111 ill 111 i!i - 4.67' = i * 1 _ 2 7/8 -5 variables ■ ■�� 13 5 8-5000 _ — Blind 1111 * 1II I11 111 2.00' Q j I + .;iI I II I I'lll 11 111 ; I 7'. � y 2 1/16 5M Choke and Kill z lit I &M AI III r 111 11 1 1 111 2.00 21.75' Drill deck UOCD 1885 19.75' - Riser 13 5/8 5M FE X 13 5/8 5M 813 API hub 6 1 Top of wellhead @ 19.75' below deck • .. Granite Point Platform GP -54 03/11/2013 H1Irnrp tl iska. 1.11 Granite Point Tubing hanger, National SMS, GP -54 135 /85M X 3'''hTC4S lift 133/8 X95/8 X7 X3''/, 335 RS Vam susp threads, w/ 3" NSCO "B" BPV profile, 33 non continuous control line port, 6'''A extended neck w/ DA carrier pocket BI-ITA, Bowen, 3 1/8 5M X 3" Bowen Quick Union O 1/111 1ik1 ._, Valve, Wing, 31/8 SM SSV ' 140 i operator o.aO 1� Tree, composite block, i NSCO, 71/16 SM X O , 3 1/8 5M, double master, swab, w /31/85M SSO for , wing, FF trim iill ,O0 0 4E:10 - Adapter, 13 5/8 5M 11.1 413 API hub 7 1/16 5M, prepped 1/ DA carrier assy, and DHSV port w/ shutoff { ti is Unihead, National — .17 SMS, 3 step system, 135 /85M API Hub 0 O top X 133/8 BTC casing bottom, w/ 2- _ 2 "6 s 0 �. O 4 -21/16 M 55O , O pit _ 0 I . L.,...,, . --,. . 4 - li 1 , ,. ea ,_, • 7" emergency slips 1� and packoff set in t� wellhead' • • i �, 11` . o : e I Ilk •e : 'Y' _ _ : E ��� UMW .mom 4 _ -1 irt PI L ~._~ ~~ ~ ~~ ~~ l ~_ ~ r-~ COI~TSE~t AATIO C 1-iIItII SS IOl~ SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE {907) 279-1433 FAX (907) 276-7542 Tunothy C. Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 ~ Anchorage, AK 99519 ~~`© ~~~ ~c~ ~ ~ 204 ~ Re: Granite Point Field, Middle Kenai Oil Pool G.~-,.5,_4.x... Sundry Number: 307-330 ~~ ~y Dear Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission shown, a person affected by it may file with the Comm scion an appli anon for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~'day of November, 2007 Encl. al Chevron Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com ~ECE~~~'E 10/2/2007 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7t" Avenue Anchorage, Alaska 99501 Re: Granite Point, GP-54, APD 196-013, API 50-733-20470-00 Dear Commissioner, OC1' ~ ~ ~Q~,r Alaska Ail ~ Gas Gdns. Carr-r~, -~ :~{ __ Anchorage Please see the attached form 10-403, Application for Sundry Approvals, pertaining to the above referenced well. Chevron Alaska, DBA Union Oil Company of California, proposes to suspend the well and °` put it on our candidate list for a re-drill in 2010. Please review the attached documents and feel free to contact me or Steve Tyler at 907- 263-7649 if you have any questions. Sincerely, 1 ~. Timothy C. Brandenburg Drilling Manager Attachments: Summary of Current Work Over Operations Summary of forward plan. Proposed Wellbore Schematic Form 10-403, Application for Sundry Approvals (in duplicate) Cc: File Union Oil Company of California / A Chevron Company Page i of 1 Chevron Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com 10/25/2007 Summary of Forward Planned Operations Granite Point, GP-54, APD 196-013, API 50-733-20470-00 1. POOH LD DP. 2. Run 3-1/2" kill string. 3. Remove BOPS and install production tree. 4. Turn well to production. 5. Release HWR unit. Union Oil Company of California / A Chevron Company Page i of i ~` '~ STATE OF ALASKA !~- NOV 0 6 2007 ~~' `~-' ALASKA OIL AND GAS CONSERVATION COMMISSION ~~I~ ~~ APPLICATION FOR SUNDRY APPROVA~~ka Oil & Gas Cons. Commission ~n vn~ ~~ ~Rn Anchorage 1. Type of Request: Abandon^ Suspend ^~ Operational shutdown ^ Perforate ^ Waiver ^ Other^ Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program^ Pull Tubing^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development a Exploratory ^ 196-013 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20470-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No D GP-54 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): II Granite Point Platform/Cook Inlet ~ ~...\g1~ 1 115 Granite Point Field/Middle Kenai "C" Sands 12. 'IY1/~~~(~PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14,070' 10,180' 13,976' 10,144' None 11,318' Casing Length Size MD ND Burst Collapse Structural 182' 33" 229' 228' Conductor 247' 26" 294' 293' Surface 1,073' 13-3/8" 1,120' 1,119' 3,450 psi 1,910 psi Intermediate 3,565' 9-5/8" 3,611' 3,327' 6,870 psi 4,760 psi Production 11,949' 7" 11,994' 9,675' 8,160 psi 7,020 psi Liner 2,474' 5" 14,070' 10,170' 8,290 psi 7,250 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11976' -13970' MD 9,681' - 10,141' TVD 3-%z" 9.2#, L-80 4051' Packers and SSSV Type: Halliburton BWD 7" permanent packer Packers and SSSV MD (ft): 11347 13. Attachments: Description Summary of Proposal ^/ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: ~~~y~~~- ~~/)5--~, 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Tim Brandenburg Title Drilling Manager Signature Phone 907 263-7657 Date 11/1/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~j~-- a t Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~ ~ ~ ~' ~ BFA~ ~lfl~ (} ~ 2a~~ APPROVED BY Approved by: COM $5'(ONER THE COMMISSION Date: 1 ~. v ~ Form 10-403 Revised 06/2006 p R I G I N A L Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRO LS ~~~r ov~~ 0 C ~ ~ 5 2007 20 AAC 25.280 iSSIOit Other 1. Type of Request: Abandon Suspend ~ Operational shutdown Perfora aive~r Qra~~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimu to ^ Time Extension Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ~ ` Ex orator ^ 196-013 ' 3. Address: Stratigraphic rvice~^ 6. API Number: ~ PO Box 196247, Anchora AK 99519 ~ 50-733-20470-00 7. KB Elevation (ft): 9. N ~I fiber: 115' RKB P- ~ 8. Property Designation: 0. Fiel ools(s): O~ ° ~ /o ~~• Granite Point Platform/Cook Inlet ~L ~ v7(Pj / r i Po Field/Middle Kenai "C" Sands 11. PRESENT O 10 S MMARY Total Depth MD (ft): Total Depth (ft): Effective Depth MD ( epth TVD (ft): Plugs (measured): Junk (measured): 14070 10180 13976 (~ 10144 ~ none 11,318' Casing Length Size D TVD Burst Collapse Structural 182 33" 228' Conductor 247 26" 293' Surface 1073 13-3/8" 1,120' 1,119' 3,450 psi 1,910 psi Intermediate 3565 5/8" 3,611' 3,327' 6,870 psi 4,760 psi Production 11949 11,994' 9,675' 8,160 psi 7,020 psi Liner 2,474' 5" 14,070' 10,170' 8,290 psi 7,250 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11976' -13970' MD 9,681' - 10,141' TVD 3-1/2" 9.2#, L-80 4000' Packers and SSSV Type: Packers and SSSV MD (ft): Pa er: Hallibu n BWD 7" permanent packer @ 11,347' 12. Attachments: Description Summary of roposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BO Sketch ^ Exploratory ^ Development ~ ,. Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/25/2007 Oil 0 - Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: \0% _~eZ ~~~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ ~ Commission Representative: ~~ ~~ 17. I hereby certify that the foregoing i true and correct to the best of my knowled Contact Steve Tyler 263-7649 Printed Name Steve Tyler ~N,~~~~, Title Drillin Engineer ~ ~~ Signature ~~ Phone 907-276-7600 Date 10/25/2007 COMMISSION USE O LY Conditions of approval: N ify Commission so that a representative may witness Sundry Number: J~,?_~n Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Locatio Clearance ^ Other: Subseque Form Required: -- APPROVED BY Approved by: I N THE COMMISSIO Date: Ov~~~~'Q~ ^eW Form 10- 03 Revised 07/2005 ,~Q~ M ~Q ~ AFE 1t~6 ~ 7(~a 66 ~2°a6~ Sub m Dujlira ~~/f~~7 ~,--. -- ~ P( Chevron -Alaska ' SWW Daily Operations Summary Well Name Field Name API/UWI Lease/Serial GP-54 GRANITE PT, i 507332047000 ADL0018761 -- - Primary Job Type Primary Wellbore Affected ;Workover 'Main Hole ~i - Jobs Primary Job Type IJob Category AFE No. !Objective Workover 1Workover ! R 7002 Mill packer and replace tubing - __ - _ Orig KB Elev (ftK6) Water Depth (ft) 115.0 __ - 4ctual Start End Date OC Engineer 10/9/2007 'Daily Operations ' ! 10/9/2007 00:00 - 10/10/2007 00:00 -_______ 'IOperations Summary Mobing Cudd HWO Rig to Granite Point Platform. NOTE: Included Cost for prior 10 days of work to RU fluid handling equipment. 10/10/2007 00:00 - 10/11/2007 00:00 Operations Summary Mobing HWO Rig to Granite Point Platform Rigging up same. 10/11/2007 00:00 - 10/12/2007 00:00 ' Operations Summary 'Continue to work boats, Rig Up Cudd Unit, Fabricate necessary items for R/U. 10/12/2007 00:00 - 10/13/2007 00:00 - - -- _--- Operations Summary I I~ Continue to work boats. Mobe/ Rig Up Cudd Unit. 10/13/2007 00:00 - 10/1412007_00:00 _ Operations Summary Continue to work boats. Mobe/ Rig Up Cudd Unit. __ _ - - 10/1412007 00:00 - 10/15/2007 00:00 !,Operations Summary I !Continue to work boats. Mobe/ Rig Up~Cudd Unit. -- - 10115/2007 00:00 - 10/16/2007 00:00 Operations Summary Continue RU of HWO Rig. ND Tree. Prep to NU BOPE. 10/16/2007 00:00 - 10/17!2007.00 00 - _ ____ _____ _ Operations Summary Continue to R/U Cudd equipment & BOPE. Prep Platform for Well Work 10/17/2007 00:00 - 10/18/2007 00:00 '. !Operations Summary 'Cont. to R/U Cudd Equipment & Prep platform for well work. Talked to Lou Grimaldi w/ AOGCC @ 1745 hrs about BOP test. -_ __ ------ ---------------- --- i 10/18/2007 00:00 - 10/19/2007 00:00 --. - _ - - - Operations Summary 'Finished R!U Cudd Rig. Start test BOPE test Lou Grimaldi w/ AOGCC on location to witness BOPE test. ' 10/19/2007 00:00 - 10/20/2007 00:00 ~ Operations Summary .- ---- ---- -- _ _- ---- _ . __ ~ .-- -- - J, ,Finished Testing ROPE. L/D TBG HGR. Start to L/D KIII stung. AOGCC witnessed test ~, _ _--- 10/20/2007 00:00 - 10/21/2007 00:00 __ ___ ,Operations Summary j Finished POOH & UD Kill String. GIH w/ BHA No 1. P/U Drill Pipe &GIH. Mill @ 3,406' @ 2400 hrs 10/21/2007 00:00 - 10/22/2007 00:00 _ _ _ _ _____ ___ Operations Summary Finish TIH w/ Drill Plpe. Tagged at 11,344'. _ -- - - - 10/22/2007 00:00 - 10/23/2007 00:00 _ _ Operations Summary 'Displace diesel from well w/ FIW. Reverse circulate (1) Wellbore volume. _ 10/23/2007 00:00 - 10/24/2007 00:00 Operations Summary Circ to clean up fluids for camera. Take pictures of Fish. 10/24/2007 00:00 - 10/25/2007 00:00 ____ Operations Summary Circ around 2% PKR Fluid 10/25/2007 00:00 - 10/26/2007 00:00 -- ~Operations Summary ~ Notified AOGCC. Mr Reggs at 1000 hrs. BOP test is waived 43.00' 229' 294' 1,120' 3,611' 10,870' 1 11,596' 1 11,994 13,976' F 14,070' Current Sketch Post WO on 04/26/06 Prepared By: Steve Tyler GPP 54 Granite Point Platform PTD#196-0130 Field: Granite Point API#: 50-733-20470-00 Leg: 4 Well Classificaton: Producer Slot: 2 Total Depth: 14,086' Surface Location: PBTD: 13,976' X: 263,333 Tubing: 3-''/i', 9.2#, L-80, IBT Y: z,5aa,sta Prod Pkrs: HES BWD Pkr @ 11,381' DPM Well Status: SI Operator: Chevron Ownership: Chevron/Exxon BHP: Spud Date: 11/23/1996 C-5 1500 psi ~ 9680 ND Other: WO 4/04/06 to 5/02/06 WO Oct 2007 Camera depicted tbg stub 8~ fish un-fishable BHT: 162 Description Weight Grade Conn ID Length Top Btm TOC Hrs Drive Pipe 33 182' 47' 229' Conductor 26 247' 47' 294' 9.0 hrs Surface 13 3/8" 68.0# K-55 BTC 1,073' 47' 1,120' Surface 52.0 hrs Interm di t 9 5/8" 47.0# L-80 Buttress 8.681 27' 46' 73' rf S 179 3 h e a e 9 5/8" 53.5# P-110 BTC 8.535 3,538' 73' 3,611' ace u . rs Production 7 29.0# P-110 KC-BTC 6.184 5,915' 45' 5,960' 10 870' 235 3 h 7 29.0# L-80 TKC-BTC 6.184 6,034' 5,960' 11,994' , . rs Liner 5 15.0# L-80 SC-KC-BTC 4.95 2,474' 11,596' 14,070' ? 28.0 hrs Tubing 3 1/2" 9.2# L-80 IBT-M 2.992 4,008' 43' 4,051' Range II tbg Jewelry Description Depth Lergtr ;~ OD Kvaerner SMS Wellhead 43' 0.83' 3-'/~', L-80, IBT x 20' Cut Tbg Stub + 6.10' pup jt 11,318' 26.10' 2.992" 2.875" Locator Seal Assy (Overall Length = 19.55') spaced out 1' above pkr. 11,346' 0.79' 2.989" 4.469" HES 7", 23# - 32# "BWD" Permanent Pkr 11,347' 4.01' 4.000" 5.873" SBE (two sections) 11,351' 15.47' 4.000" 4.951" MOE w/ OX to 3-'/~' IBT pin 11,367' 4.05' 4.428" 4.994" (1) Joint of 3-'/z", 9.2#, L-80, BTC 11,371' 31.13' 2.992" 3.500" HES 2.813 "X" Land Nipple w/ "Top Load" Plug w/ 5' prong 11,402' 1.39' 2.813" 3.954" (1) Joint of 3-'/", 9.2#, L-80, BTC 11,404' 31.82' 2.992" 3.500" Mule Shoe WLEG 11,435' 0.83' 3.050" 4.248" Fish Details Remains of Radial Torch 21.00' (4) Super Bands Fill and milling debris Note: Wellbore fill with FIW w/ 2% Corrosion Inhibitor Perforations Zone Top Btm Amt Gun Size SPF Phase Date Tyonek C-5 11,976' 13,970' 1994 4-1/2" 6 60 1/24/1997 . . Page 1 of5 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday. October 25,20078:16 AM To: 'Tyler, Steve L' Cc: Nienhaus, Doug R; Harness, Evan; Buster, Larry W; Brandenburg, Tim C Subject: RE: Granite Point GP-54 WO Sundry# 307-308 Deviation from procedure \S(o -0 \ -S Steve, et ai, Thanks for the further information. I have spoken with Commissioner Seamount and he has given oral approval for you to proceed with the planned suspension. A 403 will need to be submitted within 3 business days. Call or message with any questions. Tom Maunder, PE AOGCC SCANNED NOVO] 2007 -------~----~-----------_. w__~__·____~_____~_~_ From: Tyler, Steve L [mailto:tylersl@chevron.com] Sent: Wednesday, October 24, 2007 4:40 PM To: Maunder, Thomas E (DOA) Cc: Nienhaus, Doug R; Harness, Evan; Buster, Larry W; Brandenburg, Tim C Subject: RE: Granite Point GP-54 WO Sundry# 307-308 Deviation from procedure Tom The Eline tool string is a spent Radial Torch cutter and was lost in the well during the April '06 WOo Overall length is 20' long with the largest 00 of 2-1/2" (drawing attached). After reviewing the results from the camera we believe the Eline tool string is in multiple pieces. It also appears the tubing stub top has been spilt or damaged from the milling work accomplished during the April '06 WOo In our present operation, we have not changed anything in the wellbore or accomplished any milling on the fish. We only changed the well over to FIWand cleanout about 30' of fill on top of the fish for the camera run. Our tentative plan forward (pending partner approval) is to suspend the well in the same manner it was in when we moved on it for this WOo We will displace the wellbore with an inhibited FIW. And run the 2-%" Kill String to 4000'. Our intent is to place this well as a Redrill candidate during our 2010 development work with the drilling rig. Please let us know if you concur. -~-- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 24,20074:14 PM To: Tyler, Steve L Subject: RE: Granite Point GP-54 WO Sundry# 307-308 Deviation from procedure Steve, Thanks for the update on GP. Could you please provide some additional information (comment/description) regarding the fish. From our conversation I understand that you have not disturbed the deep plug. Please include an estimate of the timing. Tom Maunder, PE AOGCC _____~__._~_~_M_____~___~·________"____~·______~_·___·. From: Tyler, Steve L [mailto:tylersl@chevron.com] Sent: Wednesday, October 24,20073:36 PM To: Maunder, Thomas E (DOA) Subject: Granite Point GP-54 WO Sundry# 307-308 Deviation from procedure 10/25/2007 . Page 2 of5 . Tom Just to give you a "heads up" We ran in and change the Wellbore over to a clean FIW above out tubing stub and fish. We ran in with a camera to have a "Kodak Moment" of our tbg stub and fish. Upon viewing our impediment, we have locally determined we don't have enough money or time to rectify our problem. We are currently in discussion with our partners (Exxon) about our forward plan. Most likely we will want to suspend our operations and save our money for the re-drill. I've attached pictures for your viewing pleasure. Drilling Engineer, Adviser Union Oil Company of California . Office: (907) 263-7649 .Cell: (907) 350-6295 .Home: (907) 696-1837 .Fax: (866) 244-1439 ~Email: tylersl@chevron.com 10/25/2007 - D SARAH PAUN, GOVERNOR ~aa/v-7~ OII~ ~D G~5 333 W. 7th AVENUE, SUITE 100 CQ11t5ERQA~`I011T CO1~iDII55IO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Tyler Drilling Engineer UNOCAL PO Box 196247 Anchorage, AK 99519 ~~~ NG'~ ~ ~ 2Q0? `%b ~~ Re: Granite Point Field, Middle Kenai Oil Pool, GP-54 Sundry Number: 307-308 Dear Mr. Tyler: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of October, 2007 Encl. Sincerely, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ION ~ ~ ~ ; ~~~ APPLICATION FOR SUNDRY APPROVALS, , r, , 20 AAC 25.280 ~ k ' ' 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver _ Other Alter casing ^ Repair well ~ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well [~ ~~ `~~ ~ ~ r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory ^ 196-013 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-733-20470-00 7. KB Elevation (ft): 9. Well Name and Number: 115' RKB GP-54 8. Property Designation: 10. Field/Pools(s): Granite Point PlatformlCook Inlet Granite Point Field/Middle Kenai "C" Sands 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft}: Tota{ Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured}: 14070 10180 13976 10144 none 11,318' Casing Length Size MD TVD Burst Collapse Structural 182 33" 229' 228' Conductor 247 26" 294' 293' Surface 1073 13-318" 1,120' 1,119' 3,450 psi 1,910 psi {ntermediate 3565 9-5/8" 3,611' 3,327' 6,870 psi 4,760 psi Production 11949 7" 11,994' 9,675' 8,160 psi 7,020 psi Liner 2,474' 5" 14,070' 10,170' 8,290 psi 7,250 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11976' -13970' MD 9,681' - 10,141' TVD 3-1/2" 9.2#, L-80 4051' Packers and SSSV Type: Packers and SSSV MD (ft): Packer: Halli burton BWD 7" permanent packer @ 11,347' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/15/2007 Oil ~ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. f hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name teve T er Title Drilling Engineer Signature ..Phone 907-276-7600 Date 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: `~C (.i ~ t '- ~ Z~:,:t ~~E a~~v rti~ ~~ ~' ~,~`.~ '~--~ ,.,_-~ _ } ' C Subsequent Form Required: 1 ~ t~ t~~ "~ ~ APPROVED BY Approved by: ~ O MISSIONER THE COMMISSION Date: !©~l/ ~~/ v v Form 10-403 Revised 0712005 1 ~ K i ~ ~ ~ L~l IAFE 164826 Submit in Duplicate • Chevron Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com 10/2/2007 - ~,~ ~ ~i~[] 7 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7'h Avenue Anchorage, Alaska 99501 Re: Granite Point, GP-54, APD 196-013, API 50-733-20470-00 Dear Commissioner, Please see the attached form 10-403, Application for Sundry Approvals, pertaining to the above referenced well. Chevron Alaska, DBA Union Oil Company of California, proposes to repair the subject well and re-establish production. Operations are currently scheduled to begin in October, 2007. Please review the attached documents and feel free to contact me or Steve Tyler at 907- 263-7649 if you have any questions. Sincerely, - ~ Timothy C. Brandenburg Drilling Manager Attachments: Summary of Work Over Operations Current Wellbore Schematic Proposed Wellbore Schematic Form 10-403, Application for Sundry Approvals (in duplicate) Cc: File Union Oil Company of California J A Chevron Company Page 1 of i • Chevron 10/2/2007 Summary of Planned Work Over Operations Granite Point, GP-54, APD 196-013, API 50-733-20470-00 • Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com 1. Move in and rig up HWOU (hydraulic work over unit) 2. Install and test BOPE 3. Pull kill string. 4. Recover existing permanent production packer and wire line fish. 5. Run new gas lift packer and completion 6. Remove BOPE and install production tree. 7. Turn well to production. Union Oil Company of California / A Chevron Company Page i of i • • .. ~. `.... `,, GRANITE POINT PLATFORM t7 N n rv rF~Q7 WELL # 54 - - ~ -- -- ~ PROPOSED COMPLETION RKB = 115'; 43' Rig Floor to Wellhead Kvaerner SMS Wellhead CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 33" Outside conductor 47 229 26" Inside Conductor 47 294 13-3/8 68 K-55 BTC 47 1,120 9-5/8 47 L-80 BTC 46 73 9-5/8 53.5 P-110 BTC 73 3,6] 1 7" 29 P-110 KC-BTC 45 5,960 7" 29 L-80 TKC-BTC 5,960 11,994 5" 15 L-80 SC-KC-BTC 11,596 14,070 Baker 5" HMC liner hanger @ 11,596' 3-1/2" 9.2 L-80 SC BTC 44 11,400 JEWELRY DETAIL NO. ITEM DEPTH 1 Kvaerner Tubing Hanger 44' (AB TC-4S Up X STD VAM DWN) 2 STD VAM x Buttress Pup JT 3 HES XXO Safety Valve Landing 332' Nipple (ID = 2.813") 4 10 ea. McMurry-Macco SFO-1 Gas Lift Mandrels with 1-1/2" Valves at: 2250', 3350', 4300' 5200', 6050', 6850', 7600', 8250', 8750', 9250' (TVD) 5 Permanent Packer 11,381' 596' 6 HES "X"Nipple ID = 2.813" 11,437' 7 Wireline Muleshoe Re-entry Guide 11,471' PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 11,976 13,970, C-5 6 1/24/97 TCP MAX HOLE ANGLE = 80° @ 12,354' REVISED: 1 /5/06 DRAWN BY: NM PDTD = 13,976' l STATE OF ALASKA /D"9~~ ALASKA OIL AND GAS CONSERVATION COMI. LION APPLICATION FOR SUNDRY APPROVALS nn n nr nti inn i~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver =' ,% Otfter Alter casing[] Repair well ^ Plug Perforations ^ Stimulate ^ 7ime Extension '^ _ ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Weil ^ 2. Operator Name: Vell Class: 5. Permit , -Drill Number: Union Oil Company of California ~~~ ~ nt ^ Exploratory ^ 196-013 ~ - 3 Address: c ^ Service ^ 6. I Number: . < 5flf 733-20470-00 - , PO Box 196247, Anchorage, AK 9951 ~ 7. KB Elevation (ft): 1 i 1. WeII Name and Number: ~' 115' RKB ~ C ' 3P-54 8. Property Designation: l~ ~~ ~ 0. Field/Pools(s): Granite Point Platform/Cook Inlet .iranite Point Field/Middle enai "C" Sands 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total De , D (ft): Effectiv~pth MD (ft): Effective TV lug (measured): Junk (measured): /~11,83~ 11,190' ~ 11,695' - ~ ,00 "~ ~ - none 11,318' Casing Length Size MD , ` T - Burst Collapse Structural 182 33" 229' 2 8' Conductor 247 26" 29 ' ! 93' Surface 1073 13-3/8" 1 1, 19' 3,450 psi 1,910 psi Intermediate 3565 9-5/8" 1 3,327' 6,870 psi 4,760 psi Production 11949 7" 1, 4' 9,675' 8,160 psi 7,020 psi Liner 2,474' 5" ,070' 10,170' 8,290 psi 7,250 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubi g Tubing Grade: Tubing MD (ft): 11976' -13970' MD 9,681' - 10, 141' TVD 3-1/2" 9.2#, L-80 11,400' Packers and SSSV Type: Packers and SSSV MD (ft): Packe Hall on BWD 7" permanent packer @ 11,347' 12. Attachments: Description Summary f Propos ~ 13. Well Class after proposed work: Detailed Operations Program ^ B P Sk Exploratory ^ Development 0 Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/15/2007 Oil 0 Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Dat WAG ^ GINJ ^ WINJ ^ WDSPL ^ r: Commission Representative: 17. I hereby certify that the foregoing is true an correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenbu g Title Drilling Manager Signature - '~ Phon '907-276-7600 Date ~ v -> "? - r~ ~ COMMISSION USE ONLY 2 Conditions of approval: Notify Co mission so that a representative may witness Sundry Number: ~ ~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent For Required: APPROVED BY Approved y: COMMISSIONER THE COMMISSION Date: J Form 10-403 Revised 07/2005 ~ ~ ~ ~ N A L AFE 164826 Submit in Duplicate ~.~~ f ~ ~. Y ~~ STATE OF ALASKA !D-~ ~ ~~ ALA OIL AND GAS CONSERVATION COM~ION ~~.~~~~'~ `~ ~ ~~~7 WELL COMPLETION OR RECOMPLETION REPORT I~ ~ 1 a. Well Status: Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ 20AAC25.105 20AAC25.110 GINJ^ WINJ^ WDSPL^ WAG^ Other^ No. ofCompletions: 1 1 b. W ell Class: ~. };~ ,~~'~~~~,.,;+~ Development Q Exploratiiry^ Service ^ StratigraphicTest^ 2. Operator Name: Union Oil of California 5. Date Comp., Susp or Aband.: 5/2/2006 12. Permit to Drill Numb ~~ 196 0130 ~' ~~~~ 3. Address: P.O. Box 196247 Anchorage, AK 99519 6. Date Spudded: 11/23/1996 13. API Number: ~~ry~ `~ ~ti'`~;a 50-733-20470 ~~"~ ~ ~+ 4a. Location of Well (Governmental Section): Surface: 2427' FNL & 1303' FWL of Sec. 13, T10N, R12W 7. Date TD Reached: 1/19/1997 14. Well Name and Number: GP-54 Top of Productive Horizon: 2792' FNL & 1675' FEL, Sec. 23, T10N, R12W 8. KB (ft above MSL): Ground (ft MSL): 15. Field/Pool(s): Granite Point Field ~ Total Depth: 4746' FNL & 2112' FEL, Sec. 23, T10N, R12W 9. Plug Back Depth(MD+TVD): 13,976' MD/ 10,143' TVD Middle Kenai "C" Sands 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 263,333 y- 2,544,514 Zone- 10. Total Depth (MD +TVD):/ 14,086~MD / 10,186' TVD 16. Property Designation: Granite Point Platform TPI: x- 260,236 y- 2,539,007 Zone- C5 Total Depth: x- 259,884 y-.2,537,077 Zone- 11. SSSV Depth (MD +TVD): NA 17. Land Use Permit: ADL 1861 18. Directional Survey: Yes ~ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: 75 (ft MSL) 20. Thickness of Permafrost (TVD): NA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): Gamma Ray, CCL, Dual Induction, Density 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 13-3/8" 68 K-55 45 1120 45 1119 17 112 394 bbls Class G 9-5/8" 47/53.5 L-80/P-1 45 3611 45 3334 12 1/4 600 bbls Class G 7" 29 P-110/L- 45 11994 45 9690 8 1/2 160 bbls Class G 530k 5" 15 L-80 11596 14070 9470 10180 6 53 bbls Class G 23. Open to production or injection? Yes ^ No ~ If Yes, list each 24. TUBING RECORD interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 3 % 4008 11347 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period -- Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate -- Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^ Sidewall Cores Acquired? Yes ^ No ^ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submitf(separate shte~ets with this foarm, if needed). Subm`i~t\detailed descriptions,+cyo~re chips, photographs and laborSatory~analytical results per 20 AAC 25.071. ~t`Y~ ®~~S~l'° "iS~e.'A 0~0~ `~}~-~4\~1 ~. `~'~~.1 ~ ~/~~V~_''!~ \'.\ ~. ^(;,_~~.1, ~~'~. ~'1~. ~~~.~~~0, C.~~~ ; i '.. .... 5: "~ l rl _ '_f'r~~; , ~ r , ,.~ , ~ ~F~ o c~ ~ r 2oor ~~.,~~.~..,.. ~~~~~~ Form 10-407 Revised 2/20070 R t G I N A ~NTINUED ON REVERSE • C 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ^ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Top needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base Formation at total depth: 30. List of Attachments: 31, I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler @ 263-7649 Printed Name: Lar st Title: Drilling Engineering Manager r Signat Phone: 263-7853 Date: `~ ZS O 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas {njection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for /njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 43.00' 229' 294' 1.120' 3,611 10,870' l 11,596' 1 11,994' 13,976' F 14,070' Current Sketch Post WO on 04/26/06 Prepared By: Steve Tyler GPP 54 Granite Point Platform PTD# 196-0130 Field: Granite Point API#: 50-733-20470-00 Leg: 4 Well Classificaton: Producer Slot: 2 Total Depth: 14,086' Surface Location: PBTD: 13,976' X: 263,333 Tubing: 3-'/i', 9.2#, L-80, IBT Y: 2.5aa.5~a Prod Pkrs: HES BWD Pkr CrD 11,381' DPM Well Status: SI Operator: Chevron Ownership: Chevron/Exxon BHP: Spud Date: 11/23/1996 C-5 1500 psi @ 9680 ND Other: WO 4/04/06 to 5/02/06 BHT: 162 Description Wei ht Grade Conn ID Len th Top Btm TOC Hrs Drive Pipe 33 182' 47' 229' Conductor 26 247' 47' 294' 9.0 hrs Surface 13 3/8" 68.0# K-55 BTC 1,073' 47' 1,120' Surface 52.0 hr: I di t t 9 5/8" 47.0# L-80 Buttress 8.681 27' 46' 73' rf S 179 3 h n erme a e 9 5/8" 53.5# P-110 BTC 8.535 3,538' 73' 3,611' u ace . r: Prod ti n 7 29.0# P-110 KC-BTC 6.184 5,915' 45' 5,960' 10 870' 235 3 hr: uc o 7 29.0# L-80 TKC-BTC 6.184 6,034' 5,960' 11,994' , . Liner 5 15.5# L-80 SC-KC-BTC 4.95 2,474' 11,596' 14,070' ? 28.0 hr; Tubin 3 1/2" 9.2# L-80 IBT-M 2.992 4,008' 43' 4,051' Range II tbg Jewelry Description Depth Length ID OD Kvaerner SMS Wellhead 43' 0.83' 3-'/i', L-80, IBT x 20' Cut Tbg Stub + 6.10' pup jt 11,318' 26.10' 2.992" 2.875" Locator Seal Assy (Overall Length = 19.55') spaced out 1' above pkr. 11,346' 0.79' 2.989" 4.469" HES 7", 23# - 32# "BWD" Permanent Pkr 11,347' 4.01' 4.000" 5.873" SBE (two sections) 11,351' 15.47' 4.000" 4.951" MOE w/ OX to 3'/i' IBT pin 11,367' 4.05' 4.428" 4.994" (1) Joint of 3 '/:", 9.2#, L-80, BTC 11,371' 31.13' 2.992" 3.500" HES 2.813 "X" Land Nipple 11,402' 1.39' 2.813" 3.954" (1) Joint of 3-'/", 9.2#, L-80, BTC 11,404' 31.82' 2.992" 3.500" Mule Shoe WLEG 11,435' 0.83' 3.050" 4.248" Fish Details Remains of Radial Torch 21.00' (4) Super Bands Fill and milling debris Pertorations Zone Top Btm Amt Gun Size SPF Phase Date Tyonek C-5 11,976' 13,970' 1994 4-1/2" 6 60 1/24/1997 rt ` Chevron -Alaska SWW Daily Operations Summary Well NameField Name (API/UWI (Lease/Serial Orig KB Elev (ftK6) (Water Depth (ft) GP-54 GRANITE PT, 1507332047000 ~'ADL0018761 115.0 I Daily Operations 3/30/2006 00:00 - 3/31 /2006 00:00 __ _ _ _ _ _ _ _ - _ - - Operations Summary Continue rig up of BOP. _ 3/31/200600:00 - 4/1/2006 00:00 Operations Summary Cudd safety orientation, mobe hands and equipment __ ___ 4/1/2006 00:00 - 4/2/2006 00:00 _ __ ____ _ Operations Summary Mobe -- _ _ - 4/2/2006 00:00 - 4/3/2006 00:00 Operations Summary Mobe _ - _ - 4/3/2006 00:00 - 4/4/2006 00:00 Operations Summery - _ ..._. _. ___._ .._ __...__ __.__ Complete Cudd RU, clean decks, start to test BOP. _ ---- 4/4/2006 00:00 - 4/5/2006 00:00 _ _ _ _ __ Operations Summary Tested BOP (250# low 3000# high). Tested blinds (250# low 3000# high). Make up threads on hanger, start spinning hanger,. Pulled free. POOH hanger and part of tbg (total length = 9.68') Had SSSV control line issue due to line parting, fished and removed line. Lost 12 SS bands down ho{e. NU bell nipple and chained down BOP stack. _ - - _ __ 4/5/2006 00:00 - 4/6/2006 00:00 __ _.. _ _ Operations Summary RIH and set wear bushing. PUMU fishing BHA #1. RIH and latch onto tbg @ 104'. Atempted to rotate/reciprocate cut lip guide on tbg stub. RIH with multiple swedges. Work through overshot and tbg stub @ 104'. Tagged SSSV @ 346'. POOH. Reran swedges, unable to work passed 104'. RD slickline. 4/6/2006 00:00 - 4/7/2006 00:00 ___ __ _ Operations Summary Worked pipe attemting to establish where pipe is free. RU eline for tbg cut. Worked pipe. Tbg parted. POOH with 13.2', 3-1/2", tbg fish. RIH tag, and latch remaining fish @ 117'. PU 20K.RD eline. RU slickline. RIH to 346' and latch SSSV. POOH and LD same. MUPU wireline brush. RIH Passed tbg tail @ 11,475'WLM. 4/7/2006 00:00 - 4/8/2006 00:00 _ -- -- --- Operations Summary PUMU guage ring. RIH to outside tbg tail. POOH. RIH and set PX plug in profile at 11,431'. MU and load bailer with baracarb 600. RIH and dump load on prong. RD slickline. RU eline. RIH to punch holes in tbg at 11,320' - 11,326'. POOH. No change in csg pressure. PUMU Radial Torch Cutter. Tie in tool to cut @ 11,318'. --- _ 4/8/2006 00:00 - 4/9/2006 00:00 ~ - - - _ _ ___ _ _.__ -_ Operations Summary Fire shot for tbg cutter. Eline stuck. Pump diesel. Monitor pressures. Work tension on eline. Pull from rope scoket. POOH and LD eline. RU slickline. RIH and latch fish at 11,336'. Work fish, multiple runs. No recovery. POOH RD slickline. RU eline. RIH w! freepoint. Establish free pipe 5884'. __ _- __. 4/9/2006 00:00 - 4/10/2006 00:00 _ _ _ - - - -- Operations Summary - - - -- Arm tubing cutter and RIH and make cut at 5,914'. POOH. RD eline. Circulate well. Pull tbg out of well, LD GLMs. 4/10/2006 00:00 - 4/11/2 006 00:00 __ _ . Operations Summary Continue to POOH tbg, laying down GLMs. Recovered 8 of 12 stainless bands, 2 GLMs, 5891.36' of tbg. PUMU overshot fishing assy. BHA on 3-1/2" (15.5#) DP. RIH. - _ 4/11/2006 00:00 - 4/12/2006 00:00 Operations Summary TIH. Tag fish at 5,963'. Mill on fish, engaged same. POOH. 4/12/2006 00:00 - 4/13/2006 00:00 __ _ _ Operations Summary Cont. to POOH with tbg fish. LD GLMs. _ _ - _ _ _ _ 4/13/2006 00:00 - 4/14/2006 00:00 ___ __ Operations Summary Continue to POOH and LD 3-1/2" tbg fish. Tubing out of hole. Left 21' radial torch remains on tbg stub at 11,318'. Begin testing BOPS. r ~"" art ~ . Chevron -Alaska j _ SWW Daily Operations Summary We11 Name ;Field Name (API/UWI !Lease/Serial Orig KB Elev (ftK6) (Water Depth (ft) GP-54 ~i GRANITE PT, ' 507332047000 ADL0018761 115.0 Daily Operations 4/14/2006 00:00 - 4/15/2006 00:00 _ _ _ _ _ _ - - _ _-- - - --_ - - - -- Operations Summary Finish testing BOPS (250# low 3000# high) RU slickline. RIH and work on junk around 11,191'. POOH and RIH with BHA and suspect fill in hole. POOH. PUMU 7" csg scrapper BHA. Monitor pressures. RIH 3109' Reverse circulate well. 4/15/2006 00:00 - 4/16/2006 00:00 _ _ _ Operations Summary TOOH with 7" scrapper. LD scrapper. RD slickline. RU eline. PU junk basket w/5.83" GR and RIH to 3100'. POOH and recover 1 gallon of emulsion (60°lo scale/rust). Make multiple runs, recovering less and less emulsion. POOH. PUMU PMIT logging tool. RIH to 3005' and log up. Caliper log. LD logging tool and PU junk basket. RIH recovering sludge for multiple runs. RD junk basket and PU USI log. - - - .. _ - - - - - - 4/16/2006 00:00 - 4/17/2006 00:00 - -- - _- _- --- -_- ---- OPerations Summary - _ - _ PU USIT and RIH to 3000'. Attempt to run log unsuccessfully due to trash on transducer. POOH RD eline. PUMU 5-3/4"fishing assy. TIH on 3-1/2" DP. Reverse circulate wellbore. - _ - _ 4/17/2006 00:00 - 4/18/2006 00:00 __ _ _ _ _ __ __ Operations Summary Continue to RIH with DP. Circulate multiple times while RIH. Kelly up and wash down to 11,232'. Reverse circulate well to clean. - -- - - -- 4/18/2006 00:00 - 4/19/2006 00:00 _- _ __ _ _--___ _ --- -_ -- - - - _ - _ _ Operations Summary continue to reverse circulate. Wash down, start rotating, milling on fish. Pump, slack off, stack out, and pick up in an attempt to free seal assembly. POOH. 4/19/2006 00:00 - 4/20/2006 00:00 - --- -_ __ _ _ - Operations Summary - ._. -..------ -- _. _.- ._-.. Continue to POOH. LD fishing BHA #4, no fish recovered. MUPU burn shoe w/mill (BHA #5) and RIH. Kelly up @ 11,126'. _ __- -- 4/20/2006 00:00 - 4/21/2006 00:00 _ __ _ _ _ _ --- ------ --- Operations Summary Continue to wash in hole. Rotated making very little progress. TOOH vath tools. 4/21/2006 00:00 - 4/22/2006 00:00 ___ __ _ _ - - -._-._ Operations Summary Continued to POOH. LD BHA. Test BOP (250# low 3000# high). PUMU BHA #7 with junk mill and mud motor. RIH on 3-1/2" DP. -- -- - - - - - -- 4/22/2006 00:00 - 4!23/2006 00:00 - -- _.. - - -__ _--- -. - __ - Operations Summary - pressure. Wash down to tag point and begin milling @ 11,342'. Continue to RIH to 11,217'. Kelly up and establish circulation rate and - _ - - - -- - 4/23/2006 00:00 - 4/24/2006 00:00 --.. _._ --- -- -- - Operations Summary Continue to mill and wash down to 11,344'. TOH, with milling assembly. 4/24/2006 00:00 - 4/25/2006 00:00 - - -__ _ -- - -- - - _ _ - Operations Summary _- -- - Lay down BHA #7 and inspect same, Basket full of mostly sandy scale w/ 10% of basket pieces of iron (likely SS bands, centralizer bow springs from cutter tool, with bar and tbg/csg pieces). PU BHA #8 and RIH to 11,324'. Kelly up and wash down to 11,344'. Begin milling operation. 4/25/2006 00:00 - 4/26/2006 00:00 Operations Summary Attempt to mill over stub not much luck Mill stalling. Pump 22 tills barolift sweep followed by 489 bbls diesel to circ hole clean. POOH laying down drill pipe - - - - - - _ 4/26/2006 00:00 - 4/27/2006 00:00 - _ _ - - - -- _ - _ --- Operations Summary - -- _- Laydown drill pipe and BHA. Boot basket full of rust like particles. Some metal from bow spring of radial cutter and several metal chunks. Run kill string (3-1/2", 9.2#, L-80 Inp Butt mod with stn cpl bevel top and btm), - -- 4/27/2006 00:00 - 4/28/2006 00:00 _ __ _ __ Operations Summary RIH W/ Kill string to 1095.89' RKB, land hanger, RD Cudd equipment _ _ -._. _ - _ _ 4/28/2006 00:00 - 4/29/2006 00:00 -- _ - _ Operations Summary Rig down. Demobe - - ~- - - 4/29/2006 00:00 - 4/30/2006 00:00 _-_-__- _ _ _ _ _ - - _ Operations Summary Operations Secured for Crew off time. Conitnue demobe. ... Chevron -Alaska SWW Daily Operations Summary Well Name (Field Name (API/UWI Lease/Serial ~Orig KB Elev (ftK6) '(Water Depth (ft} GP-54 jGRANITE PT, 507332047000 IADL0018761 I 115.0 Daily Operations 4/30/2006 00:00 - 5/1/2006 00:00 --__- Operations Summary Demobe 5/1 /2006 00:00 - 5/2!2006 00:00 Operations Summary Demobe 5/2/2006 00:00 - 5/3/2006 00:00 Operations Summary Clean location. 43.00' 229' 294' 1,120' 3,611' 10,870' - 11, 596' 11,994' 13,976' I 14,070' Current Sketch Post WO on 04/26/06 Prepared By: Steve Tyler • GPP 54 Granite Point Platform PTD# 196-0130 Field: Granite Point API#: 50-733-20470-00 Leg: 4 Well Classificaton: Producer Slot: 2 Total Depth: 14,086' Surface Location: PBTD: 13,976' X: 263,333 Tubing: 3-'/~', 9.2#, L-80, IBT Y: 2,544,514 Prod Pkrs: HES BWD Pkr @ 11,381' DPM Well Status: SI Operator: Chevron Ownership: Chevron/Exxon BHP: Spud Date: 11/23/1996 C-5 1500 psi ~ 9680 ND Other: WO 4/04/06 to 5/02/06 BHT: 162 Description Wei ht Grade Conn ID Length Top Btm TOC H~ Drive Pipe 33 182' 47' 229' Conductor 26 247' 47' 294' 9.0 hrs Surface 13 3/8" 68.0# K-55 BTC 1,073' 47' 1,120' Surface 52.0 hr; I di t t 9 5/8" 47.0# L-80 Buttress 8.681 27' 46' 73' rf S 179 3 hr: n erme a e 9 5/8" 53.5# P-110 BTC 8.535 3,538' 73' 3,611' u ace . P d ti 7 29.0# P-110 KC-BTC 6.184 5,915' 45' 5,960' 10 870' 235 3 h : ro uc on 7 29.0# L-80 TKC-BTC 6.184 6,034' 5,960' 11,994' , . r Liner 5 15.0# L-80 SC-KC-BTC 4.95 2,474' 11,596' 14,070' ? 28.0 hr: Tubino 3 1/2" 9.2# L-80 IBT-M 2.992 4,008' 43' 4,051' Range II tbq Jewelry Description Depth Length ID OD Kvaerner SMS Wellhead 43' 0.83' 3-'/2', L-80, IBT x 20' Cut Tbg Stub + 6.10' pup jt 11,318' 26.10' 2.992" 2.875" Locator Seal Assy (Overall Length = 19.55') spaced out 1' above pkr. 11,346' 0.79' 2.989" 4.469" HES 7", 23# - 32# "BWD" Permanent Pkr 11,347' 4.01' 4.000" 5.873" SBE (two sections) 11,351' 15.47' 4.000" 4.951" MOE w/ OX to 3 Yi' IBT pin 11,367' 4.05' 4.428" 4.994" (1) Joint of 3-'/i', 9.2#, L-80, BTC 11,371' 31.13' 2.992" 3.500" HES 2.813 "X" Land Nipple 11,402' 1.39' 2.813" 3.954" (1) Joint of 3-'/~', 9.2#, L-80, BTC 11,404' 31.82' 2.992" 3.500" Mule Shoe WLEG 11,435' 0.83' 3.050" 4.248" Fish Details Remains of Radial Torch 21.00' (4) Super Bands Fill and milling debris Perforations Zone Top Btm Amt Gun Size SPF Phase Date Tyonek C-5 11,976' 13,970' 1994 4-112" 6 60 1/24/1997 e e FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager Union Oil Company PO Box 196247 Anchorage, AK 99519 0\3 \q~'" Re: Granite Point Field, Middle Kenai Oil Pool, GP-54 Sundry Number: 306-166 Dear Mr. Brandenburg: C.C~.i 110.1.', ·..1. t::.. '.''''.' IU¡N~ -.\.. '" 20PG \]1 ..r\~~~'4,_,t.5 w'·' ,~. 0·u!.n1 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~44- Cathy P. Foerster Commissioner DATED thi~~y of May, 2006 Encl. e e Chevron === Neil Magee Drilling Engineer Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7804 Fax 907 263 7884 Email mageen@chevron.com April 27, 2006 Tom Maunder Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Re: Granite Point 54 Tubing Replacement (Form 10-403) Mr. Maunder: The purpose of this letter is to advise you that the wellwork on Granite Point 54 will be temporarily suspended pending equipment upgrades to the CUDD hydrauilic workover unit that will provide enhanced packer milling capability. We left a 22' long tubing cutter assembly in the hole when we made the bottom cut just above the packer at 11,381' and this has prevented us from latching the tubing stub ,m above the packer to pull it free. Runs with washpipe and shoe have been unsuccessful w.r due to the high tðque we're seeing at 11,300' and runs with a downhole motor and ;..'tÞ~ milling assembly we"'Gnsuccessful making any progress. The CUDD rotary table is torque limited too 9500 ft-Ibs. ,L Our plans are to suspend operations on GP 54 after running a 3-1/2" kill string to 4000' and moving over to do the Anna 35 Kobe change-out. Afterwards we plan to either return to GP 54 or move over to King Platform to perform some ESP work. The GP 54 has a tubing plug installed in the tailpipe immediately below the packer and the production casing was bundle tested to 1100 psi for 30 minutes. / We anticipate we'll be off the Granite Point Platform by Saturday April 29th. Please contact me at 263-7804 if you have any questions concerning this sundry. Sincerely, '-iJ.. -fk¡)rr¡~ Neil Magee Drilling Engineer Attachments Cc: Tim Brandenburg Union Oil Company of California I A Chevron Company http://www.chevron.com .. STATE OF ALASKA .. k ALA~OIL AND GAS CONSERVATION COMMI~N ' {IV APPLICATION FOR SUNDRY AP~OVALS n. t~^ I: ð i 20 MC 25.280 .~~ (",() tHð'S k ¡;¡ iJi ¡ ¡.~~ t; ;:;'~ r: {HE:'" "''''' 1. Type of Request: Abandon U Suspend "0 Operational shutdown ~ . Perforate TI Waiver U t\?1,.fr¡,,,.u", Other G:J Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 ~>'V":.'{~ g,,~\;,-~ Time Extension 0 SÙspend Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 Operations from 306-047 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development 0 Exploratory 0 196-013 .. 3. Address: Stratigraphic 0 Service 0 6. API Number: Fa Box 196247, Anchorage, AK 99519 50-733-20470-00 .. .,. KB Elevation (ft): 9. Well Name and Number: 115' RKB - GP-54 8. Property Designation: 10. Field/Pools( s): Granite Point Platform/Cook Inlet . Granite Point Field/Middle Kenai "c" Sands . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11 ,839' 11,190' 11,695' 11,005' none none Casing Length Size MD TVD Burst Collapse Structural 229' 33" 229' 228' Conductor 294' 26" 294' 293' Surface 1,120' 13-3/8" 1,120' 1,119' 3,450 psi 1,910 psi Intermediate 3,611' 9-5/8" 3,611' 3,327' 6,870 psi 4,760 psi Production 11,994' 7" 11,994' 9,675' 8,160 psi 7,020 psi Liner 2,474' 5" 14,070' 10,170' 8,290 psi 7,250 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11976' -13970' MD 9,681' -10,141' TVD 3-1/2" 9.2#, L-80 11,344' to 11,400' Packers and SSSV Type: I Packers and SSSV MD (ft): Packer: Halliburton BWD 7" permanent packer @ 11381' 12. Attachments: Description Summary of Proposal GJ 13. Well Class after proposed work: .. Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: n/a Oil 0· Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Neil Magee 263-7804 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature 7~c:~ b/......- Phone 907-276-7600 Date J:: --+ ~ ,A; ¿j COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I ~ I n -- I (e Ú2 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RBDMS 8FL Mil Y .2 8 2006 S.b"q"'"tFo~ Req.'''''' ~ "-"- a'< ,,"" .. ....\ "" <c . "....::.." <--0 ,<, ¡;" "'''- 'ù "" a ç ~"''' \ "'':,. """~ \~ ~CD~L ~~~c:.~~~~ "'1 ~...J\'\ ~\. "-\0"\ \ ~ ~~~\~ Approved by: all! ¡J::::l.l '- L COMMISSIONER APPROVED BY THE COMMISSION Date: 5-1:2".-G,b -~ -- - . - ... . . .. I U K I b 11\1 A L AFE 164826 ~ ç./~.Þ(, Form 10-403 Revised 07/2005 Submit' Duplicate :;K 7/fðl¿>6 RECE\v!O MAY 1 5 100B Union Oil.pany of California 909 W. 9th ue Anchorage, 99501 Tela: (907) 263-7889 E-mail: oudeand@chevron.com Fax: (907) 263-7828 Chevron .. (. 'C(/!lIII~i~'¡{' Debra Oudeq'O~1Ü'! 01\ ~,. b¡~ .~¡f\!;I. , Technologist And\ì:)!ðíJ~ To: AOGCC Helen Warman 333 W. ih Ave. Ste#100 Anchorage, AK 99501 i 204-186 i 502312002800 "HAPPYVAL.LEY- . A10 204-207 ' ;' 5023ÙWÒ2900 ; HAPPY VAL.LEY- , A11 '204-207 'r-"so¿ái20Ö200Ö"u, I 'H'APPŸ'VÄ[LEY~ . A11 , 204-207 502312002900 "HAPPY VAl.l.EY- A11 199-054 501331012501 ;SCÜ¿1A~Ò9 190-147 T5Ò7331óo5SÒ1 ,----_........,..................... TBF A-01RD 167-080 507332006800 TTSU D~ò1 198-064 ...............,.".........--.--........ TBU G-21RD 507332026701 169-086 507332049800 TBU G-32 Date: May 11, 2006 o \ "'?) \~~' 19'\ V~... . MUl TIFINGER IMAGING . TOOL , TCÒMPLËT¡ÒNRECoFiÓ¿" · OMEGA HSD 6SPF HAl.ÜBURTON MAGNÄ(;¡sp ; SETTING RECORD '" 'SiNcH ..................-.'..,-,....,...".... . 7250-8020 .--........., 5 INCH 16-Noy- . 05 6720-7190 2.SPOWERGETHSOGUNT "i5ìNCH PERFORATION RECORD I 16-Noy- i683Ò~699Ò" iT , 05 : COMPLETION RECORD 'TSINCH, 10-NoY- : 7990-9085 : HALLIBURTON CIBP FOR 3.5" I . 05 : CASING /2.5 HSD POWER · JET 6 SPF PERF i 1 , pds,txt m ; COMPLETION 'RECORD 2.5 : OMEGA HSD 6 SPF :COMPl.ETION RECORD2 , HSD POWER JETS 4SPF í SINCH 01-May- , 06 10095- 10450 , 1 I pds · 5 INCH · 02-Feb- '5300-6015 '1 06 , pds 'f'''CÓMPLETIÓj~fRECORö''à 3/8 .. r"!5"'ïNCH"" , HSD POWER JET 6 SPF, 60 · PHASING 11-Feb- i928()-9414 ' , 06 , 1 ; pds p-..".-...------ .""".....-..- "................................."... COMPLETION RECORD 2.25 · POWERJET HSD GUNS, 4 : SPF, 60 DEG, GAMMA RAY / CCl CORRELATION '. ' pds, pdi " 0" SINCH . 29-Jan- ; 06 9615-9833 ."....,-,-""-----------.,-,,,,--. , COMPLETION RECORD 2.875 : 51NCH 31-Jan- I 9180-9950 , POWERJET HSD GUNS, 4 ' 06 : SPF, 60 DEG, GAMMA RAY / i eCl CORRELA nON .¡. pds, pdt Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. I Received By c.1L--- I Date .s-¡;"/fJý Granite Point 54 Forward Plan e e Tom, l~(ò -0 (~ I'm going to follow this up with a Sundry tomorrow however I wanted to pass on to you that we'll be suspending operations on Granite Point 54 until we can make some changes to the unit to accommodate the unexpected packer milling work that we're now faced with. We have been unsuccessful pulling the completion tubing free from the packer. We left a 22' long tubing cutter assembly in the hole when we made the bottom cut just above the packer and this has prevented us from latching the tubing stub just above the packer and pulling it free. Runs with washpipe and shoe have been unsuccessful due to the high toque we're seeing at 11,300' and runs with a downhole motor and milling assembly we unsuccessful making any progress. The CUDD rotary table is torque limited too 9500 ft-Ibs. Our plans will be to suspend operations on GP 54 after running a kill string and moving over to do the Anna 35 Kobe change-out and then either return to GP 54 or move over to King to do some ESP work. The GP 54 has a tubing plug installed and the production casing was bundle tested to 1100 psi for 30 minutes. The return to GP-54 will be dependant on mobilizing a more capable rotary table up from Louisiana and making plans to use oil base mud in the well rather than the diesel system we are currently using to assist us in the packer milling operation. We anticipate we'll be off the Granite Point Platform by Saturday. 1\ .~! 2005 Neil Magee Chevron North America Exploration and Production Company Union Oil Company Of California 909 West 9th Avenue Anchorage, AK 99501 Tel 907 263 7804 Fax 907 263 7884 mac¡een@chevron.com 1 of I 4/26/2006 12:45 PM Re: CUDD 131 BOP Test Cudd 131 BOPE test is due tonight by my understanding oflast test on Granite Pt Well 54, so I am understanding your request as a 1 to 2 day extension. That request is granted; you must test BOPE prior to your next wellbore entry after retrieving the fish. Please contact me as the test schedule becomes more definite so an Inspector can witness the BOPE test. Jim Regg AOGCC Lucas Ken wrote: Jim, as we spoke the CUDD Rig 131 BOP Test would be due tomorrow. We are 2 hours from latching top of tubing fish at 5916' (CUDD Jack is slower than I anticipated). Within a couple of hours we should have the Fish headed out but, would not make it by Midnight Tonight. Could we request scheduling the test latter. Thanks in advance. Kenneth J. Lucas Union Oil Company of California Chevron P.O. Box 8129, Nikiski AK 99635 email: lucask@chevron.com 907-776-6725 Work 907 260-6607 Home 907 252-3916 Cell 907 263-7306 Fax 8':I'~N/i1,!!:;.n " :t"e:...-~; 'j C £)'ì[lh ",t ('J tf.lJ'(;j 1 of 1 4/11/2006 12:53 PM ) ) FRANK H. MURKOWSKI, GOVERNOR AI1ASIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. -¡rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, Alaska 99519 l'P b- 0 ~3 l Re: Granite Point Field GP-54 306-047 \)(j¿~ð~E.D fED 2120GB Dear Mr. Brandenburg: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this/l:day of February, 2006 Encl. ) ) REC1=" It:-I , Chevron === Neil Magee Drilling Engineer Union Oil Company of California P,O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7804 Fax 907 263 7884 Email mageen@chevron.com RECEIVED February 6, 2006 FEB 0 7 2006 Alaska Oil & Gas Cons. Commission Anchorage Tom Maunder Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Re: Granite Point 54 Tubing Replacement (Form 10-403) Mr. Maunder: The purpose of this letter is to advise you of the planned commencement of rig activities on the Granite Point Platform with the CUDD Hydraulic Workover Unit per Conservation Order 351A Rule 4. The anticipated start up date is March 10th. The Granite Point 54 is the only planned worked on the Granite Point Platform at this time. The purpose of the workover on Granite Point Well 54 is to recover the existing parted tubing string from the well and replace it with a new 3-1/2" completion string. The existing tubing string is parted 9' below the tubing hanger. The well will remain completed in the Tyonek C-5 sand interval. The anticipate duration of the rig activation, planned workover and deactivation is twenty-one days. Please contact me at 263-7804 if you have any questions concerning this application. Sincerely, {,%~ Neil Magee Drilling Engineer Attachments Cc: Tim Brandenburg Union Oil Company of California I A Chevron Company http://www.chevron.com c/¡- 2..-17~ð \ STATE OF ALASKA f)7:J ~)'\ ALAt ~ OIL AND GAS CONSERVATION COMM¡ ,A APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Abandon U Alter casing D Change approved program D 1. Typ~ of Request: Suspend U Repair well D Pull Tubing 0 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK 99519 7, KB Elevation (ft): 115' RKB 8. Property Designation: Granite Point Platform/Cook Inlet 11. Total Depth MD (ft): 11,839' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 11976' -13970' MD Packers and SSSV Type: Development Stratigraphic , I ';",RECEIVED . ~'v'! FEB It 7 2006 Perforate U Allsbtml & Gal CU'\§t~~ ,issia Stimulate D Time Extension D A~~rted Re-enter Suspended Well D tubing 5, Permit to Drill Number: Exploratory D 196-013 v/" D 6. API Number: 50-733-20470-00 ,/ o D Service 9. Well Name and Number: Total Depth TVD (ft): 11 ,190' Length Effective Depth MD (ft): 11,695' Effective Depth TVD (ft): 11,005' Plugs (measured): none none GP-54 10. Field/Pools(s): Granite Point Field/Middle Kenai "C" Sands MD 229' 294' 1,120' 3,611' 11,994' 14,070' Tubing Size: PRESENT WELL CONDITION SUMMARY Size 22g 33" 294' 26" 1 ,120' 13-3/8" 3,611' 9-5/8" 11,994' 7" 2,474' 5" Perforation Depth TVD (ft): 9,681' - 10,141' TVD Conditions of approval: Notify Commission so that a representative may witness 3-1/2" 9.2#, L-80 I Packers and SSSV MD (ft): Packer: Halliburton BWD 7" permanent packer @ 11381' SSSV: Halliburton XXO @ 332' 12. Attachments: Description Summary of Proposal LJ 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/10/2006 Oil 0 Gas D 16. Verbal Approval: Date: WAG D GINJ D Form 10-403 Revised 07/20~ N AOMM'SSIONER o R \ G \ AFE 164826 TVD 228' 293' 1,119' 3,327' 9,675' 10,170' Tubing Grade: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ?,q¡/- "C/ Ç'~hone 907-276-7600 Date V / COMMISSION USE ONLY Junk (measured): Burst Collapse 3,450 psi 1,910 psi 6,870 psi 4,760 psi 8,160 psi 7,020 psi 8,290 psi 7,250 psi Tubing MD (ft): 11 ,400' o Service D Plugged WINJ D D WDSPL Abandoned D D Neil Magee 263-7804 APPROVED BY THE COMMISSION Sundry Number: W Q - (YLÞ 7 Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: <:-c.....~ \- -c .......",,<t<- \e" \-0 ,..; \\'~It. <;.<:, ~ X' -\õ ~~~ "s. ....:I? ' t>ê)OO~" . ~~~v~""' ~aT( \1::..C,~f RBDMS 8Ft FEB 2 ]. 2006 Subsequent For quir: . ~t::J ~ z - ".:}- - 0'; Date: tfl"/1- -Dþ Submit in Duplicate ) Granite Point 54 Tubing Replacement Preliminary Procedure 1 Move in CUDD onto Granite Point Platform. 2 ND tree and NU BOPE. Complete RU of CUDD Unit and ancillary equipment. 3 Install TWC and test BOPE. Screw in landing joint and test VBR's. Recover hanger and tubing stub.PU 3-1/2" DP and overshot. 4 Engage tubing stub with overshot and pull tension in tubing. 5 RU slickline. Recover SSSV and set plug in packer tailpipe. Isolate with sand. RD slickline. 6 Attempt to pull tubing free from packer. RU e-line and perform chemical cut. RO e-line 7 Pull tubing free from cut. Attempt to circulate well to diesel. (Additional time due to transfer diesel from IMO tanks) 8 POOH laying down tubing (additional time for rotten tubing) 9 Pressure test production casing 10 PU overshot and RIH PU 3-1/2" DP. Latch tubing stub and pull free. 11 Circulate well to diesel. 12 POOH standing back DP and lay down tubing stub and seal assembly. 13 PU dummy seal assembly and stage in hole circulating diesel. 14 Stab seals into packer and clean off packer top. 15 POOH standing back drill pipe. 16 MU and run completion string. Space out and land hanger. 17 RU slickline. Bail sand and recover plug in packer tailpipe. RD slickline. 18 Set hanger pack-off and lay down landing joint. Set BPV. 19 NO BOPE. NU and test tree. 20 Lay down 3-/12" drill pipe. 21 NO CUOD unit and ancilliary equipment. 22 Offload CUDD unit from Granite Point Platform. (. ../ UNOCALi> L RKB = 115'; 43' Rig Floor to Wellhead Kvaerner SMS Wellhead 1 "'---l 2 - 3---. L,. Ln... L L_: ~ 4 L_ L_ L_¡ ~ L_ L_ ::::.. L_ L_¡ 5 Z Z6 ::i:: 7 ¡--\ 8 TOL (ª? 11,596' C-5 SAND n s L ~ PDTD = 13,976' MAX HOLE ANGLE = 80° @ 12,354' ~ ) GRANl'fE POINT PLATFORM WELL # 54 PROPOSED COMPLETION CASING AND TrJßING DETAIL SIZE WT GRAllE CONN TOP 33" Outside conductor 4 7 26" Inside Conductor 4 7 13-3/8 68 K-55 BTC 47 9-5/8 47 L-80 BTC 46 9-5/8 53.5 P-II0 BTC 73 7" 29 P-II0 KC-BTC 45 7" 29 L-80 TKC-BTC 5,960 5" 15 L-80 SC-KC-BTC 11,596 Baker 5" HMC liner hanger @ 11,596' 3-1/2" 9.2 L-80 SC BTC 44 BOTTOM 229 294 1,120 73 3,611 5,960 11,994 14,070 11 ,400 JEWELRY DETAIL NO.. ITEM: DE.PTH 1 K vaemer Tubing Hanger 44' (AB TC-4S Up X STD V AM DWN) 2 STD V AM x Buttress Pup JT 3 HES XXO Safety Valve Landing 332' Nipple (ID = 2.813") 4 10 ea. McMurry-Macco SFO-l Gas Lift Mandrels with 1-1/2" Valves at: 2250', 3350', 4300' 5200', 6050', 6850', 7600', 8250', 8750', 9250' (TVD) 5 HES Seal Assembly with Nitrile molded seals (18.5') Existing: 6 HES BWD Pennanent Packer 18' Seal Bore Extension 4.4' Millout Extension 7 HES "X" Nipple ID = 2.813" 8 Wireline Muleshoe Re-entry Guide 11,381' 11,437' 11,471' PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 11,976 13,970, C-5 6 1/24/97 TCP REVISED: 1/5/06 DRA WN BY: NM ) UNO CALf> RKB = 115'; 43' Rig Floor to Wellhead K vaerner SMS Wellhead 1 \---.1 2 - L L 3-_ L_ ~ ~ 4L~ L.. L.. L_ L_ ~I ~: 5 Z Z6 ~ ~ =:¡:. 7 ¡--\ 8 C-5 SAND s L ~ PDTD = 13,976' MAX HOLE ANGLE = 80° @ 12,354' ~ ) GRANrr'E POINT PLATFORM: WELL # 54 FINAL COMPLETION: 1/26/97 CASING AND TITHING ,nET AIL SIZE WT GRAUE CONN TOP 33" Outside conductor 4 7 26" Inside Conductor 4 7 13-3/8 68 K-55 BTC 47 9-5/8 47 L-80 BTC 46 9-5/8 53.5 P-II0 BTC 73 7" 29 P-II0 KC-BTC 45 7" 29 L-80 TKC-BTC 5,960 5" 15 L-80 SC-KC-BTC 11,596 Baker 5" HMC liner hanger @ 11,596' 3-1/2" 9.2 1.-80 SC BTC 44 BOTTOM 229 294 1,120 73 3,611 5,960 11,994 14,070 11,400 JEWELRY DETAIL NO. ITEM DEPTH 1 K vaemer Tubing Hanger 44' (AB TC-4S Up X STD V AM DWN) 2 3.6' STD V AM x Buttress Pup JT 3 HES XXO Safety Valve Landing 332' Nipple (ID =2.813") 4 10 McMurry-MACCO SMO-2 SC Gas Lift Mandrels with 1-1/2" Valves: 2,628'; 4,662'; 5,948'; 6,897'; 7,722'; 8,548'; 9,377'; 10,202'; 11,025'; 11,293' 5 HES Seal Assembly with Nitrile/Flourel 11,345-11,365' molded seals 6 HES BWD Permanent Packer 11,381' 18' Seal Bore Extension 4.4' Millout Extension 7 RES "X" Nipple ID = 2.813" 11,437' 8 Wireline Muleshoe Re-entry Guide 11,471' PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 11,976 13,970, C-5 6 1/24/97 TCP O:\DRILLING\SCHEMA TIC\GP\GPP\GP-54 Schm 1-26-97 Completin REVISED: 2/04/97 DRAWNBY:MWD 1~-~ 3M F'1hW Ö1,g 27Jyr(2..1.~ 13-5/811 3M Ki"ref" Spfto1 2Lo-(~.ft) {r'ífW')j S'(v T.cftgØ1 mid 'RamI I zI ~ 13-Sl:Þ SM R;gø- ~d {ti7'", .';.;8.' 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M ~ C..raneHejgb:t ÙW]' Wall 7 Snub Un1t HIi iht T i~ Rdj1lt A~'t'.r:e ~1IUb TTnit Y T" 29# r-110 KC- RTC. -r '191 -...sa TK c- RTÇ.. 3-1fl" 9_211 L-RO SC BTC Granite Pa'nt ChINron ~.lk.J ..~S~IJt.S)'~~ 'CufJdAraøu·.<Cønf«A····..·ln'ç.. '.:'.'......,.:<'.':,.,:.,':.:.......,\;....:'::.......·.'·,,·..·.··'·'····..':.·'..·...··.··i, ......:"..".':".';.'... " ......:"",.,..! ,'....': ··p~ø...··~..,'.···ølU....."'····.I'II~$_~'.ra' ·16.Jano. 06" røv O. no 'scale '" Q 13 _WIT :SM .A.I'LßI.1ß.1' 54"(4.5') 1.1-518- SM VBR Ram ~.5"'(l..Ø15') 1 ~~. ~ 'R1inttlSbtW" 340k Jack Unit R1~~: (21 lIB' "":" . .......'<~+.. t\4 ';"':t:~+ I«I"~ I . I, .. ....... '1 " , ... ~ ~ ~ " 1Í.1i' \,r1:\' G(Ç.815"") 3.CYr v {;I 4.. 1 ~ 1.1'7' y R~l'I1'I~d Unit} ~24ð.1Atf) ~rU12' \. .... ./ . Wö'l'lt Window (lsö.Kj 10.9" , ). I . ;' ))IJ:. ~ / ... / ~ , ' ,," ,../. FJcvatiön (707 otJ4j st.92t \. / " ). r-kmh 'Jnit A. W..."'JtŸ RMt-tt 288'" / " ,. ..... ...... .I / ....... ." 111111 (I ~.~~ .I [~ I: ÐI1 r --~ __"UI~.f.Wm'~_ ) ) Re: Question on Choke Manifold BOPE Hose for Workovers ) . ·J#:r:ç~p~~~·.~(l~~~9f?~$~#~~~çt~~f$a~i~;$~~tY~~·H~?··.··.·....... ,Jp:;Et~})~QQpJ~:t'~~.$QtQQOø··· Neil, I don't specifically remember what wells were worked on in the last campaign. With regard to the regulation citation, for workovers such as what is proposed on GP 54 you need to look at 20 AAC 25.285. .035 is for rotary drilling. The citation I am looking at is 20 AAC 25.285 (c) (9) (A) which is the same as the one you cited. It appears that the hoses you are planning to use meet the regulatory requirement. I will move your sundry forward, recommending approval. Tom Maunder, PE AOGCC \ ~<O-O \~ Magee, Neil wrote, On 2/15/2006 12:05 PM: Tom, I talked with one of our W5L's, Don Fowler and he tells me that the rig up they have with CUDD was quite clean. We're using a 2" 5M single hose with flanged connections between the choke manifold and the BOP. Not a combination of chicksan, hard piping, hose. The 2" hose was selected for workover operations due to the ease of handling and rig up. I understand we've had a waiver for in the past for use of 2"hoses however in reviewing the AOGCC Regulations section 20AAC25.035(e)(4)(F) (i) it appears that if the choke/killline is specifically used in non rotary operations, that a 2" nom diameter is approved. Can you confirm your interpretation is the same for future reference in our workover operations. Regards, Neil Magee Union Oil Company Of California 909 West 9th Avenue Anchorage, AK 99501 Tel 907 263 7804 Fax 907 263 7884 maqeen@chevron.com 1 of 1 2/16/2006 11: 16 AM Doghouse Hazard Sheet and Special Precautions for Use of Diesel i... ) ) Tom, Here's the documents we discussed regarding the use of diesel while changing out the tubing in Granite Point 54. \C\\o'-O\~ Neil Magee Union Oil Company Of California 909 West 9th Avenue Anchorage, AK 99501 Tel 907 263 7804 Fax 907 263 7884 maq ee n@chevron,com . C t t D . t· . Discussion on Use Of Diesel on en - escnp Ion. for GP54.doc ,. Discussion on Use Of Diesel for GP54.doc Content-Type: application/msword 'Content-Encoding: base64 Content-Description: Summary of Hazards (Diesel).doc Summary of Hazards (Diesel).doc Content-Type: application/msword Content-Encoding: base64 1 of 1 2/17/20067:29 AM ) ) The purpose of this document is to discuss the use of No. 2 diesel as a workover fluid in Chevron's Cook Inlet Operations on Well Granite Point 54. Diesel Application in GP 54: Diesel was selected for use on the Granite Point well 54 due to our wish to minimize any aqueous fluid coming into contact with the reservoir. The well was originally drilled with OBM and has been producing water free for almost 8 years. The reservoir pressure in the well is estimated at 1500 psi equating to 3.0 ppg at the top of the completed interval. Diesel will be used to load the well and to monitor fluid levels during the tubing swap. Some circulation of diesel will take place while filling up the wellbore however extended circulation is not planned as part of this tubing change-out. \<;Co-a\~ Contingencies: Although diesel is programmed for use on this well, there are contingency plans to load the well above the packer with seawater if we are able to successfully place a plug in the tailpipe assembly. This decision will be made after operations are underway as the ability to set a tubing plug in the packer tailpipe is unknown. If the tubing swap encounters difficulty and extended fishing operations become apparent we have a plan to utilize an OBM to complete the workover. Diesel No.2 has been selected in place of No. 4 Diesel. The Granite Point Platform uses No.2 diesel to fuel it prime movers and has the ability to provide 2000 bbls additional diesel storage and delivery capability to the surface tanks in the event extensive fluid losses are encountered. Discussion: Flammable and combustible fluids can both be hazardous to use and ifnot used correctly cause fires. By definition flammable fluids have a flash point below 100F and have a vapor pressure greater than 1 psi but less than 40 psi at 1 OOF. Flammable fluid will ignite and bum at normal working temperatures whereas combustible fluids have vapor pressures less than 1 psi and have a "Flash Point between 100F and 200F. In Alaska, diesel fuels are routinely pumped into wells during paraffin cleanouts, coil tubing operations during methanol and diesel/xylene treatments, freeze protecting operations with "dead crude", spill spotting, OBM clean-ups etc. Precautions must be taken to ensure that diesel is not placed in a combustible environment. In pumping operations this condition may take place if heated diesel is vented into the atmosphere in the form of a mist or spray and comes into contact with an ignition source. Should these criteria be met, the combustible fluid will ignite. Fluid Properties Flash Point Auto-ignition Temperature Vapor pressure Diesel Fuel No.2 120F (Min)-204F 490F -545F <.5 psia Diesel Fuel No.4 142F (Min)- 240F 505F <.5 psia ) Operating Guidelines: \'\'-0 -ü \--s During well service operations these risks have been mitigated by operating under strict guidelines which include: Personnel: · Personnel handling or working directly with diesel should ensure that the following PPE is available and in use: Protective Gloves - Chemical resistant gloves (neoprene) Eye Protection - Splash goggles and face shield Protective Clothing - Chemical resistant clothing should be used when long term exposure or splashing is present. Equipment and Rig Up: · Per API Recommended Practice 500, the electrical equipment within a 10' radius of the open diesel storage tank should comply with Class I, Division I (NEC) regulations. · Ensure electrical grounding of surface equipment s checked by the electrician to ensure conductivity. · Insure any potential ignition sources are kept a minimum of 25' away from the diesel storage tanks. · Tanks should be positioned such that there is adequate ventilation to prevent the accumulation of diesel fumes in the surrounding area. · Testing of all high pressure lines and equipment is carried out before introducing diesel. · Monitor pressured lines during pumping operations and ensure spill containment positioned underneath connections and storage tanks. · Do not position any high pressure lines under fired heaters or other open ignition sources. · No.2 diesel starts to gel at 15F. It may be necessary to closed loop circulate the diesel to prevent gelling. Special Precautions: · If there is a fluid spill or leak, the fluid may be expelled as a fluid or a mist. Safeguards to be in place to shut down all pumping equipment immediately from both the work basket and platform deck. · Monitoring temperature of the pumping fluid (ie. ensure diesel in open tanks does not exceed 90F, 10F below the minimum Flash Point) Note: If the fluid temperature is above the flash point, there is sufficient volatility that the vapors given off by the fluid will be rich enough to burn if exposed to an ignition source. · Continuously monitor pressured lines and connections during pumping. · Monitoring wind direction for wind shifts and safeguards in place to shut down immediately. ') These precautions are not all inclusive and will be modified and enhanced based on the conditions which come to light during the workover. \~~-a\~ ) Summary of Hazards ) Diesel Handlina and Use Guidelines \ S. to - a \. S Diesel No.2 will be used as the workover fluid on Granite Point 54. Diesel is a combustible fluid (greater than 1 OOF flash point) with a auto-ignition temperature in excess of 490F. The following recommendations are the minimum requirements to ensure that this fluid may be used safely. Personnel: · Personnel handling or working directly with diesel should ènsure that the following PPE is available and in use: Protective Gloves - Chemical resistant gloves (neoprene) Eve Protection - Splash goggles and face shield Protective Clothing - Chemical resistant clothing should be used when long term exposure or splashing is present. Equipment and Rig Up: · Per API Recommended Practice 500, the electrical equipment within a 10' radius of the open diesel storage tank should comply with Class I, Division I (NEC) regulations. · Ensure electrical grounding of surface equipment s checked by the electrician to ensure conductivity. . Insure any potential ignition sources are kept a minimum of 25' away from the diesel storage ta n ks. · Tanks should be positioned such that there is adequate ventilation to prevent the accumulation of diesel fumes in the surrounding area. · Monitor pressured lines during pumping operations and ensure spill containment positioned underneath connections and storage tanks. · Do not position any high pressure lines under fired heaters or other open ignition sources. · NO.2 diesel starts to gel at 15F. It may be necessary to circulate the diesel more frequently to prevent gelling. · Monitor surface fluid temperature and ensure fluids are kept below the fluid "Flash Point" of NO.2 diesel. (120F (minimum) Note: Flash Point is the temperature at which diesel will ignite if an ignition source comes in contact. Special Precautions: · If there is a fluid spill or leak, the fluid may be expelled as a fluid or a mist. Safeguards to be in place to shut down all pumping equipment immediately from both the work basket and platform deck. Note: If the fluid temperature is above the flash point, there is sufficient volatility that the vapors given off by the fluid will be rich enough to burn if exposed to an ignition source. Decompletion/Recompletion: · Potential exists for trapped pressure if fill has plugged the tubing. A hot tap tool will be ready on location to release trapped pressure while tubing is recovered. · Significantly underpressured reservoir sands (3 PPPG) will be encountered A heightened awareness of downhole fluid levels and management of the mud system volume will required. · Granite Point is not designated as an H2S facility. Cudd Operations and GP 54 ) ) S~~je~t:~udclOpe~~~ì~l1sW~~~~4 Fr~1p;"Il\1¡i~e!, ..Neil".5~ª~~~~~µ1l()c~1,cÞm>···. p~~e:Tp,l.1, Q~~eÞ2.o~p 9Q':,$4:04:~OQQO . .. OO1.~~,:~r::i:~t;: Tom, I've attached the following CUDD HWOU drawings: '\ ~<O--QJ \ S BOP Schematic. (This is Unocal's 5M BOP stack) Choke Manifold Schematic (This is Unocal's manifold.) Drawing of mud pit (top view). We'll be using a CUDD supplied pit rather the platform pit system. Overall equipment layout drawing on the platform. It looks like the platform personnel suspected the tubing had parted 11/23/05 when production dropped off. I'm not sure if they felt a jolt, although you would think that if someone was in the vicinity of the wellhead they would have. Shane Hauck took a wireline crew out on 11/25/05 and confirmed the tubing had parted. This is the only planned workover at this time with the CUDD unit. I believe CUDD is trying to secure some additional work for the unit. (I heard possibly ConocoPhilips but haven't had that confirmed yet.) I haven't forgotten about you questions on A-18. We're getting together with the Oil team after lunch to review your question on the annulus monitoring and the packer integrity question you raised. Regards, Neil -----Original Message----- From: Thomas Maunder [mailto: tom maunder@adrnin. state. ak.. us] Sent: Wednesday, February 08, 2 õo6"·-·-·:g--;··S·6-....Ai'.T·-·..---···- To: Neil Magee Subject: Re: Cudd Operations and GP 54 Neil, I checked the production report for this well. It would appears that the tubing may have parted sometime around Thanksgiving. Is that the case? I suspect there was quite a jolt when it let go. Torn Thomas Maunder wrote, On 2/8/2006 9:42 AM: Neil, I am looking at the sundry for the GP 54 workover. 1. Could you provide 2. Will you be using pit system you use is 3. Interesting using like this before. 4. You only plan this one job on GP. planned? a drawing of the choke and choke manifold. the platform mud pits? A diagram of whatever requested. diesel, I don't remember of diesel being used Are there other HWO operations Thanks in advance for your reply. Call or message with any questions. Tom Maunder, PE AOGCC 1 of2 2/9/2006 1 :48 PM Cudd Operations and GP 54 ') ) Content-Description: BOP stackl.xls stackl.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 ¡. Content-Description: HWOU choke manifold.xls HWOU choke manifold.xls]. Content-Type: application/vnd.ms-excel ,¡ Content-Encoding: base64 view of HWOU mud Content-Description: top view of HWOU mud tank.jpg Content-Type: image/jpeg Content-Encoding: base64 CUDD Content-Description: CUDD Layout.pdf Content-Type: application/octet-stream Content-Encoding: base64 20f2 2/9/2006 1 :48 PM Chok~ line Down$tream Iron III flange~ 5M hose to 2" dual'S*" manualchøke manifôld(refer to attach"'d choke.' manif91d diagram), Drill Deck Elevation Top of Unihead (tbg spool) ') ) 13 5/8" 5M HWOU BOP Stack up r, 138/8" 3M '~ Hydril Annular '--- ./ ~_m nm Ilij ; --~~~~~ r "'I Choke Line - two f1ann..rt 4" J;M "al"..o:: "- ~ ~:lfl\\\'Ii\!!ll!!IIHIllliI +- - ~ -r-y- . ... _"-J_~ " ,13 5/8" 5M Mud Cross" Kill Line - two flanged 3" J;M "al\,..o:: _13,,' ,',,' -,' ~,,' ,', ,', ...-,' ~ iK, n,l L"i,ne UP, stream,', I,r~n , i ,",,: : ~fla,"ged 2~'5+m' steØI ----, " " ", ~ '-Y :-i:liping/valves (WI ",Çi :', :,. . chicsans) , ' , , ~"-"~-,'~:' ~ ~",~,:,~ ~I r ';':~S\~ä~,::,=;)'(;" \ " -'~ ~ "- ./ ~ ':." ..:' a: ' ~. ) ') ~"""""""""" Y- UN CAL Portable 2" Dual Manual Choke Manifold Bypass -:;~t~t'1?~~;.~~._ t;L J¡~ ....:~~~;,\i;:y:ß)::, 1T> gF~' dtr }-, ~~~1;~~ 2" ,7.,<:·:';"'~-::>r>f '. ~" ., , Manual ,~~~iWj.Þf',~,~~~~d !:r .\ ~ftìf.~~~~ ' "~~~~~/': '.' 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Öt1~4'-Ò4 . . œY'O~ J1.o.~:OOaJt) 11>, ;.",~ .-~,. ~!~ ~~~-> ~ntt,f!- ~ ~1\:61.!If)' .Rclly dn~uIlU- RnR: ~~~.-Em - -". t ..o"-.~~~v;.;t~=~,r' 7t{~~·WiÖ!; I ~:~ \ i .:17 -,~ ' ,~,' , . .~ .t;;··:..-tïN~; .... ~ 1J.þ:''f¡ jj"::' ~Ii~""""""'~:~~- .~).. V.,!. c...J. ~.'" ."~ ~#~ ",~ I T~I:T~'" ~~" g , , ~ BIDW Dtlvm ,-1' ~ I- "ir~. J~.¡~....,...'.,. iì.~l;Át:~:'::· ~..~-è }Iii!!!: ~ '.' "\ . .. . .- '·"-.'~:'Pin "~.~.:." j: \ .'<,:' ." I 1 ' ?þ~::~~ '~ ~. ,,1 .z.{~ - .a- .....- >~ ·~:'k1~'. ~!~.~ _ -. _ -"- . ---- -- ._----" ---- -- ---- --- --. --- -~ -----~-------". ---- -- --_.- -~----~"- ~-~-~._------_._~_._------------------- MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg,. J) &1a 1{7ò/04 P. I. Supervisor ~ rt DATE: September 10, 2004 THRU: FROM: Lou Grimaldi, Petroleu m Inspector SUBJECT: No-Flow Test Unocal, Granite Point platform GP-54 Granite Point Field PTD #196-0130 NON-CONFIDENTIAL Fridav, AUQust 20, 2004: I witnessed No-Flow verification on the Granite Point platform in the Granite Point Field, well #54. Following is a timeline and well status during test. 0830 Arrive location, Well 54 flowing to Crude Oil slop tank at <.5 psi. Route to barrel. 0845 Flow well to barrel at bare whisper. Shut-in well at <.5 psi. 0945 Shut-in @ 2 psi, Open well to flow meter @ 1200 scf. 0950 Well flowing gas at <180 scf. 1030 Well flowing gas at bare whisper, Shut-in well at <.5 psi. 1145 Shut-in @ 1 psi. Open well to flow, flowing gas at bare whisper. 1215 Well flowing @ bare whisper. 1400 Well in same state. I turned well back over to production at this point. During this test there was no evidence of fluid made. Gauges used were incapable of measurement at less than 180 scf or .5 psi. SUMMARY: I witnessed No-Flow verification on UNOCAL's Granite Point Field well #GP-54 on the Granite Point Platform. NON-CONFIDENTIAL CC; Dwight Johnson (UNOCAL) SCANNED OCT 0 9 2004, 2004-0910_No-Flow~ GPF - GP-S4_lg.doc MEMORANDUM TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. i. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: May 10, 2001 Safety Valve Tests Granite Point Platform Granite Point Field May 10, 20.0.!; i traveled to UNOCAL's Granite Point Platform and witnessed the semi annual safety valve system testing. I found a very clean platform with sign's of regular maintenance and much flesh paint in evidence. The Safety Valve Systems were tested. 9 wells and 26 components were tested with two failures. Ted Medley lead operator conducted the testing today, he demonstrated good test procedure and was a pleasure to work with. The SSSV on GP-50 failed to close. This is a repeat of the previous tests failure; I expressed the AOGCC's concern for the repair & retest of the failures. The AOGCC test report is attached for reference. Summary; I witnessed the semi annual Safety Valve System testing at UNOCAL's Granite Point Platform in the Granite Point Field. Granite Point Platform, 9 Wells, 26 components 2 failures. 7.7% failure rate. A..ttachment: SVS Granite Point Pit. 05-10-0 ljc NON-CONFIDENTIAL SVS Granite Point Plt. 05-10-01jc Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Ted Me, d!e¥. ., AOGCC Rep: John Cr~p .... Submitted By: John Crisp _ Date: Field/Unit/Pad: Granite Point Field & Pit. Separator psi: LPS 60 HPS 5/10/01 i i I i i i i i i i i Well Permit Separ Set LfP Test Test Test Date Oil, WAG, GIN J, _Number Number PSI PSI Trip Code Code Code Passed (;ns or CYCLE ll-13RD 19li330 60 40 33 e ...... 4' " P .... ¥3-i3 1670210 60 40 40 P P P ....... OIL 31-13 1660550 31-14RD2 1002660 51-23 1670840i 60 40 40 'i~ ..... P ..... OIL 32-13RD 1920200 601 40 40 P P P OIL 42-23RD 1951450 60 40 34 P P P OIL 44-14 1670620 60 40 36 P P P OIL 50 19204i0 60 ' 40 33 1~ 13 ' 8 .... OIL 5t 1920720 60 40 ' 3g' ' e "P e " oI'L · 54 1960130 '60 40 ' 34 e e e OIL Wells: 9 Components: 26 Failures: 2 Failure Rate: 7.69% EJ 90 var Remarks: SSV on well 11-1.3. ,,faile, d to,, ho!d, .,D,.P. This gate valve will be serviced & re-tested. SS: Well ,G'..P'50 failed to close. Ted. Medley will contact Unocal Supervisors about AOGCC',s c0ncem for th.e ?pair & re-test of Ge50's SSSV. 1/16/01 Page 1 ofl SVS Granite Point Pit. 5-10-01jc THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 PL M--ATE IA T H IS M E W L UNDER A R K E R C:LORIkMFILM.DOC MEMORANDUM TO: THRU: FROM: Julie Heusser, Commissioner Tom Maunder, ~--'J'~ ~ P. I. Supervisor b~.~. ~-~,3z3~ John Crisp, Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission SUBJECT: DATE: December 7, 2000 Safety Valve Tests Granite Point Platform Granite Point Field December 7, 2000; I traveled to UNOCAL's Granite Point Platform and witnessed the semi annual safety valve system testing. I found a very clean platform with sign's of~regular maintenance and much fresh Paint in evidence. The Safety Valve Systems were tested. 9 wells and 26 components were tested with two failUres. Ted Medley lead operator conducted the testing today, he demonstrated good test procedure and was a pleasure to work with. The AOGCC test report is attached for reference. . Summary; I witnessed the semi annual Safety Valve System testing at UNOCAL's Granite Point Platform in the Granite Point Field, Granite point Platform, 9 Wells, 26 components 2 failures. 7.7% failure rate. Attachment: SVS Granite Point Pit. 12-07-00jc NON-CONFIDENTIAL SVS Granite Point Plt. 12-07-00jc.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: nocal Operator Rep: Ted Medley AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Granite Point Field &Plt. Separator psi' LPS 60 HPS 12/7/00 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE ll-13RD 1911330 60 40 33 P P P OIL -- 13-13 1670210 60 40 37 P (r5) P 12/8/00 OIL '31-13 1660550, 31-14RD2 1002660 31-23 1670840 60 40 35 P P OIL 32-13RD 1920200 60 40 35 P P P OIL 42-23RD 1951450 60 40 40 P P P OIL 44-14 1670620 60 40 35 P P L OIL 50 1920410 60 40 35 e . e (~) frK,~'~ln~.\~.~.% OIL 51 1920720 60 40 35 'P P P OIL 54 1960130 60 401 36 P P P OIL Wells: 9 Components: 26 Failures: 2 Failure Rate: 7.7% Z39o Day Remarks: Well 31023 is a no flow. ' 12/13/00 Page 1 of 1 SVS Granite Point Plt. 12-07-00jc.xls AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA PLUS 96-013 MUD/LITHO ~2~8-14086 96-013 PIL-SFL ~hYLAR 11977-13927 Page: 1 Date: 01/21/99 RUN RECVD 1 02/10/97 1 02/10/97 96-013 LDT L MYLAR 11977-14005 1 02/10/97 96-013 COMP RCD L/MYLAR 11100-11500 1 02/10/97 96-013 7626 ~CHLUM DITE/LDT 1 03/04/97 lO-4O7 ~'%COMPLET~O~ o~TE //~.~/~?/ /~_~/~/ To ? ~? / ~?/ ~IL~W~oPs RI~ ''~ ~ ~ "" A~re dry ditch samples required? yes ~.~.And received? Was the well cored? yes ~.~.Analysis & description received? y~s~no kre well tests required? ~es no Received? yes no Well is in compliance Initial Unocal Agricultural Products Diversified Business Group 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-marl: childersd@odon, unocal, com UNOCAL ) Debra Childers Geoscience Clerk DATA TRANSMITTAL 97-32 September 23, 1997 To: Laurie Taylor From: Debra Childers 3001 Porcupine 909 W. 9th Avenue Anchorage, AK 99501 Alaska Oil & Gas Anchorage, AK 99519-6247 Unocal Transmitting the following items: Granite Point 22-13 RD 2 11550-12810 ~/ ;//~ '-'-.'. ": 12810-13934 ,,' Granite Point 53 1080-2130 ¢ 'i' 'i~:. -:: i :-! 2130-2970 l 2970-3480 ,- 3480-4410 ' 4410-5250 ' 5250-6480 ' 6480-7320 - 7320-8400' 8400-9480 9480-10560' 10560-11640 11640-12660 ' 12660-13540" 13540-13950" Granite Point 53, C5 Lateral 13380-14460 - 14460-15540 15540-16657- Granite Point 53, Sidetrack 1 13880-14556 Granite Point 54 ¢"~ - _ ~, 9000-11160 Granite Point 55 1320-2400 . ~ - ;~ 2430-3480 3510-4560 4590-55t8 Please acknowledq,e ,receipt by siqnincl and returning one copy of this transmittal or FAX to (907) 263-7828 . Received by: , ~ .... ,.. . .-, Unocal Agricultural Products Diversified Business Group 909 West 9th Ave, Anchorage, AK 99501 Tele: (907) 263-7889 lax: (907) 263-7828 E-mail: epardac ! @anchorage. unocal corn UNOCAL Debra Childers Geoscience C/erk DATA TRANSMITTAL 97-07 March 3, 1997 To: Laurie Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From' Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting · I Graniie POint 54 I FieldTape / Listing 1/20/97 I Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828 I Received by: ~ E~~.~ ~ I Date: STATE OF ALASKA ALASKA L _ AND GAS CONSERVATION ,.,OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal 96-0013 3. Address 8. APl Number P.O. Box 196247 Anchorage, AK 99519 50- 733-20470 4. Location of well at surface ~ "~~"~'"'""'~-'"T~ 9. Unit or Lease Name 2427' FNL & t303' FWL of Sec. 13, T10N, R12W~;'~_~- ~/'~,~~' "~'~.,;,~.,~:.,;¢,¢;" '~: ~';' ~'~ Granite Point Field At Top Producing Interval ~... .... . ~ 54 ADL t 8761/374045 At Total Depth ~.~ 11. Field and Pool 4746' FNL & 2112' FEL, Sec. 23, T10N, R12W ........... ' -.":i- . Granite Point Field/Middle Kenai "C" Sands 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 114.75 RKB (MLLW)I ADL 18761 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/23/96 1/19/97 1/26/97 75 feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)I 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 14,086' MD/10,186' TVD 13,976' MD/10,143' TVD Yes: X No: N/A feet MD N/A 22. Type Electric or Other Logs Run Gamma Ray, CCL, Dual Induction, Density 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68 K-55 45 1120 17-1/2" 394 bbls Class G 9-5/8" 47/53.5 L-80/P-110 45 361 t 12-1/4" 600 bbls Class G 7" 29 P-110IL-80 45 11994 8-1/2" 160 bbls Class G 5" 15 L-80 45 14070 6 53 bbls Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 11471 11381' 11,976'-13,970' MD C-5, 6 SPF 9681'-10,141' TVD 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.) 1/28/97I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 2/2/97 12 TEST PERIOD => 502 226 .5 48/64I 451 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 250 1040 24-HOUR RATE--> 1004 453 1 39 deg 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Interbedded sandstones; conglomerates, claystones and coals. Pay zone is a sandy conglomerate averaging 12% porosity with an estimated Sw of 39%. RECEiVeD Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE FEB 1 4.. 1997' Submit in duplicate 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. C-1 Sand 11,065 9084 C-2 Sand 11,455 9366 None C-5 Sand (Producing zone) 11,998 9693 31. LIST OF AI-I'ACHMENTS Daily Operations Summary, Wellbore Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Dale A. Haines,~Y'~ ~..~,_j[ j Drilling Manager 'February 5, 1997 Signed .C~ Title Date Form 10-407 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- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". RECEIVED Alrt¢',¢-i (-)il 8, C,~-,~ Cdn~. Cornm~r~s~or~ UNOCAL RKB = 115'; 43' Rig Floor to Wellhead Kvaerner SMS Wellhead TOL @ 11,596' GRANdamE POINT PLATFORM WELL # 54 FINAL COMPLETION: 1/26/97 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 33" Outside conductor 47 229 26" Inside Conductor 47 294 13-3/8 68 K-55 BTC 47 1,120 9-5/8 47 L-80 BTC 46 73 9-5/8 53.5 P-110 BTC 73 3,611 7" 29 P-110 KC-BTC 45 5,960 7" 29 L-80 TKC-BTC 5,960 11,994 5" 15 L-80 SC-KC-BTC 11,596 14,070 Baker 5" HMC liner hanger @ 11,596' 3-1/2" 9.2 L-80 SC BTC 44 11,400 JEWELRY DETAIL NO. ITEM DEPTH 1 Kvaemer Tubing Hanger 44' (AB TC-4S Up X STD VAM DWN) 2 3.6' STD VAM x Buttress Pup JT 3 HES XXO Safety Valve Landing 332' Nipple (ID = 2.813") 10 McMurry-MACCO SMO-2 SC Gas Lift Mandrels with 1-1/2" Valves: 2,628'; 4,662'; 5,948'; 6,897'; 7,722'; 8,548'; 9,377'; 10,202'; 11,025'; 11,293' HES Seal Assembly with Nitrile/Flourel molded seals HES BWD Permanent Packer 8' Seal Bore Extension 4.4' Millout Extension HES "X" Nipple ID = 2.813" Wireline Muleshoe Re-entry Guide 11,345-11,365' 11,381' 11,437' 11,471' C-5 SAND PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 11,976 13,970, C-5 6 1/24/97 TCP PDTD = 13,976' MAX HOLE ANGLE = 80° @ 12,354' O:~DRILLING\SCHEMATIC\GP~GPP~GP54-FIN. DOC REVISED: 2/04/97 DRAWN BY: MWD GRANITE POINT 54 DAY 1-2 (11/23-11/24/96) ACCEPT RIG @ 11/23/96 @ 00:00 HRS. RIH WITH 17-1/2" BIT AND BHA AND DRILL FROM 294' TO 1,132'. CBU. POOH. RIH WITH 13-3/8" 68#/FT K- 55 CSG AND KVAERNER SMS WELLHEAD. MIX AND PUMP LEAD AND TAIL CEMENT SLURRIES. CEMENT RETURNS WERE ACHIEVED AT SURFACE. LD RISER. NU AND TEST BOP'S. RIH WITH 12-1/4" BIT AND MOTOR. DAY 3 (11/25/96) RIH WITH 12-1/4" BHA. TAG CEMENT @ 888'. DRILL OUT TO 1,142'. PERFORM LEAK-OFF TEST--FRAC GRADIENT WAS .98 PSI/FT. DIRECTIONAL DRILL FROM 1,143' TO 1,693'. SOME MAGNETIC INTERFERENCE FROM GP 13-13. DAY 4 (11/26/96) DIRECTIONAL DRILL 12-1/4" HOLE FROM 1,693' TO 2,578'. DURING THE FIRST PART OF THE 12-1/4" HOLE, MAGNETIC INTERFERENCE PROBLEMS WERE ENCOUNTERED FROM GP 13-13. DAY 5-10 (11/27/96 - 12/2/96) DIRECTIONALLY DRILL 12-1/4" HOLE F/2578'-3611'. POOH. RUN & CEMENT 9-5/8" CASING @ 3597' W/950 SX LEAD @ 12.8 PPG FIB 168 SX TAIL @ 15.8 PPG DISPLACING CEMENT WITH OIL BASED MUD. CIRCULATED CEMENT TO SURFACE. WASHOUT WELL HEAD & TEST BOP. CHANGE SURFACE SYSTEM TO OIL BASED MUD. RIH W/8-1/2" PDC ON MOTOR ASSBY. DRILL 8-1/2" HOLE TO 3621' & CONDUCT LOT TO 17.29 PPG EMW. DIRECTIONALLY DRILL 8-1/2" HOLE F/3621'-8301' DAY 11 (12/3/96) DIRECTIONALLY DRILL 8-1/2" HOLE F/8301' - 9070'. DAY 12 (12/4/96) DIRECTIONALLY DRILL 8-1/2" HOLE F1 9070' - 9558'. DAY 13 DRILL 8-1/2" HOLE 9558'-9567'. POOH. TEST BOPE, OK. RIH W/BHA AND DRILL 6" HOLE TO 9815'. DAY 14 - 16 (12/6/96 12/7/96) DIRECTIONALLY DRILL 8-1/2" HOLE F/9815' - 9983' WITHOUT MWD. POOH F/MWD. CHANGE OUT MWD & RIH TAKING CHECK SHOTS. DIRECTIONALLY DRILL 8-1/2" HOLE F/9983' - 11048'. POOH F/BIT. RIH W/ 8-1/2" MOTOR ASSBY. DAY 17(12/9/96) CONTINUE TO RIH WI 8-1/2" MOTOR ASSBY. DIRECTIONALLY DRILL 8-1/2" HOLE F/11,048' - 11,455'. DAY 18 (12/11/96) SLIDE 11,455'-11,468'. ROTATE 11,468'-11,484'. SLIDE 11,484'-11,606'. POOH FOR BHA CHANGE. MU BHA #7. SET MOTOR AKO TO 1.3 AND LD TOP STABILIZER. SURFACE CHECK MWD AND MOTOR--OK. RIH TO 11,606 AND SLIDE 11,606'-11,670' @ 10 DEG LEFT. DAY 19 (12/11/96) ROTARY AND DIRECTIONALLY DRILL FROM 11,670' TO 11,937'. SLIDE FROM 11,937'-11,942'. BHA BECAME STUCK. ATTEMPT TO JAR STUCK PIPE. GOOD CIRCULATION AND JARRING ACTION. RU APRS WLU FOR STRINGSHOT BACK-OFF. DAY 20 (12/11/96) RU APRS. RIH AND FIRE STRING SHOT. BACKOFF ONE JOINT ABOVE DRLG JARS. POOH WITH DRILL STRING. PU FISHING ASSEMBLY. RIH AND TAG @ 11,766'. ClRC DOWN TO TOP OF FISH AND SCREW INTO FISH. JAR STUCK FISH. DAY 22-23 (12/13-12/15/96) ATTEMPT TO JAR FISH LOOSE. NEG. BACK-OFF 1 JT ABOVE JARS. POOH. RIH WITH FISHING ASSEMBLY. SCREW INTO FISH. ATTEMPT TO JAR. NEG. BACK-OFF FISH. LEFT FISHING JARS IN HOLE. POOH. BEARINGS FAILED ON ELMAGO BRAKE. REPAIR SAME. PU 2-7/8" TUBING. RIH WITH -BULL-NOSE CEMENT STRING. STINGER PACKED-OFF WITH COAL. POOH AND CLEAN-OUT STINGER. RIH WITH MULE SHOE ON STINGER. TAG FISH @ 11,736'. PUMP KICK-OFF PLUG. CIP @ 13:06 HRS ON 12/15/96. CIRC. THE LONG WAY AND CLEAN-UP DP. POOH AND LD TBG. TEST BOPE. DAY 24 (12/16/96) COMPLETE BOP TEST. MU BHA AND SET MOTOR AKO @ 1.30. DRILL RATTY CEMENT @ 10,978'-11,037'. DRILL HARD CEMENT 11,038' TO 11,257'. KICK-OFF CEMENT PLUG AND DRILL TO 11,450'. DAY 25 (12/17/96) DRILL 8-1/2" HOLE FROM 11,450' TO 11,960'. REACHED 8-112" TD @ 12,029' ON 12/18/96 @ 5:30 HRS. TOP OF C-5 IS APPROXIMATELY @ 11,968'. DAY 26 (12/18/96) ROTARY DRILL 8-1/2" HOLE TO 12,029'--TD. POOH TO 9-5~8" SHOE. CSDL. CONT POOH. LD BHA. RU TO RUN 7" CASING. RUN CSG TO 3,773'. FILL- UP TOOL LEAKED. FIX SAME. DAY 26 (12/19/96) CONT TO RIH WITH 7" 29 LB/FT CASING. CSG STUCK @ 9,596'. WORK CASING--EVENTUALLY BROKE FREE. POOH. PULLED TIGHT FROM 9,626' TO 9,284'. PULLED FREE FROM 9,284' TO SURFACE. DAY 27-29 (12/20-12/22/96) CONT POOH WITH 7" CSG. LOST 11 TURBOLIZERS. CHANGE PIPE RAMS. PU AND RIH WITH CLEANOUT ASSEMBLY. PUSH JUNK TO BTM. MILL UP JUNK. POOH AND LD BHA. CHANGE PIPE RAMS. RIH WITH 7" 29 LB/FT CASING. CASING RAN FREE TO 11,810'. WORK PIPE DOWN TO 12,014. RU CEMENTING EQ. PUMP CEMENT JOB--RECIPROCATING PIPE. DISPLACED WITH 367 BBLS OF MUD. PIPE STUCK 15' HIGH. 7" SHOE IS @ 11,994'. DAY 30-37 (12-23/96-12/29/96) CONT DISPLACING CEMENT. SET EMERGENCY SLIPS AND PACKOFF. LAY DOWN 5" DRILL PIPE. TEST BOPE, OK. RIH W/MILL ASSY. PU 3-112" D.P. TAG CMT @ 9670'. CLEAN OUT CMT. CHANGE OVER TO 8.3 PPG OBM. DRILL CMT T/11,192'. TEST 7" CASING TO 3500', BLED TO 3.400 PSI IN 30 MINS. DRILL T/12,039'. PERFORM FIT W/8.4 PPG OBM. FRACTURE GRADIENT IN 795 PSI/FT. POOH RIH AND DRILL 6" HOLE F/12,039'-12,139'. POOH. PU TURBINE & RIH. DRILL 6" HOLE 12,139'-12,167'. DAY 38 (12/30/96) DRILL WITH NEYTFOR TURBINE F/12,167'- 12,257'. CBU. POOH. LD TURBINE AND IMPREGNATED DIAMOND BIT. PU MOTOR AND INSERT BIT. RIH. ROTATE F/12,257'-12,260'. DAY 39-40 (12/30/96-1/1/97) ROTARY DRILL 6" HOLE FROM 12,260' TO 12,335'. TRIP FOR BHA. MUD MOTOR FAILED AFTER 6.1 HOURS. TEST BOP'S/ PU NEW MOTOR RIH. REPLACE TRACTION MOTOR ON DRAWORKS. DRILL 6" HOLE FORM 12,335'-12,434'. DAY 41 (1/2/97) DRILL 6" HOLE FROM 12,434' TO 12,539'. TRIP FOR BIT. LD MUD MOTOR AND PU TURBINE AND HYCALOG 472. RIH TO 12,144'. REAM FROM 12,144' TO 12,449'. DAY 42-44 (1131-11597) RIH WITH NEYRFOR TURBINE AND DRILL 6" HOLE FROM 12,539' TO 12,749'. REAM OUT TO SHOE. POOH WITH BHA. INSTALL NEW GOOSE NECK. LD TURBINE AND MWD. MU ROTARY ASSEMBLY AND RIH. SMOOTH TRIP IN HOLE. DRILL 6" HOLE F/12,749' TO 12,916'. BACK REAM OUT. HUNG UP AT 12,740'-721' JAR FREE. REAM OUT HOLE. POOH WITH ROTARY BHA. DAY 45-53 (1/6/-1/14/97) RIH WITH BHA. DRILL 6" HOLE TO 13,000'. POOH. CHANGE BHA. RIH. DRILL 6" HOLE TO 13,094'. POOH. CHANGE BHA. RIH WITH BHA AND DRILL 6" HOLE TO 13,154'. POOH. CHANGE BHA. TEST BOPE-- WITNESSED BY JOHN SPAULDING OF AOGCC. EVERYTHING PASSED ACCEPT ANNULAR. CHANGE ANNULAR RUBBER OUT. RETESTED ANNULAR TO 250/3,500 PSI-- PASSED TEST. RIH WITH BHA AND DRILL 6" HOLE TO 13,296'. POOH AND CHANGE BHA. RIH WITH BHA AND DRILL 6" HOLE TO 13,389'. POOH AND CHANGE BHA. RIH WITH BHA. LOST ELECTRICAL POWER TO DRAWORKS. RUN ON EMERGENCY SYSTEM. CONTINUE TO RIH WITH BHA. DRILL 6" HOLE TO 13,545'. POOH WITH BHA. PU P/HF MOTOR AND 6" PDC BIT AND RIH. ROTARY DRILL 6" HOLE 13,545' TO 13,670'. ASSEMBLY BUILDING. PULL BIT DUE TO BHA. DAY 54 (1/7/97) POOH WITH BHA. PU MUD MOTOR SET @ 1.3 AKO. RIH WITH BHA. DRILL 6" HOLE FI13,545'-13,756'. DAY 55 (1/16/97) DRILL 6" HOLE TO 13,786'. MOTOR BEGAN TO STALL. POOH. CHANGE BHAAND RIG. REAM FROM 13,740'-13,786'. DRILL 6" HOLE 13,786'-13,870'. QUICK PRESSURE INCREASE WAS SEEN AND ROP STOPPED. DAY 56-58 (1/17-1/19/97) DRILL 6" HOLE TO 13,870'. POOH. MOTOR SHAFT FAILED. TEST BOPE-- OK. CHANGE BHA AND RIH. DRIL 6" HOLE F/13,870'-14,025'--DROPPING ANGLE. POOH. PU NEW MOTOR AND RIH. DRILL 6" F/14,025'-14,086'. DRILLING BREAK OCCURRED. CBU--COAL. POOH AND LD BHA. RU SCHLUMBERGER AND PU DRILLPIPE CONVEYED LOGGING TOOLS. RIH WITH LOGGING TOOLS. DAY 59 (1/20/97) CONTINUE RIG WITH DUAL PHASOR, DENSITY, AND GAMMA RAY ON 3- 112" DRILLPIPE. RIH WITH WIRELINE. LATCH UP WET CONNECT. LOG DOW Nll,923'-14,055'. LOG UP 14,055-11,923'. POOH WITH WIRELINE AND DRILLPIPE. RD SWS. RU AND RUN 5" 15 LB/FT CASING. DAY 60 (1/21/97) CONTINUE TO RIH WITH 5" 15 LB/FT LINER. RU CEMENT EQ AND TEST. PUMP 53 BBLS OF CEMENT--BUMP PLUGS AND SET HANGER. RELEASE FROM HANGER AND POOH TO 9,740'. CIRCUALTE AND THEN POOH. MU CLEANOUT ASSEMBLY. DAY 61 (1/22/97) RIH 7" CLEANOUNT ASSEMBLY AND TAG CEMENT @ 11,175'. DRILL CEMENT TO 11,596'. CBU AND CSDL. TEST CSG TO 3,500 PSI--OK AND PU 5" CLEANOUT ASSEMBLY. DRILL CMT Fl11,596'-11,604'. CLEANOUT RS NIPPLE. DRILL CMT STRINGERS Fl11,607'-11,668'. POOH DAY 63-65 (1/24-1/26/97) POOH WITH CLEANOUT ASSEMBLY. RIH WITH 3-3/8" TCP GUNS AND PERFORATE THE C-5 Fl11,496'-11,976'. POOH AND LD GUNS--ALL SHOTS FIRED. WELL TAKING DIESEL AT .3 BPM. RU SWS WIRELINE UNIT AND MU HALLIBURTON PERMANENT PACKER. RIH WITH PACKER. PULL GR/CCL STRIP AND TIE-IN LOG. SET PACKER @ 11,346' WLM. POOH. RIH PU 3-1/2" 9.2 LB/FT L-80 BUTTRESS GAS LIFT COMPLETION. SPACEOUT AND LAND HANGER. SET BPV AND ND BOPE. MU TREE. TEST HGR, TREE, AND PACKOFF TO 5,000 PSI--OK. TURN WELL OVER TO PRODUCTION. LAY DOWN 3-1/2" DRILLPIPE. DAY 66 (1/27/97) CONTINUE LAY DOWN 3-1/2" DRILLPIPE. RELEASE RIG ON 1/27/97 @ 12:00 HRS. SURVEY' CALCULATION AND FIELD W IKSHEET N°. 0450-81687 Sidetrack No. 1 Company UNOCAL Rig Contractor & No. NaboreAla~ka Drill- Rig: #156 _ Field GRANITE POINT FieLD Well Name & No. GRANITE POINT PLATFORM/GP54 Survey Section Name Definitive Survey BHI Rep. MILLER, SUTHERLAND ' WELL DATA Target TVD (F'r) ~ Target Coord. N/S Slot Coord. N/S -2415.00 Grid Correction 0.0OO Depths Measured From: RKB ~] MSL ~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 1297.00 Magn. Declination 22.220 Calculation Method MINIMUM CURVATURE Target Direction (Do) Build~Walk\DL per: lOOftr~ 30m~ lOm~ Vert. Sec. Azim. 190.69 Magn. to Map Corr. 22.220 Map North to: OTHER i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length '['VD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (OD) (FT) (F'T) (F'I~ (FT) (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 23-NOV-96 GSS 237.00 0.25 255.00 237.00 237.00 0.22 -0.13 -0.50 0.11 0.11 ,,, 23-NOV-96 GSS 377.00 0.75 315.00 140.00 376.99 -0.16 0.44 -1.44 0.47 0.36 ,, 23-NOV-96 GS$ 466.00 0.82 344.00 89.00 465.99 -1.06 1.46 -2.03 0.45 0.08 ......... 23-NOV-96 GSS 565.00 0.75 334.00 99.00 564.98 -2.21 2.72 -2.51 0.16 -0.07 23-NOV-96 GSS 735.00 0.63 300.00 170.00 734.97 -3.41 4.19 -3.81 0.25 -0.07 23.Nov.96 GI~ 913.00 0.83 295.00 178.00 912.95 -4.05 5.22 -5.82 0.12 0.11 23-NOV'-96 GSS 1091.00 0.50 335.00 178.00 1090.94 -5.00 6.47 -7.32 0.31 -0.19 25-NOV-96 MWD 1130.00 0.85 32.1.00 39.00 1129.94 -5.33 6.85 -7.57 0.99 0.90 25-NOV-96 MWD 1164.00 1.60 336.00 34.00 1163.93 -5.88 7.48 -7.92 2.38 2.21 25-NOV-96 MWD 1220.00 3.40 341.30 56.00 1219.87 -7.97 9.77 -8.78 3.24 3.21 25-NOV-96 MWD 1302.00 4.70 330.20 82.00 1301.67 -12.65 14.99 -11.22 1.84 1.59 25-NOV-96 MWD 1380.00 5.20 300.30 78.00 1379.39 -16.26 19.54 -15.87 3.33 0.64 -38.33 25-NOV-96 MWD 1496.00 3.52 252.93 116.00 1495.08 -16.37 21.15 -23.81 3.30 -1.45 125-NOV-96 MWD 1567.00 2.24 237.96 71.00 1565.99 -14.41 19.78 -27.07 2.08 -1.80 26-NOV-96 MWD 1698.00 5.10 202.20 131.00 1696.73 -6.97 13.02 -31.44 2.70 2.18 -27.30 26-NOV-96 MWD 1761.00 6.78 203.30 63.00 1759.39 -0.59 7.02 -33.97 2.67 2.67 1.75 26-NOV-96 MWD 1871.00 10.23 205.14 110.00 1868.16 15.21 -7.79 -40.69 3.15 3.14 1.67 .... 26-NOV-96 MWD 1971.00 14.03 198.65 100.00 1965.91 35.82 -27.33 -48.34 4.03 3.80 -6.49 26-NOV-96 MWD 2064.00 16.96 196.42 93.00 2055.52 60.49 -51.02 -55.78 3.21 3.15 -2.40 26-NOV-96 MWD 2157.00 19.93 198.88 93.00 2143.74 89.68 -79.04 -64.75 3.30 3.19 2.65 26'NOV-96 MWD 2248.00 22.65 201.27 91.00 ~.~8.52 122.26 -110.05 -76.13 3.14 2.99 2.63 ,, 26-NOV-96 MWD 2342.00 25.16 204.01 94.00 2314.45 159.50 -145.18 -90.83 2.92 2.67 2.91 26-NOV-96 MWD 2437.00 28.09 206.18 95.00 2399.37 200.72 -183.70 -108.92 3.25 3.08 2.28 i i iiii i m ii i i i ii ii i i i i i mil Il II I II I I I SURVEY CALCULATION AND FIELD W'"' KSHEET Job No. 0450-81687 Sidetrack No. 2 of 5 Company UNOCAL Rig Contractor & No. Nabors Alaska Drill - Rig: #156 Field GRANITE POINT Well Name & No. GRANITE POINT PLATFORM/GP54 Survey Section Name Definitive Survey BHI Rep. MILLER, SUTHERLAND ~ .~ ' WELL DATA Target TVD (FT) ~ Target Coord. N/S Slot Coord. N/S -2415.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL E] ssE] Target Description Target Coord. F_./W Slot Coord. E/W 1297.00 Magn. Declination 22.220 Calculation Method MINIMUM CURVATURE Target Direction {DO) .. Build~Walk\DL per: lOOft[~ 30mE] lOmE] Vert. Sec. Azim. 190.69 Magn. to Map Corr. 22.220 Map North to: OTHER I ii SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment ,TYPe . {DO) (DD) {Er) (FI') (FT) (F'D (Per lO0 .FO Drop (-) Left (-) 26-NOV-96 MVVD 2533.00 30.83 207.60 96.00 2482.95 246.04 -225.80 -130.29 2.95 2.85 1.48 , , 26-Nov-96 MWD 2624.00 33.34 207.42 91.00 2560.05 292.31 -268.66 .152.61 2.76 2.76 -0.20 / 27-N 0V-96 MWD 2716.00 35.47 208.73 92.00 2635.95 341.91 -314.52 -177.09 2.45 2.32 1.42 27-NOV-96 MWD 2812.00 37.65 209.49 96.00 2713.06 396.16 -364.47 -204.91 2.32 2.27 0.79 ' 27-Nov-96 MWD 2905.00 39.17 209.56 93.00 2785.93 450.84 -414.75 -233.39 1.64 1.63 0.08 27-NOV'96 MWD 2998.00 39.22 210.21 93.00 2858.00 506.34 -465.70 -262.67 0.44 0.05 0.70 ! 27-NOV'96 MWD 3092.00 39.13 210.93 94.00 2930.87 562.18 -516.83 -292.e7 0.49 -0.10 0.77 ...... . ~:/-NOv-98 MWD 3185.00 39.02 211.43 93.00 3003.07 617.10 -566.98 -323.22 0.36 -0.12 0.54 , , 27-NOV-96 MWD 3278.00 38.62 211.26 93.00 3075.53 671.65 -616.77 -353.55 0.45 -0.43 -0.18 27-NOV-9~ MWD 3372.00 39.10 211.27 94.00 3148.73 726.86 -667.18 -384.15 0.51 0.51 0.01 27-Nov-98 MWD 3464.00 38.89 211.78 92.00 3220.23 780.97 -716.53 -414.42 0.42 -0.23 0.55 28-NOv-96 MWD 3566.00 38.87 212.06 102.00 3299.63 840.65 -770.87 -448.27 0.17 -0.02 0.27 30.NOV-96 MWD 3642.00 38.45 211.20 76.00 3358.98 884.99 -611.30 -473.17 0.90 -0.55 -1.13 30-NOV-96 MWD 3735.00 39.05 210.81 93.00 3431.51 939.58 -861.19 -503.16 0.70 0.65 -0.42 30.NOV-96 MWD 3828.00 39.22 210.94 93.00 3503.64 994.67 -911.57 -533.28 0.20 0.18 O. 14 30-NOV-98 MWD 3923.00 39.85 210.56 95.00 3576.91 1051.47 -963.54 -564.20 0.71 0.66 -0.40 30-NOV-96 MWD 4017.00 40.29 210.44 94.00 3648.84 11 08.40 -1015.68 -594.91 0.48 0.47 -0.13 30-NOV-96 MWD 4111.00 40.75 210.15 94.00 3720.30 1165.93 -1068.41 -625.72 0.53 0.49 -0.31 30- NOV-98 MWD 43(X).00 39.90 209.60 189.00 3864.39 1281.44 -1174.48 -686.64 0.49 -0.45 -0.29 30-NOV-98 MWD 4393.00 39.08 209.42 93.00 3936.16 1 337.42 -1225.93 -715.77 0.89 -0.88 -0.19 30-NOV-96 MWD 4581.00 40.33 209.09 188.00 4080.80 1451.27 -1330.71 -774.48 0.67 0.66 -0.18 , , 30-NOV-96 MWD 4854.00 39.70 208.14 273.00 4289.88 1618.28 -1484.80 -858.53 0.32 -0.23 -0.35 30-NOV-96 MWD 5043.00 39.19 208.16 189.00 4435.83 1732.63 -1590.67 -915.19 0.27 -0.27 0.01 I 01-DEC-96 MWD 6,?.36.00 37.86 208.~7 193.00 4588.82 i847.27 -1698.3i) -g'~2156 - 0.73 -0.69 0.37 ...................................... I I rl kiZl .' SURVEY CALCULATION AND FIELD W 'RKSHEET Job No. 0450 1667 S,d,rackNo. .., 3 of 5 Company UNOCAL Rig Contractor & No. Nabors Alaska Drlg- Rig: #156 Field GRANITE POINT F~..~ Well Name & No. GRANITE POINT PLATFORM/GP54 Survey Section Name Definitive Survey BHI Rep. MILLER, SUTHERLAND ~ ,~ ~ WELL DATA , , Target TVD .(FT) ~ Target Coord. N/S Slot Coord. N/S -2415.00 Grid Correction 0.000 Depths Measured From: RKB ~] MSL 0 SS~ Target Description Target Coord. F_.YW Slot Coord. EAN 1297.00 Magn. Declination 22.220 Calculation Method MINIMUM CURVATURE Target Direction ....... .{ODI Build~Walk\DL per: lOOft[~ 30m0 lOm~ Vert. Sec. Azlm. 190.69 Magn. to Map Corr. 22.220 Map North to: OTHER ........... SURVEY DATA ........ , , Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type e'~ So) ~q ,.. {FQ, {F'Q ........... (F'~. ..... ~ ....... ..LFT~ (PerlOO__F~'} Drop(-) Left(-) 01 -DEc-96' MWD 5426.00 38.59 209.24 190.00 4736.08 1958.84 -1799.07 -1029.66 0.40 0.38 O. 19 , , 01-DEC-96 MWD 5520.00 38.71 209.66 94.00 4809.49 2014.43 -1850.18 -1058.53 0.32 0.13 0.47 / 01 .DEC-96 MWD 5612.00 38.94 209.58 92.00 4881.17 2068.98 -1900.32 -1087.05 0.26 0.25 -0.11 ,., 01-DEC-96 MWD 5706.00 39.61 210.10 94.00 4953.93 2125.19 -1951.94 -1116.66 0.79 0.71 0.55 0i -DEc-96 MWD 5799.00 39.92 209.82 93.00 5025.42 2181.35 -2003.47 -1146.36 0.38 0.33 -0.30 01 -DEC'96 MWD 5988.00 38.38 210.33 189.00 5171.99 2293.91 -2106.73 -1206.15 0.83 -0.81 0.27 01 -DEC-96 MWD 6080.00 38.58 210.02 92.00 5244.01 2347.66 -2156.22 -1234.93 0.30 0.22 -0.34 01 -DEC-96 MwD 6172.00 39.09 210.50 92.00 5315.67 2402.23 -2206.05 -1264.00 0.64 0.55 0.52 01 -DEC-96 MWD 6268.00 39.49 210.24 98.00 5389.97 2459.47 -2258.50 -1294.73 0.45 0.42 -0.27 01 -DEC-96 MWD 6362.00 38.76 210.90 94.00 5462.89 2515.25 -2309.57 -1324.90 0.89 -0.78 0.70 01 -DEC-96 MWD 6551.00 37.21 209.09 189.00 5611.86 2625.01 -2410.29 -1383.07 1.01 -0.82 -0.96 01 -DEC-96 MWD 6738.00 37.49 208.89 187.00 5760.51 2732.72 -2509.52 -1438.05 O. 16 O. 15 -0.11 01 -DEC-96 MWD 6923.00 38.11 209.14 185.00 5906.69 2640.36 -2608.66 -1493.05 0.35 0.34 O. 14 01 -DEC-96 MWD 7111.00 38.54 208.57 188.00 6054.18 2951.13 -2710.79 -1549.31 0.30 0.23 -0.30 01 -DEC-96 MWD 7300.00 39.74 207.94 189.00 6200.76 3064.87 -2815.87 -1605.78 0.67 0.63 -0.33 02- D EC-96 MWD 7393.00 39.44 207.43 93.00 6272.43 3121.55 -2868.36 -16,33.32 0.48 -0.32 -0.55 . 02-D EC-96 MWD 7584.00 38.31 208.77 191.00 6421.1 3 3235.93 -2974.10 -1689.76 0.74 -0.59 0.70 02-DEC-96 MWD 7772.00 38,06 20g.40 188.00 6568.90 3346.21 -3075.67 -1746.25 0.25 -0,13 0.34 02-DEC-9(~ MWD 7865.00 38.16 209.52 93.00 6642.07 3400.56. -3125.64 -1774.48 0.13 0.11 0.13 02-DEC-96 MWD 8056.00 37.61 208.70 191.00 6792.82 3511.83 -3228.11 -1 631.55 0.39 -0.29 -0.43 02-DEC-96 MWD 6246.00 38.22 209.04 190.00 6942.72 3822.75 -3330.35 -1 687.92 0.34 0.32 O. 18 02-DEC-96 MWD 8437.00 38.46 208.98 191.00 7092.52 3735.23 -3433.97 -1 945.38 0.13 0.13 -0.03 02-DEC-96 MWD 8625.00 38.79 209.06 188.00 7239.40 3846.63 -3536.59 -2002.31 0.18 0.18 0.04 03-DEC-96 MWD 8814.00 37.97 209.43 189.00 7387.56 3957.88 -3638.98 -2059.63 0.45 -0.43 0.20 __ m SURVEYCALCULATION AND FIELD W~clKSHEET Job No. 0450-81687 Sidetrack No. P~, 4 of 5 Company UNOCAL Rig Contractor & No. Nabors Alaska Drill - Rig: #156 Field GRANITE POINT Well Name & No. GRANITE POINT PLATFORM/GP54 survey Section Name Definitive Survey BHI Rep. MILLER, SUTHERLAND I iiii ii ! i ii ~ ,,~' ~' ' WELL DATA ,,, Target TVD (FT) w Target Coord. N/S Slot Coord. N/S -2415.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 ssF1 Target Description Target Coord. EjW Slot Coord. E/W 1297.00 Magn. Declination 22.220 Calculation Method MINIMUM CURVATURE Target Direction (DO) Buil~Walk\DL per: 100ft[~ 30mr'l 10m~ Vert. Seo. Azim. 190.69 Magn. to Map Corr. 22,220 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment m,,ype, ~y'z) (DO) (DO) (FT) (FT) (F'r) (FT) (Per lOO ~ Drop (-) Left (-) 03'DEC-96 MWD 8,908.00 37.50 209.66 94.00 7461.90 4012.32 -3689.03 -2088.00 0.52 -0.50 0.24 ...... 03'DEc-96 MWD 9003.00 37.55 210.12 95.00 7537.24 4066.96 -3739.19 -2116.84 0.30 0.05 0.48 / 03-DEC-96 MWD 9189.00 38.29 210.56 186.00 7683.97 4174.61 -3837.84 -2174.58 0.42 0.40 0.24 ,, 04-DEC-96 MWD 9376.00 37.92 210.39 187.00 7831.12 4283.20 -3937.30 -2233.10 0.21 -0.20 -0.09 04-OEC''98- ~ MWD ' ~9.00 37.20- 21112~ .... 93.~-'- ' ~90~ii~ ................ ~l~,,~'~"' -3985.98 .... ~'~i'~' ............ ~i~ ..................... '~.-~' ............ -'~19-~ 06'DEc-96 MWD 9927.00 39,72 212.35 458.00 8263.45 4602.09 -4227.99 -2412.35 0.57 0.55 0.24 06-DEC-96 MWD 10025.00 40.68 211.68 98.00 8338.31 4660.98 -4281.56 -2445.97 1.01 0.98 -0.48 06-DEC-96 MWD 10213.00 42.81 210.68 188.00 8478.59 4778.04 -4388.40 -2511.11 1.20 1.14 -0.53 ..... 07-DEC-96 MWD 10305.00 43.77 210.79 92.00 8545.56 4637.26 -4442.57 -2543.45 1.05 1.04 -0.10 07-DEC'96 MWD 10398.00 43.78 210.29 93.00 8612.71 4897.78 -4497.98 -2576.14 0.37 0.01 -0.54 _, 07-DEC-96 MWD 10491.00 43.54 209.38 93.00 8679.99 4958.43 -4553.68 -2608.08 0.72 -0.26 -0.98 07-DEC-96 MWD 10583,00 44.15 208.19 92.00 8746.35 5019.01 -4609.63 -2638.76 1.11 0.68 -1.29 --,, 07-DEC-98 MWD 10676.00 44.77 206.54 93.00 8812.73 5081,41 -4667.38 -2668.70 1.41 0.67 -1.77 07-DEC-96 MWD 10769.00 45.37 205.45 93.00 6878.41 5144.91 -4726.56 -2697.55 1.05 0.65 -1.17 07-DEC-96 MWD 10863.00 45.99 204.83 94.00 8944.08 5210.03 -4787.44 -2726.12 0.81 0.66 -0.56 08-DEC-98 MWD 10957.00 46.80 202.46 94.00 9008.92 5276.36 -4849.78 -2763.42 2.00 0.86 -2.50 09-DEC-96 MWD 11048.00 45.59 201.30 91.00 9071.91 5340.78 -4910.71 -2777.91 1.63 -1.33 -1.30 ,09-DEC-96 MWD 11142.00 43.51 202.38 94.00 9138.89 5405.47 -4971.92 -2802.43 2.35 -2.21 1.15 i 09-DEC-96 MWD 11238.00 42.36 203.14 94.00 9207.71 5468.09 -5030.97 -2827.19 1.34 -1.22 0.81 09-DEC-96 MWD 11330.00 41,98 202,80 94.00 9277.38 5529.75 -508g.07 -2851.82 0.47 -0.40 -0.38 10-DEC-96 MWD 11425.00 41.32 202.39 95.00 9348.37 5591.52 -5147.36 -2876.08 0.75 -0.69 -0.43 10-DEC-98 MWD 11467.00 41.67 201.37 42.00 9379.83 5618.82 -5173.18 -2886.45 1.81 0.63 -2.43 __ ,, 10-DEC'96 MWD 11516.00 41.67 199.46 49.00 9416.43 5650.93 -5203.71 -2897.82 2.56 0.00 -3.68 10-DEC-98 I~/VD 11557.00 42.21 199.13 41.00 9446.93 5678.02 -5229.57 -2906.88 1.44 1.32 -0.85 i i -- '~ - SURVEY CALCULATION AND FIELD W"'RKSHEET ~o~ No. 0450-81687 Sidetrack No. P~, 5 of 5 Company UNOCAL Rig Contractor & No. Nabors Alaska Drlg - Rig: #156 Field GRANITE POINT Well Name & No. GRANITE POINT PLATFORM/GP54 Survey Section Name Definitive Survey BHI Rep. MILLER, SUTHERLAND , WELL DATA Target 'I'VD . .. (FT) , Target Coord. N/S Slot Coord. N/S -2415.00 Grid Correction 0.000 Depthe Measured From: RKB ~ MSL L~ ss~ Target Description Target Coord. E/W Slot Co°rd. E/Y~ 1297.00 Magn. Declination 22.220 Calculation Method MINIMUM CURVATURE Target Direction (DO) Buil~Walk\DL per: lOOff[~ 30m~ 1Omi-1 Vert. Sec. Azim. 190.69 Magn. to Map Corr. 22.220 Map North to: OTHER ........ SURVEY DATA "' Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type ~=~ (Dm ~X~ (F~ ~=~ (F~ (F-r) (Per ~00 FT) Drop (-) Left (-) 10-DEC-96 MWD 11611.00 43.92 199.27 54.00 9486.38 5714.48 -5264.39 -2919.00 3.17 3.17 0.26 ..... 11-DEC-96 MWD 11704.00 49.14 199.17 93.00 9550.34 5781.21 -5328.10 -2941.21 5.61 5.61 -0.11 / , ,, 11-DEC-96 MWD 11739.00 50.81 198.39 35.00 9572.85 5807.74 -5353.47 -2949.84 5.07 4.77 -2.23 ,. ...... 11 -DEc-96 MWD 11944.00 56.04 196.79 53.00 9695.46 5970.79 -5510.11 -2999.05 2.84 2.79 -0.60 ...... , , ................................................. ~ ....................................................... ,, ...... _ ,,, ,_ .... __ ' SURVEY CALCULATION AND FIELD Wr RKSHEET ~ Job No. 0450-81687 Sidetrack No. I Ps,'- 1 of 3 Company UNOCAL Rig Contract,.,, ~. No. Nabors Alaska Drlg - Rig: #156 Field GRANITE POINT ~. Well Name & No. GRANITE POINT PLATFORM/GP54 Survey Section Name Definitive Survey BHI Rep. MARK MILLER WELL DATA Target TVD (FT) ~ Target Coord. N/S Slot Coord. N/S -2415.00 Grid Correction 0.000 Depths Measured From: RKB ~-I MSL Q SS[- Target Description Target Coord. E/W ~, Slot Coord. EJW 1297.00 Magn. Declination 22.220 Calculation Method MINIMUM CURVATURE Target Direction {oo) BuiI~Walk\DL per: lOOft[~ 30m~ lOmQ Vert. Sec. Azim. 190.69 Magn. to Map Corr. 22.220 Map North to: OTHER ....... SURVEY DATA ...... Survey Survey Incl. Hole Course Vertical Total Coordinate BUild'i~;i;- ........ Wall< Rate Date Tool Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL (FT) (DD) {DD) (F'i~ (Er) {IT) (F'r) (Per ~00 FT) Drop (-) Left (-) MWD 11236.00 42.36 203.14 9207.71 5468.76 -5030.98 -2827.19 TIE IN POINT 16-DEC-96 MWD 11289.00 40.05 200,45 53.00 9247.58 5502.34 -5063.38 -2840.17 5.49 -4.36 -5.08 16-DEC-96 MWD 11361.00 40.59 198.59 72.00 9302.48 5548.38 -5107,29 -2855.73 1.83 0.75 -2.58 17-DEC-96 MWD 11456.00 42.85 193.81 95.00 9373.40 5611.27 -5167.98 -2873.30 4.11 2.38 -5.03 17-DEC-96 MWD 11550.00 47.11 192.06 94.00 9439.88 5677.64 -5232.72 -2888.13 4.72 4.53 -1.86 17-DEC-96 MWD 11625.00 50.97 193.84 75.00 9489.04 5734.22 -5287.90 -2900.84 5.45 5.15 2.37 17-DEC-96 MWD 11675.00 54.28 195.54 50.00 9519.39 5773.85 -5326.32 -2910.93 7.15 6.62 3.40 ,, 17-DEC-96 MWD 11737.00 56.50 197.10 62.00 9554.60 5824.62 -5375.29 -2925.28 4.14 3.58 2.52 ...... 17-DEC-96 MWD 11829,00 56.07 196.28 92.00 9604.33 5901.60 -5449.43 -2947.50 1.86 1.71 -0.89 18-DEC-96 MWD 11921.00 58.28 196.45 92.00 9652.84 5979.39 -5524.43 -2969.53 0.28 0.23 0.18 18-DEC-96 MWD 11984.00 59.93 197.11 63.00 9685.19 6033.14 -5576.19 -2985.14 2.77 2.62 1.05 28-DEC-96 MWD 12029.00 60.60 196.22 45.00 9707.51 6072.00 -5613.62 -2996.34 2.27 1.49 -1.98 28-DEC-96 MWD 12059.00 64.00 196.52 30.00 9721.45 6098.43 -5639.10 -3(X)3.83 11.37 11.33 1.00 · 28-DEC-96 MWD 12092.00 68.50 195.30 33.00 9734.74 6128.50 -5668.14 -3012.10 14.05 13.64 -3.70 ,'. 29--DEC-.96 MWD 12144.00 74.06 191.68 52.00 9751.43 6177.67 -5716.01 -3023.56 12.56 10,69 -6.96 29-DEC-96 MWD 12178.00 75.24 191.14 34.00 9760.43 6210.45 -5748.15 -3030.04 3.79 3.47 -1.59 30-DEC-96 MWD 12236.00 77.60 191.87 56.00 9774.04 6266.82 -5803.39 -3041.29 4.25 4.07 1.26 31-DEC-96 MWD 12256.00 79.00 192.96 20.00 9778.10 6286.39 -5822.52 -,,-,-,-,-,-,-,-,-~5.50 8.80 7.00 5.45 01-JAN-97 MWD 12354.00 80.60 192.24 98.00 9795.45 6382.79 -5916.64 -3066.54 1.79 1.63 -0.73 02-JAN-97 MWD 12444.00 79.00 191.37 90.00 9811,39 6471.34 -6003.34 -3084.66 2.02 -1.78 -0.97 03-JAN-97 MWD 125,39.00 80.00 190.70 95.00 9828.70 6564.75 -6095.02 -3102.54 1.26 1.05 -0.71 04-JAN-97 MWD 12611.00 78.58 189.82 72.00 9842.08 6635.49 -6164.64 -3115.14 2.31 -1.97 -1.22 04-JAN-97 MWD 12672.00 77.40 189.79 61.00 9854.78 6695.15 -6223.43 -3125.30 1.94 -1.93 -0.05 06-JAN-97 MWD 12749.00 77.31 190.10 77.00 9871.63 6770.27 -6297.43 -3138.27 0.41 -0.12 0.40 '~ " SURVEY CALCULATION AND FIELD W/"~KSHEET Job No. 0450-81687 Sidetrack No. 1 Pe' 2 of 3 Company UNOCAL Rig Contractor & No. Nabors Alaska Drlg- Rig: #156 Field GRANITE POINT F,_-~) Well Name & No. GRANITE POINT PLATFORM/CPS4 Survey Section Name Definitive Survey BHI Rep. MARK MILLER . ,, WELL DATA Target TVD (FT) ~ Target Coord. N/S Slot Coord. N/S -2415.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SS["] Target Description Target Coord. E/W Slot Coord. EAN 1297.00 Magn. Declination 22.220 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build~Walk\DL per: lOOft[~ 30m~ lOm~ Vert. Sec. Azim. 190.69 Magn. to Map Corr. 22.220 Map North to: OTHER SURVEY DATA Total Coordinate Build Rate Walk Rate Survey Survey Incl. Hole Course Vertical "' Build (+) Right (+) Comment Date Tool Depth Angle Direction Length TVD Section N'(+)/'S(.) E(+)"/W(.) DL Type (FT) (DD) (DD) (FT) (FT) (FT) (Fl') (Per 100 ET) Drop (-) Left (-) 06-JAN'97 MWD 12809.00 77.35 189.88 60.00 9884.79 6828,81 -6355.08 -3148.43 0.36 0.07 -0,37 06-JAN-97 MWD 12869.00 76.68 189.54 60.00 9898.33 6887.25 -6412.70 -3158.29 1.40 -1.28 ~.57 r~ 06--JAN'97 MWD 12909.00 77.22 189.95 40.00 9907.39 6926.21 '6451.10 '3164.88 1 .89 1.60 1 .03 06--JAN'97 MWD 12949.00 77.47 189.69 40.00 9916.1 6 6965.23 --6489.55 -3171 .54 0.89 0.62 -0.65 07'JAN'97 MWD 13002.00 76.90 189.36 53.00 9927.91 7016.90 --6540.52 -3180.09 I .24 '1 .08 -0.62 07--JAN'97 MWD 13049.00 76.33 189.28 47.00 9938.79 7062.61 -6585.64 '3187.50 I .22 '1 .21 -0.17 08-JAN'97 MWD 13080.00 76.26 I 89.11 31 .00 9946.1 4 7092.72 '6615.37 '3192.31 0.58 --0.23 -0.55 08'JAN'97 MWD 13129.00 78.04 1 89.02 49.00 9957.03 7140.47 '6662.54 '3199.83 3.64 3.63 -0.18 10--JAN'97 MWD 13170.00 78.71 188.42 41 .00 9965.29 7180.60 '6702.24 '3205.92 2.17 1 .63 '1.46 1 0--JAN'97 MWD 13231 .00 78.05 189.68 61 .00 9977.58 7240.33 -6761.24 '321 5.32 2.29 '1 .08 2.07 10'JAN'97 MWD 13253.00 78.04 1 89,79 22.00 9982.1 4 7261 ,85 -6782,45 '321 8,96 0.49 -0.05 0.50 I 1--JAN'97 MWD 13349.00 77.54 190.54 96.00 10002.44 7355.67 --6874.81 '3235.52 0.92 -0.52 0.78 13--JAN'97 MWD 1 3390.00 78.20 190.99 41 .00 10011 .06 7395.75 -6914.19 '3243.00 I .93 I .61 1.10 13--JAN'97 MWD 1 3451 .00 78.1 3 1 90.76 61 .00 10023.57 7455.46 -6972.82 '3254.27 0.39 -0,11 -0.38 13--JAN'97 MWD 1 3498.00 78.11 1 90.88 47.00 10033.25 7501 .45 '7017.99 '3262.90 0,25 -0.04 0.26 14--JAN'97 MWD 13544.00 78.30 190.73 46,00 10042.65 7546.48 '7062.23 -3271 .34 0.52 0,41 -0,33 i 4--JAN'97 MWD 1 3590.00 79,46 1 91 .33 46.00 10051 ,52 7591 .61 '7106.53 '3279.98 2,83 2.52 1 .30 ...... 14--JAN'97 MWD 1 3620.00 81 .70 1 91 .59 30.00 10056.43 7621 .20 '7135.53 '3285.86 7.52 7.47 0.87 15--JAN'97 MWD 13677.00 82.89 192.04 57.00 10064.07 7677.68 '7190.82 -3297.43 2.23 2.09 0.79 1 5--JAN'97 MWD 1 3798.00 79.97 I 92.44 29.00 10068.39 7706.34 '7218.84 '3303.50 I 0.16 '10.07 1.38 I 6--JAN'97 MWD 1 3741 .00 76.70 194.86 35.00 10075.47 7740.56 '7252.14 '3311 .59 I I .54 --9.34 6.91 16--JAN'97 MWD 1 381 5.00 75.51 197.07 74.00 10093,24 7812.09 '7321 .20 '3331 .34 3.32 '1 .61 2.99 17--JAN'97 MWD 13855.00 73.44 195,96 40.00 101 03.95 7850,43 '7358.15 '3342.30 5.82 '5.17 '2.78 i8--JAN'97 MWD 13900.00 71.07 196.09 45.00 10117.66 7893.10 '7399.34 '3354.13 5.27 '5.27 0.29 ~ SURVEY CALCULATION AND FIELD W 3KSHEET Job No. 0450-81687 Sidetrack No. 1 P, 3 of 3 Company UNOCAL Rig Contractor & No. Nabors Alaska Dr!g - Rig!, ,~,!56 Field GRANITE POINT FIELD Wall Name & No, GRANITE POINT PLATFORM/GP54 Survey Section Name Definitive Survey BHI Rep. MARK MILLER ~r~~ wE ................ D--ATA I iii I I i i i ! i i iii ii i iiii LL ,, Target TVD (F~ ~ Target Coord. N/S Slot Coord. N/S -2415.00 Grid Correction 0.000 Depths Measured From: RKB ~1 MSL[~ SS[~ Target Description Target Coord. E/W Slot Coord. E/W 1297.00 Magn. Declination 22.220 Calculation Method MINIMUM CURVATURE Target Direction {DO) Builc~Walk\DL per: 100ft~ 30mj-J 10m ~ Vert. Sec. Azim. 190.69 Magn. to Map Corr. 22.220 Map North to: OTHER I ii SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-)' E(+) / W(-) DL Build (+) Right (+) Comment Type (F~ (1313) (DO) (FI) ~ (IT), (F-r) (Per 100 FT) Drop (-) Left (-) 18-JAN-97 MWD 13980.00 69.12 195.91 80.00 10144.90 7967.99 -7471.64 -3374.86 2.45 -2.44 -0.23 ..... 19-JAN-97 MWD 14034.03 67.03 195.96 54.00 10165.06 8017.87 -7519.81 -3388.61 3.87 -3.87 0.09 19-JAN-97 MWD 14086.00 65.00 195.90 52.00 10186.20 8065.18 -7565.49 -3401.65 3.91 -3.90 -0.12 Projected Data - NO SURVEY . , _, , , _, _. UNOCAL Structure: GRANITE: POINT Platform Well: GP54 Field : Granite Paint Field Location : Cook InleT, Alaska 600 1200 1800 240O 3000 3600 4200 540O 60~O 66O0 7200 78OO 84OO 900O 9B00 10200 1O8OO J L 26 Conductor J L ~3-VB Cos;ng 9 5/8 Casing UNOCALe <- West (feet) 3600 3000 2400 1800 1200 600 0 600 f II I I I I I I I ; I I I I 600 600 1200 1800 2400 300O 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 I I '1 I I I I I I I I I I I I I i I I i I I i II i i ! I I I I 1 I I 600 0 600 1200 1800 2400 3000 ,:3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 Vertical Section (feet) -> Azimuth 208.24 with reference 0.00 N, 0.00 E from slot #4-2 Unocal Agricultural Products - · Diversified Business Group 909 West 9th Ave, Anchorage, AK 99501 Te/e: f907) 263-7889 Fax: (907) 263-7828 E-mail: epardac I @anchorage. unocal com UNOCAL® Debra Childers Geoscience C/erk DATA TRANSMITTAL 97-01 February 7, 1997 To: Laurie Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal GP 54 1 1 COMPLETION RECORD 1 1/25/97 GP 54 1 1 DRILLPIPE CONVEYED 1 1/20/97 PHASOR INDUCTION-SFL GP 54 1 1 DRILLPIPE CONVEYED 1 1/20/97 LITHOLOGY DENSITY LOG GP 54 ST1 I 1 FORMATION MWD LOG I 1/19/97 SRU 14-15 1 1 COMPLETION RECORD 2 1/16/97 SRU 14-15 1 1 COMPLETION RECORD 1 1/23/97 SRU 14-15 1 1 GAMMA RAY/CCL LOG 1 1/16/97 SRU 14-15 1 1 GAMMA RAY/CCL LOG 1 1/22/97 TBU D-14 RD 1 1 INJECTION PROFILE 1 1/19/97 TBU D-6 RD 1 1 INJECTION PROFILE 1 1/18/97 TBU G-21 1 1 THERMAL DECAY TIME LOG 1 1/14/97 --,. 0o% NOTE' SCHLUMBERGER HASN'T CHANGED THE DISTRIBUTION OF FILMS TO PREFOLDED SEPIAS YET. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Received by: Date: --' .... ~-";' !;i ,~, '~:~;:.'.5.' '"" ~' :..::i".';;'%i:!-':~:L ·.,; , .,_ ~ ,.~.1~- Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of Union Oil Company of California (Unocal) for exception to 20 AAC 25.055 to allow drilling the Granite Point No 54 development oil well. Unocal by letter dated January 31, 1996 has requested an exception to the provisions of 20 AAC 25.055(a)(3) and the well spacing requirements of Conservation Order No. 76 for the drilling of a development oil well to the Middle Kenai oil pool of the Granite Point Field located in the Cook Inlet Basin, Southcentral Alaska. The exception would allow Unocal to directionally drill the Granite Point No. 54 development oil well to a producing location that is closer than 500 feet from a section line. The proposed surface location is 2660' from the south line and 3991' from the east line of Section 13, T10N, R12W, Seward Meridian (SM) and the proposed bottom-hole location is 69' from the north line and 2594' from the east line of Section 26, T10N, R12W SM. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM February 20, 1996 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 am on March 7, 1996 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433 after February 20, 1996. If no protest is filed, the Commission will consider the issuance of the order without a hearing. if you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than March 1, 1996. erman Babcock ~ Commissioner Alaska Oil and Gas Conservation Commission Published February 6, 1996 AO-02614030 MEMORANDUM TO: David Joh~/'// Chairman ---"~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 9, 1997 THRU: Blair Wondzell, ,¢a2~ FILE NO: P. !. Supervisor FROM: John Spaulding~ ~,/k, SUBJECT: Petroleum lnsp.~' q~ ao91aied.doc BOPE Test Nabors 156 UNOCAL Granite Pt. Plat. GPP 54 Granite Point Field PTD 96-13 Thursday January 9~ 1997: I traveled to the Granite Point a UNOCAL platform to witness the BOPE test on Nabors rig 154. The test went quite well with I failure observed. The annular preventer passed the iow pressure test but failed the high pressure test. Marvin Rogers Nabors toolpusher had a new annular preventer coming out on the same helicopter that I left on. The annular will be repaired and a copy of the subsequent test will be faxed to the AOGCC within 24 hours. Summary: I witnessed the BOPE test Nabors rig 156, 1 failure, 3.5 hour test time. Attachments: ao91aied X Unclassified Confidential Confidential (Unclassified if document removed) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: ~ Drlg Contractor: NABORS Rig No. Operator: UNOCAL Well Name: C-¢ P ~ ,~ ~ Casing Size: 7" Set @ '/'!,994' Test: Initial Weekly X Other '/56 PTD Cf Rep.: Rig Rep.: Location: Sec. 96-'/3 DATE: '1/9/97 Rig Ph.# (907) 776.6656 Shane Hauck Marvin Rogers '/3 T. '/ON R. '/2W Merldlall Seward MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location yes Standing Order Posted yes Well Sign yes Drl. Rig ok Hazard Sec. yes FLOOR SAFETY VALVES: Upper Kelly / IBOP '/ Lower Kelly / IBOP '/ Ball Type Inside BOP Test Pressure 25015000 25015000 250/5000 '/ 250~5000 P/F P P P P BOP STACK: Quan. Annular Preventer '/ Pipe Rams Lower Pipe Rams '/ Blind Rams '/ Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Press. P/F 250/3,500 F* '/ 250/5,000 P 25O/5,0OO 250/5,000 P P '/ 250/5,000 P 2 250/5,000 P '/ 250/5,000 P CHOKE MANIFOLD: No. Valves '/3 No. Flanges 34 Manual Chokes '/ Hydraulic Chokes 2 Test Pressure 250/5000 250/5000 Functioned Functioned P/F P P ACCUMULATOR SYSTEM: N/A System Pressure 3000 I P Pressure After Closure 1600I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure allllllle$ ,38 sec. Trip Tank ok ok System Pressure Attained 2 IIIIIl#le$ 50 SeC. Pit Level Indicators ok ok Blind Switch Covers: Master:. '/ Remete: 2 Flow Indicator ok ok Nitgn. Btl's: '/900, 2000 Meth Gas Detector ok ok 2000, 2000 Psig. H2S Gas Detector ok ok Number of Failures: '/ ,TestTime: 3.5 Hours. Hllalllerel~lve$lesled '/9 Repair or Replacement of Failed Equipment will be made within '/ days. Notify the Inspector and follow with Written or Faxed verification to me ~ou~e oemm~ssie, em.,.: He. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: * The annular failed on the high pressure test, the element must be replaced and retested and written verification must follow. Please send to AOGCC Anchorage office Distribution: orig-Well File c- Oper./Rig c - Database c - Tdp Rpt File c -Inspector FI-021L (Rev.12/94) STATE WITNESS REQUIUEIIP YES X NO 24 HOUR NOTICE GIVER YES X NO Waived By: Witnessed By: AO9LAIED~XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh~ Chairman.'-~ THRU: Blair Wondzell, ~ P. I. Supervisor FROM Lou Grimaldi,¢'~ · h:~ Petroleum Inspector DATE: FILE NO' SUBJECT: November 24, 1996 AOJJKXDD.DOC BOP Test UNOCAL well #GP-54 Granite Point Platform Granite Point Field PTD #96-13 Sunday, November 24, 1996: I witnessed the initial BOP test on UNOCAL's Granite Point platform in the Granite Point Field. Nabors Alaska is utilizing the platforms rig to drill well #GP-54. The crew was still in the process of nippling up when I arrived but was ready shortly thereafter. We tested the Choke Manifold while the stack was getting its final assembly. All valves passed their test of 250/5000 psi. Later this evening the stack and remaining BOPE were tested with no failures observed. SUMMARY: I witnessed the initial BOP test on UNOCAL's Granite Point platform, well #GP-54. No failures observed. Test Time; Four hours. Attachments' AOJJKXDD.XLS cc: Dale Haines (UNOCAL Drilling, Anchorage) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Nabors Rig No. G.P PTD # UNOCAL Rep.: GP-54 Rig Rep.: Set @ Location: Sec. Weekly Other DATE: 11/24/96 96-13 Rig Ph.# 283-6657 Mike McCall Mike Williams 13 T. 1ON R. 12W Meridian Seward TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign P Dd. Rig P Hazard Sec. N/A Quan. 1 Test Press. P/F 250/3500 . P P 1 250/5,000 1 250/5,000 P 1 250/5,000 P 1 250/5,000 P 2 250/5,000 P 1 250/5,000 P N/A 250/5, 000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F N/A 250/5,000 P N/A 250/5,000 P 1 250/5,000 P 1 250/5,000 P CHOKE MANIFOLD: No. Valves 16 I No. Flanges Manual Chokes Hydraulic Chokes 2 Test Pressure P/F 250/5,000 P 38 250/5,000 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 4 Bottles 1600 average psi 3,100 I P 1,700 P minutes 29 sec. minutes 33 sec. P Remote: P Psig. ~, ~.~,;, TEST RESULTS Number of Failures: 0 ,Test Time: 4.0 .,)Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good test. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R Grimaldi FI-021L (Rev. 12/94) AOJJKXDD.XLS STATE OF ALASKA 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: x Pull tubing: Variance: Perforate: Other: X 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 114.75 RKB (MLLW) feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Granite Point Field 4. Location of well at surface 8. Well number 2860' FSL, 3991' FEL, Sec. 13, T1 ON, R12W, SM 54 ADL 18761/374045 At top of productive interval 9. Permit number 2715' FNL, 1732' FEL, Sec. 23, T10N, R12W, SM 96-0013 At effective depth 10. APl number 50- 733-20470 At total depth 11. Field/Pool 442' FNL, 2275' FEL, Sec 26, T10N, R12W Granite Point Field/Middle Kenai "C" Sands 12. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 242' 26" Driven 294' RKB Surface R E C E IV E D LJner t~OV 2 1 199[; Perforation depth: measured Alaska 0il & Gas Cons. 0o.mmission true vertical Anchorage Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. Attachements Description summary of proposal: x Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: November 2t, 1996 t6. If proposal well verbally approved: Oil: x Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Dale Haines ~_____~_ ~ ~ ~ Title: Drilling Manager Date: 11/20/96 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witneSSplug integrity BOP Test Location clearance~ Mechanical Integrity Test Subsequent form required lO- Original Signed By David W. Johnston Approved by order of the Commissioner ..... Form 10-403 Rev 06/15/88 Returned SUBMIT IN TRIP I Unocal North Americar Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region November 20, 1995 AOGCC Attn: Mr. Blair Wondzell 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: ORIGINAL This letter is in reference to the conversation Dan Williamson had with yourself on 11/19/96. UNOCAL is requesting a variance from Article 1 20 AAC25.050 Deviation--concerning survey frequency. AOGCC Regulation Article 1 20 AAC25.050 requires surveys to be taken at least 100 ft apart while drilling Granite Point #54 (Permit # 96-13). Since the well will be vertical down to 1,200 ft (MD), we like to begin surveying at the conductor shoe, 294 ft (MD), and then survey 200 ft apart from 294 ft (MD) to 1,200 ft (MD). We would then survey every 100 ft during the build section--I,200 ft (MD) to 2,700 ft (MD). We are then requesting a variance; so that we can survey at least 500 ft apart during the first tangent section. The first tangent section will start at 2,700 ft (MD) and will end at 10,449 ft (MD). We would then survey every 100 ft during the second build section--10,449 ft (MD) to 12,455 ft (MD). In the final tangent section from 12,455 ft (MD) to 15,120 ft (MD), we are also a requesting a variance to be able to survey at least 500 ft. The proposals listed above are in reference to the Proposed AOGCC Regulations (see page 29 Dated 10/4/96). We thank you for the opportunity to submit this proposal and will be happy to answer any of your questions. Please contact Dan Williamson ~ 263-7677 if further details are required. Sincerely, REC£!YED NOV ~ ~ ~l ~ska 0il &Anch0rageGas 0ohs. 60.mm~ssl0n Dale Haines Drilling Manager mwd NOV-19-96 TUE 04:36 PM Y, UI/UI Unocal Drilling Date: ...Tuesday._~. November 19~ 1996,,, Number of pages including cover sheet: I To: AOGCC Blair Wondz~ll Phone: 279-1433 Fax p_hpn~.: 276-7542 CC: Dan Williamson ... Phon~: 907-263-7677 phone: 907-263-7884 REMARKS: [] Urgeat [] For yourr~view ['3 RepIy ASAP Phone .di_s~usS.10n c. oncer.n..in9 of cementing_of G_ranite P_oint 5.4 [] Please comment After our phone conversation of today I reviewed the subject well in more depth, We have 26" conductor driven to 294', 13 3/8" Surface Casing will be at 1100' and the 9 5/8" Intermediate Casing will be at 3500'. i had forgotten about the driven conductor and therefore used the wrong terminology in referring to the 13 3/8" and 9 5/8" casing strings as conductor and surface casing respectfully. We will send over a proposal for the variance to the well bore survey requirement tomorrow. Thanks for your cooperation, Regards Dan Williamson RECEIVED NOV 1 9 1996 Naska 011 & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended weil: Alter casing: Repair weq: Plugging: Time extension: Stimulate: Change approved Program: x Pull tubing: Variance: Perforate: Other: , 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: x 114.75 RKB (MLLW) feet 3. Address Exploratory: 7'. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Granite Point Fiekl 4. Location of well at surface 8. Well number 2860' FSL, 3991' FEL, Sec. 13, T10N, R12W, SM 54ADL 18761/374045 ,, At top of productive interval 9. Permit number 2715' FNL, 1732' FEL, Sec. 23, T10N, R12W, SM 96.0013 At effective depth 10. APl number 50- 733-20470 At total depth 1 '1. Field/Pool 442' FNL, 2275' FEL, Sec 26, T10N, R12VV Granite Point Fiekt/Middle Kenai "C" Sands 12. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk(measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate See attached Production Liner Perforation depth: measured i::lV true vertical O : Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) A,3,:,,,.-'~ c,. 13. Attachements Description summary of proposal: x Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: November 13, 1996 16. If proposal well verbally approved: Oil: x Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sign,: Dale Haines ? ~ ~ ~ l(--~,. Title: Drilling Manager Date: 10/4/* FOR COMMISSION USE ONLY C ond it ions of approval: Notify Commission so re pre se nta, ive may witnessIIAP" royal No. Plug integrity BOP Test ~ Location clearance ..._~?~::) '"" Mechanical Integrity Test Subsequent form required 10- ~ O '7 Original,:::;,~.',-, David W. Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 Approved Copy SUBMIT IN TRIPLICATE Returned STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Unocal has changed the directional program of Granite Point #54. Please see the attachments that shows the new directional program. In addition, the 7" & 5" casing measured depths have changed as follows: 7" Shoe Old Measured Depth 12,684' New Measured Depth 12,104' Old True Vertical Depth 9,765' New True Vertical Depth 9745' 5" Shoe Old Measured Depth 15,477' New Measured Depth 15,247' Old True Vertical Depth 10,212' New True Vedical Depth 10,385' If you have questions, please call Mitch Damm @ 907-263-7679. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 265000 270000 274005 255824 260000 ...... I 25 : ,.~ ~ / / ~ o ~ooo~o~o~ooo j ~ / ', Feet [ - / i UNOCAL ~ ........... /_ . AD)2 1~61 ' GRANITE~ .... ' ....................... ADL :' ~ ....................................... GRANITE POINT FIELD -:3 4045 Proposed Well ~54,' ~1'12°°° ~ FEET I + ~oo- + ~ ~ 26 ' 25 ]85 I ~ ~ ~ 274005 · 2535000 2,.534383 255824 260000 2 UNOCAL( ) RKB = 115' GRANITE POINT PLATFORM WELL tt 54 GRASS ROOTS PROPOSED COMPLETION CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 33" Outside conductor 26" Inside Conductor 13-3/8 68 K-55 BTC 9-5/8 47 L-80 BTC 7" 29 L-80 ' KC-BTC 5" 15 L-80 SC-KC-BTC NOTE: 4-1/2" = slotted liner 3-1/2" L-80 SC BTC 12,000 229 294 1,100 3,500 12,104 15,274 12,030 NO. ITEM JEWELRY DETAIL 1 SSSV 2 Camco Gas Lift Mandrels 3 Sliding Sleeve 4 7" Packer 5 "X" Profile Nipple 6 Wireline Re-entry Guide DEPTH 300 As Required 11,975 TOL ~ 12,00' C-5 SAND '~ TI) = 15,274' MAX HOLE ANGLE = 80° 0 :kDRILLINGKS CHEMATICSGP\GPP\GP54 -PR2.D OC PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 12,120 12,274 C-5 6 TCP REVISED: 10/07/96 DRAWN BY: MWD Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL G. Russell Schmidt Drilling Manager Wednesday, March 06, 1996 Mr. David Johnston AOGCC 3001 Porcupine Drive Anchorage, AK 99519 Dear Mr. Johnston: This letter is concerning the conversation Mitchell Damm had with Blair Wondzell on March 6, 1996. Unocal would like to inform you of the changes we have made in our directional and casing programs for Granite Point 52, 53 & 54. The modications in the directional plans have changed the total depths slightly in each wells. We are also changing the 13-3/8" and 9-5/8" casings depths in GP #52 slightly. The major change is in which slots the wells will be drilled out of. ORIGINAL PLAN 13-3/8" shoe 9-5/8" shoe 7" shoe TD Slot # GP #52 900' MD 2,700' MD 11,395' MD 14,357' MD 6 GP #53 1100' MD 3,500' MD 12,800' MD 15,700' MD 8 GP #54 1100' MD 3,500' MD 12,684' MD 15,477' MD 9 REVISED PLAN GP #52 1100' MD 3,450' MD 11,400' MD 13,793' MD 4 GP #53 1100' MD 3,500' MD 12,950' MD 15,859' MD 3 GP #54 1100' MD 3,550' MD 12,625' MD 14,508' MD 2 If you require additional information, please contact myself or Mitchell Damm. G. Russell Schmidt Drilling Manager MWD/leg ALASKA OIL GAS CONSERYATION COMMISSION TONY.KNOWLE$, GOVERNOR · . 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 22, 1996 G. Russell Schmidt, Ddiling Manager Union Oil Company of Califomia (Unocal) P O BoX 196247 Anchorage, AK 99519-6247 Re: Granite Point Field 54 ADL 18761 Union Oil Company of California (Unocal) Permit No 96-013 Surf Loc 2860'FSL, 3991'FEL, Sec. 13, T10N, R12W, SM Btmhole Loc 69'FNL, 2594'FEL, Sec. 26, T10N, R12W, SM Dear Mr. Schmidt: Enclosed is the approved application for permit to ddil 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 ddiling operations until all other required permitting determinations are made. Your application for a waiver of the diverter requirements of 20 AAC 25.035 on the 26" conductor casing strings is approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a re~ of the Commission may witness the test. Notice may be given by contactin 279-1433. David W. Job iston Chairman BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o end STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Re-Entry BI Deepen Lr~ Service r-] Development Gas BI Single Zone BI Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (Unocal) 114.75 RKB feet Granite Point Field 3. Address 6. Property Designation Middle Kenai "C" Sands P.O. Box 196247, Anchorage, AK 99519 ADL 18761 '~,. Location of well at surface 7. Unit or property name 11.Type Bond (SEE 20 ACC 25.025) 2,860' FSL, 3,991' FEL, Sec 13, TION, R12W, SM Granite Point Field AK Statewide Oil & Gas Bond At top of productive interval 12,155' 8. Well number Number 2,396' FNL, 1,493' FEL, Sec 23, T10N, R12W 54 ADL-18761 U62 - 9269 At total depth 15,517' : 9. Approximate spud date Amount 69' FNL, 2,594' FEL, Sec 26, T10N, R12W 2/17/95 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line I 50 feet See Clearance Reports feet 5089 15,477'/10,212' feet 16. To be completed for deviated wells 17. Anticipated Pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 3,600 feet Maximum hole angle 83.5 Maximum surface psig At total depth ("FVD) 2187 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) 17-1/2" 13-3/8" 68 K-55 BTC 1100 47 47 1100 1099 3056 ft3 12-114" 9-5~8" 47 L-80 BTC 3500 47 47 3500 3499 4384 8-1/2" 7" 29 L-80 BTC 12,684 47 47 12684 9765 520 ft3 6" 4-1/2" 12.6 L-80 SC-BTC 3033 12484' 9634' 15,477 10212 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 294' 26" Driven 294' RKB ,'° ~ Intermediate Production Liner J~l~t 6 1 6' Perforation depth: measured See attached Na,t~ Oil & Gas Co~s, true vertical See attached 20. Attachments Filing fee ['~ Property plat [] BOP Sketch ~-] Diverter Sketch [~] Drilling program Drillin§ fluid program [] Time vs depth plot [~ Refraction analysis ['"] Seabed report BI 20 ^AC 25.050 requirements 21. I hereby ce¢~ tpa~4.he foregoi0~ i~tru~"~nd c~rrect tong. Ibc ~gls~.~cf my knowledge Commission Use Only ~'~' ..~,/¢.,_~ 50- ~,_,~' --. 2 ~ ~/"~,~ .,,~, "' 4;;~ ~'~ ~' for other requirements Condition~ of approva, Samples required E~ Yes ~ No Mud log requi~ci r-~ Yes .,~ No Hydrogen sulfidemeasures [] Yes ~'] No Directional surveyrequired -- ~ Yes ~ No Required working pressure for I~DPF_, , !~] 2M; BI 3M; Other: urlglrlat Signed~.,V [~ 5M; E~ 10M; [] 15M by the order of Approved by David W. J0hnst0rl Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re~ THE APPLICATION OF UNION ) OIL COMI'~ OF CALIFORNIA ) for an order granting ) an exception to spacing ) requirements of Title ) 20 AAC 25.055 to provide ) for the drilling of the ) Granite Point No. 54 ) development oil well. ) Conservation Order No. 371 Union Oil Company of Califomia Granite Point No. 54 February 21, 1996 IT APPEARING THAT: Union Oil Company of Califomia (Unocal) submitted an application dated January 31, 1996 requesting exception to 20 AAC 25.055(a)(3) to allow drilling the Granite Point State No. 54 development oil well to a producing location that is closer than 500 feet to a drilling umt boundary. 2. Notice of opportunity for public heating was published in the Anchorage Daily News on February 6, 1996 pursuant to 20 AAC 25.540. 3. No protests to the application were received. The Unocal Granite Point State No. 54 well as proposed will be a deviated hole drilled from a surface location 2860' from the south line and 3991' from the east line of Section 13, T10N, R12W, Seward Meridian (SM) to a bottom-hole location 69' from the north line and 2594' from the east line of Section 26, T10N, R12W SM. 2 Offset owner Mobil Oil Company has been duly notified. 3. An exception to 20 AAC 25.055(a)(3) is necessary to allow drilling of this well. CONCLUSION: Granting a spacing exception to allow drilling of the Unocal Granite Point No. 54 well as proposed will not result in waste nor jeopardize correlative fights. Conservation Order February 21, 1996 Page 2 NOW, TH-EREFORE, IT IS ORDERED: Unocal's application for exceptioh to 20 AAC 25.055 for the purpose of drilling the Granite Point No. 54 well is approved as proposed. DONE at Anchorage, Alaska and dated February 21, 1996. -~'\ ~ati ? ~,~}[ Alaska Oil and on Commission Tuckarman Babcock, (~ommissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for reheating. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for reheating is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). Memorandum State of Alaska Oil and Gas Conservation Commission To: Commission Fm: Sta~ ¢J~ Subj: Request for Diverter Variance -- ~' Unocal Granite Pt. Platform Wells 52,53 & 54 January 31, 1996 Unocal has requested a waiver of diverter requirements on the subject wells. They propose to drill the 17-1/2" hole through the 26" conductor with a flow nipple to approximately 900', set 13-3/8" surface casing at 900', then drill 12-1/4" hole from +/- 2700' to 3500' using a 13 5/8", 5000 psi. BOPE system. They state in their application letter that the fracture gradient anticipated at the surface and intermediate casing shoes are .90 and .85 psi/foot respectively and the rock is competent to shut in the well and circulate a kick rather than divert. The fracture gradients are based on recent leak off tests done in the Cook Inlet area and other Granite Point wells drilled recently. I reviewed 3 wells which offset the subject wells. There were no shallow gas kicks, abnormal pressure or lost circulation noted in the wells reviewed. There were several instances of stuck tools, however, fishing operations were successful and no other complications were noted. Regulation 20 AAC 25.035 (b) (3) and (c) (2) authorizes the Commission to waive diverter requirements if drilling experience in the near vicinity indicates a diverter system is not necessary. The same approach and similar arguments were the basis of the diverter variances granted on MGS Dillon wells 16 & 17 in April, 1994 and Granite Point Anna Wells 50, 51, and 52 in July, 1994. The proposal to drill the surface hole to 900' with a drilling nipple means there is no annular preventer to divert the well and returns go straight to the shakers and pits. For the hole sections from 900-3500', their permit application shows a 13-5/8" BOP system with a 3000 psi annular preventer. Unocal believes the diverter is not appropriate and would rather use positive control measures and shut in on kicks where the formation is competent. In summary, a review of AOGCC well histories on three wells in the vicinity of the 3 proposed wells indicated no shallow gas, kicks or lost circulation zones The section of hole drilled from the structural pipe to the conductor depth of 900' RKB will be done without any means to divert. Hole drilled from 900' RKB to total depth will be accomplished with BOP equipment. Recommendation: Absent shallow gas and other notable drilling problems in the vicinity of the well to be drilled, I recommend approval of the waiver of diverter requirements. If there are other circumstances which the Commission thinks would cause a need for diverter use, Unocal should be allowed to address those circumstances. Unocal Corporation Oil 8, Gas Operations 909 West 9th Avenue. P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL Kevin A. Tabler Land Manager Alaska Business Unit January 12, 1996 Mr. G. M. Moffit Mobil Exploration & Producing U.S. Inc. as Agent for Mobil Rocky Mountain Inc. 12450 Greenspoint Drive Houston, Texas 77060-1991 Cook Inlet Area State of Alaska Notice of Application Submittal to Drill Granite Point Platform Wells 53 & 54 Dear Mike: As you know, Union Oil Company of California, Operator of the Granite Point Field and Granite Point Platform, intends to drill the above referenced Wells and has submitted Permit to Drill applications to the Alaska Oil and Gas Conservation Commission. Pursuant to the provisions of 20 AAC 25.050 and 20 AAC 25.055, Mobil Exploration & Producing U. S. Inc. as Agent for Mobil Rocky Mountain Inc. is the only affected owner or operator having a leasehold or working interest ownership either directly or diagonally offsetting any quarter section upon which said drilling operations are proposed to be conducted. This letter constitutes formal written notice of our intent to drill Granite Point 53 & 54 wells, as required under said regulations. I am enclosing copies of the Permit to Drill applications for your reference. Also enclosed is a copy of a plat showing all of the wells within one-half mile of any portion of the new wells and a lease map showing current ownerships for the affected leases. As a working interest owner in these wells, you will receive an AFE for your participation, if you have not already done so. cc: AOGCC Ve7 truly yours, . i /? .... ~ ...... ":~ ~'' .... "~ · - in A. Tabler ,' ~"'~14t~ c ,~ ~ ',.. , ADL 17585 13070 ACI HBP · UNOCAL 25% MOBIL -7 ~-%- iF BRL~CE e~ANNA [5060 AC HBP := 1874- RA E P . MOBII~-75% 2sed AC 3-31-98 A'D L-~ ?___4~4_4_ _. UNOCA MOBIl L-25% -75% 256d) AC 3-3 -98 ADL- ~74045 2000 FEET i ' · + + VERIFICATION OF APPLICATION FOR SPACING EXCEPTION COOK INLET, ALASKA STATE OF ALASKA ADL # 374045 GRANITE POINT pLATFORM I, KEVIN A. TABLER, Land Manager, Union Oil Company of California, do hereby verify the following: I am acquainted with the application submitted for the drilling of the Granite Point Platform Well #53. I have reviewed the application submitted for the exception to 20 AAC 25.055 (3) (statewide spacing) and all facts therein are true. I have reviewed the plat attached to said application, and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this 12th day of January, 1996. K~A. Tabler Land Manager : . STATE OF ALASKA ) )SS ........ THIRD JUDICIAL DISTRICT ) SUBSCRIBED TO AND SWORN before me this 12th day of January, 1996. OFFICIAL SEAL State of Alaska NOTARY PUBLIC Roxanne M. Sinz My Commission Expires Auguet 1,1997 NOTARY PUBLIC IN AND FOR d' THE STATE OF ALASKA My Commission expires: ~7.//. ~q ~ VERIFICATION OF APPLICATION FOR SPACING EXCEPTION GRANITE POINT FIELD, COOK INLET, ALASKA STATE OF ALASKA ADL # 18761 GRANITE POINT PLATFORM I, KEVIN A. TABLER, Land Manager, Union Oil Company of California, do hereby verify the following: I am acquainted with the application submitted for the drilling of the Granite Point Field, #54 platform well. I have reviewed the application submitted for the exception to Rule 2, Conservation Order No. 76 and all facts therein are true. I have reviewed the plat attached to said application, and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this 12th day of January, 1996. KeM'n A. Tabler Land Manager STATE OF ALASKA ) )ss THIRD JUDICIAL DISTRICT ) S~SC~ED TO ~ SWO~ before me tbs 12th day of Janua~, 1996. NOTAI(Y pUBLIC IN AND THE STATE OF ALASKA My Commission expires: fi" /' J~ 7 Unocal Corporation '~ ' ~ l' Oil & Gas Operations 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL Kevin A. Tabler Land Manager Alaska Business Unit January 12, 1995 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 GRANITE POINT #$3 & #54 REQUEST FOR SPA CING EXCEPTION ADL 18 761 and ADL 3 74045 Dear Chairman Johnson: Union Oil Company of California (Unocal), as Operator of the Granite Point Field, requests your approval to drill Granite Point # 54, ADL 18761 and further requests Administrative Approval, pursuant to Rule 7, for a spacing exception to Rule 2, Conservation Order No. 76. In triplicate, is our application for Permit to Drill Granite Point #54 (form 10-401) pursuant to 20 AAC 25.005 and our check No. 011161 in the amount of $100.00 as required under 20 AAC 25.005 (c) (1). Also enclosed, is Verification of Application by the undersigned stating that applicant is acquainted with the facts. Granite Pt. #54 The specific location, interval and depth are as follows: 2480' FSL 1650' FEL Sec. 23, T10N-R12W, SM Top C-5 Producing Interval 60' FSL 2540' FEL Sec. 23, T10N-R12W, SM Bottom C-5 Producing Interval Also enclosed and submitted in triplicate is our application for Permit to Drill Granite Point #53, ADL 374045 (form 10-401) pursuant to 20 AAC 25.005 and our check No.o]]]42 in the amount of $100.00 as required under 20 AAC 25.005 (c) (1). Verification of Application by the undersigned stating that applicant is acquainted with the facts pursuant to 20 AAC 25.055 (b) is attached as part of this application. JAN ?._~ ~,5 It is requested that the Commision approve an exception to the statewide spacing regulation 20 AAC 25.055 (3) for the drilling of well Granite Point//53, ADL 374045 from the Granite Point Platform. Granite Pt.//53 The specific location, interval and depth are as follows: 1780' FSL 640' FWL Sec. 24, T10N-R12W, SM 60O' FNL 490' FWL Sec. 25, T10N-R12W, SM Please note that once production is established in well//53 (since we have entered Sec. 25- -ADL 374045), this lease will be held by production. All applicable provisions of 20 AAC 25.050 (Deviation) have been met for each application and each owner and all operators of governmental quarter sections directly or diagonally offsetting the section where the oil wells are located have been notified by registered mail pursuant to 20 AAC 25.055 (b). A copy of said notification is attached hereto. If you require additional information, please contact Roxanne Sinz at (907) 263-7623 or Mitch Damm, Drilling Department at (907) 263-7679. We appreciate your review and trust the enclosed is satisfactory. V7 truly yours, · -~Kevin A. Tabler Enclosures Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOr..AL G. Russell Schmidt Drilling Manager Thursday, January 11, 1996 Mr. David Johnston Commissioner Alaska O&G Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston: Please find the enclosed Applications for Permit to Drill (Form 10-401 ) for the Granite Point Platform wells #52, #53, #54. UNOCAL is planning to batch drill all three wells; we will be commence batch drilling operations on GP #52 in mid- February. (See enclosed Granite Pt. Time Line.) These three grass root wells are part of UNOCAL's continued development drilling program on the Granite Point Platform. UNOCAL is requesting that the AOGCC waive the diverter system requirements on the 26" conductor casing strings for all three grass root wells. This waiver is similar to our April & July 1993 request for the Dillon Platform wells #16. #17, and #18 and the Anna Platform wells #50, #51, #52. The AOGCC approved UNOCAL's request to waive the diverter system requirements for both the Anna and Dillon wells. For the Granite Point Platform drilling program, UNOCAL is intending to drill out of the 26" conductor casing to approximately 900' to 1,100' utilizing a flow nipple; run and cement 13-3/8" surface casing; and will then install a 13-5/8" 5,000 psi BOPE stack on the 13-3/8" surface casing. Mr. David Johnston Page 2 January 11, 1996 UNOCAL has selected the casing points of the 13-3/8" ( 900' to 1,100') and 9- 5/8" (2,700' to 3,500' ) to be in competent formation. From offset development wells and log data, no gas bearing zones are evident above the proposed 13- 318" casing setting points. The anticipated formation fracture gradients at these shoe depths are 0.9 psi/ft and 0.85 psi/ft respectively. UNOCAL's recent experience in the Granite Point Field and in the Cook Inlet in general has demonstrated that the true fracture gradients range from 0.75 to 0.94 psi/ft; design assumptions are reasonable based on this data (See attached Granite Point Fracture Gradient Data and Graph.) While drilling below the 26' conductor casing, the maximum hydrostatic pressures (during as gas kick scenario) will not exceed the fracture pressures at the individual casing shoes. Since the casing shoes are structurally competent and the setting depths are in competent formations, UNOCAL believes the casing designs and drilling operations are safe and prudent designs. The completion design for Granite Point Platform wells #52, #53, #54 is to set 4- 1/2" slotted liner throughout the Tyonek C-5 sand. All three wells will then be completed with 2-7/8" gas lift completions. An outline and diagram of UNOCAL drilling and completion plans are included in each Application for Permit to Drill. For the Granite Point 53 and Granite Point 54 Wells, UNOCAL is requesting an exception to Rule No. 2 of Conservation Order No. 76 and 20 AAC 25.055. Drilling Units and Well Spacing. The open pay section in Granite Point 53 will cross the lease line between ADL 18761 and ADL 374045; and Granite Point 54's pay section will be drilled less than 500 ft from the ADL 18761 lease line. UNOCAL would like to inform the AOGCC that all three wells will be intentionally - -deviated; and we are aware of'the 15 day public comment period. UNOCAL would like to thank Robert P. Crandall for his help and cooperation with the spacing and Conservation Order issues. If any questions arise while the Permit to Drills are being reviewed, please contact the drilling engineer who is assigned to this project--Mitchell Damm (263-7679). Thank you for your time and cooperation. Enclosure /mwd UNOCAL _ GRANITE POINT PLATFORM WELL # 54 GRASS ROOTS PROPOSED COMPLETION RKB= 115' CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP 33" Outside conductor 26" Inside Conductor 13-3/8 68 K-55 9-5/8 47 L-80 7" 29 L-80 4-1/2" 12.6 L-80 BTC BTC BTC SC-BTC NOTE: 4-1/2"= slotted liner 2-7/8" 6.4 N-80 SC BTC BOTTOM 0 229 0 294 0 1,100 0 3,500 0 12,684 12,484 15,477 0 12,520 JEWELRY DETAIL NO. ITEM 1 SSSV 2 Camco Gas Lit~ Mandrels 3 Sliding Sleeve 4 7" Packer 5 "X" Profile Nipple 6 Wireline Re-entry Guide DEPTH 3O0 As Required 12,410 12,440 12,490 12,520 TOL ~ 12,684' PERFORATION DATA TOP BTM ZONE SPF. DATE COMMENTS SLOTTED LINER TYONEK C-5 SAND TD = 15,517' MAX HOLE ANGLE = 8:;° O:~DRILLING\S CHEMATIC\GP\GPP\GP54-PRO.DOC REVISED: 11/27/95 DRAWN BY: MWD Granite Pt. 54 (New Well, South East Tyonek C-5) AFE 761102 TimeEst. Cum Time Preliminary Procedure: 0.5 0.5 1 1.5 1 2.5 0.5 3 2.5 5.5 1,5 7 0.5 7.5 14.5 22 I MIRU R156, Leg #4, Conductor #?, Install 26-30" flow riser. 2 Drill 17-1/2" hole to 13-3/8" csg point of approx. 1100'. 3 Run and cement 13-3/8" casing. Install 13-5/8" wellhead system. 4 Batch drill, skid rig to next well. Install 13-5/8" BOPE. 5 Drill 12-1/4" hole to 9-5/8" csg point of approx. 3500' (ROP 11007. 6 Run and cement 9-5/8" casing. 7 Batch drill, skid rig to next well. 8 Directionally drill 8-1/2" hole from approx 3500'-12684' (Top C-5). ROP=640 fpd (all 8-1/2" hole) KOP DLS Angle Range 3600 2.5 0-52 0 22 2 24 12 36 9 No intermediate E-line logs required 10 Run & cement 7" casing. 11 Directionally drill 6" hole from 12684'-15477'. ROP=240 fpd (all 6" hole) KOP DLS Angle Range 12700 7 52-84 2 38 1 39 2 41 2 43 0 43 0 43 0 43 2 45 0.5 45.5 0.5 46 12 Run drillpipe conveyed logs; DIL-GR-SP-Sonic. 13 RIH, CCH for 4-1/2" slotted liner 14 Run & install slotted liner from 12484'-15517'. 15 PU 2-7/8" tubing, RIH. Displ well to diesel & wash slotted liner. 16 17 18 19 2O 21 MU packer assy, 2-7/8" tbg completion, GLM and RIH. Land same. Set BPV. Nipple down BOP's. Install wellhead. Install gas lift system. Release rig. Revised 1/11/96 GRWEST.XLS Page 1 A 2,000 4,000 6,000 8,000 10,000 12,000 14,000 16,000 0 GP54DVT.XLS GPP 54 Grass Roots Depth VS Days Drill 17-1/2" OH (ROP = 900') Run 13-3/8" CSGWellhead Drill 12-1/4" OH (ROP = 1100') Run 9-5/8" CSG Drill 8-112" )OH (ROP = 640'~ ~--Estimated Depth (FT) Actual Depth (FT) Rub 7" CSG JAN t Drill) 6" OH (ROP = 2~40') i Run Logs; Clean0ut OH; Run 4- ~/2" Slotted Liner Run TBG 10 2O 3O Days 40 50 60 12/19/95 26"@ (105' BML) RT 114.75' RKB ik5.75' TOP OF L 62' (75' WATER OEP: I[ SEA LEVEL rMI. J ?$' .~_ Top 26" ~ 1~' R~ Ho' ~ML~ ~' R~ ~ No~: O~r 9 ~u~m he~ 2~ ~ok to suffa~ DECK LEG LINE Inner 3 alots are d/ffemnL See attached plan view. GRANITE POINT WELLBORE CONDUCTOR STATUS UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL File: GPCOND. drw DATE: 07-21-95 Granite Pt. Time Line Overall Plan for Granite Pt. Platform Days Start End Refl'd.. Cpm Days Date Date Description of work 71 71~ 7/12/95 9/21195 7 78 9/21195 9/28~95 13 91 9/28195 10/11/95 11 102 10111/95 10/22/95 2 104 10/22/95 10/24/95 65 169 10/24/95 12/28/95 39 208 12/28/95 2/5/96 2 210 2/5/96 2/7/96 4 214 2/7/96 2/11/96 3 217 2/11196 2/14/96 3.5 220.5 2/14/96 2/17/96 7 227.5 2/17~96 2/24/96 3 230.5 2/24196 2/27/96 3 233.5 2/27/96 3/1/96 2 235.5 3/1196 3~3~96 38 273.5 3~3/96 4110~96 39.5 313 4/10~96 5/20196 38 351 5~20~96 6/27~96 18 369 6/27196 7/15/96 Mobilize I Install Rig 156 and Gdndin~l Package at GPP Workover 11-13 Rd P&A 42-23 for reddll P&A 22-13 for reddll Change over mud system from WBM to OBM Reddll 22-13 and complete Reddll 42-23 and complete Remove OBM and clean active/resv system Skid d~l from le~l #3 to ~ Batch ddll well #52 to 13-3/8" csg. pt. Batch ddll well #53 to 13-3/8" csg. pt. (includes dg skid) Batch ddll well #54 to both 13-3/8" & 9-5~8" csg. pt. (includes dg skid) Batch ddll well #53 to 9-5~8" csg. pt. (includes rig skid) Drill well #52 to 9-5~8" CS~l. pt. Change over mud system from WBM to OBM Drill to TD & complete well #52 Drill to TD & complete well #53 Drill to TD & complete well #54 Demobilize Rig 156 Revised 12/19/95 per MWD TIMELINE.XLS Page 1 14 18 4- T10N R12~ 4- 4- 1.53 + I 24 2400 feet I -I. -I- · +- + I · I .1- I 1 UNOCAL GRANITE POINT Platform GP54 slot #4-9 Granite Point Field Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : GP54 Version #4 Our ref : prop1457 License : Date printed : 3-Jan-96 Date created : 15-Nov-95 Last revised : 3-Jan-96 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 57 52.745,w151 20 20.066 Slot location is n60 57 28.914,w151 19 53.944 Slot Grid coordinates are N 2544511.417, E 263322.224 Slot local coordinates are 2420.00 S 1289.81E Reference North is True North Nm~a 0~ & Gas Cons. UNOCAL GRANITE POINT P[atform,GP54 Granite Point Fietd,Cook Intet, Ataska PROPOSAL LISTING Page 1 Your ref : GP54 Version #4 Last revised : 3-Jan-96 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/1OOFt Sect 0.00 0.00 270.00 0.00 0.00 N 0.00 E 0.00 500.00 0.00 270.00 500.00 0.00 N 0.00 E 0.00 600.00 1.00 270.00 599.99 0.00 S 0.87 W 1.00 700.00 2.00 270.00 699.96 0.00 S 3.49 W 1.00 800.00 3.00 270.00 799.86 0.00 S 7.85 W 1.00 1000.00 3.00 270.00 999.59 0.00 S 18.32 W 0.00 1200.00 3.00 270.00 1199.31 0.00 S 28.79 W 0.00 1300.00 2.00 270.00 1299.22 0.00 S 33.15 W 1.00 1400.00 1.00 270.00 1399.18 0.00 S 35.7-/ W 1.00 1500.00 0.00 270.00 1499.18 0.00 S 36.64 W 1.00 0.00 0.00 Begin Due West Nudge 0.41 1.63 3.67 End Angle Build 8.56 13.46 Begin Angle Drop 15.50 16.72 17.13 End of Directional Nudge 2000.00 0.00 270.00 1999.18 0.00 S 36.64 W 0.00 17.13 2500.00 0.00 270.00 2499.18 0.00 S 36.64 W 0.00 17.13 3000.00 0.00 270.00 2999.18 0.00 S 36.64 W 0.00 17.13 3500.00 0.00 270.00 3499.18 0.00 S 36.64 W 0.00 17.13 3600.00 0.00 270.00 359<2.18 0.00 S 36.64 W 0.00 17.13 KOP 3700.00 2.50 207.58 3699.14 1.93 S 37.65 W 2.50 19.31 3800.00 5.00 207.58 3798.92 7.7-5 S 40.68 W 2.50 25.85 3900.00 7.50 207.58 3898.32 17.38 S 45.72 W 2.50 36.74 4000.00 10.00 207.58 3997.15 30.~ S 52.76 W 2.50 51.95 4100.00 12.50 207.58 4095.22 48.15 S 61.79 W 2.50 71.46 4200.00 15.00 207.58 4192.35 69.22 S 72.80 W 2.50 95.22 4300.00 17.50 207.58 4288.34 94.02 S 85.76 W 2.50 123.20 4400.00 20.00 207.58 4383.03 122.50 S 100.64 W 2.50 155.34 4500.00 22.50 207.58 4476.22 154.62 S 117.42 W 2.50 191.58 4600.00 25.00 207.58 4567.75 190.32 S 136.07 W 2.50 231.86 4700.00 27.50 207.58 4657.43 229.52 S 156.54 W 2.50 276.08 4800.00 30.00 207.58 4745.09 272.15 S 178.81 W 2.50 324.17 4900.00 32.50 207.58 4830.58 318.12 S 202.83 W 2.50 376.05 5000.00 35.00 207.58 4913.72 367.36 S 228.56 W 2.50 431.60 5100.00 37.50 207.58 4994.36 419.77 S 255.94 W 2.50 490.72 5200.00 40.00 207.58 5072.34 475.24 S 284.92 W 2.50 553.31 5300.00 42.50 207.58 5147.52 533.68 S 315.44 W 2.50 619.24 5400.00 45.00 207.58 5219.75 594.96 S 347.46 W 2.50 688.38 5500.00 47.50 207.58 5288.89 658.98 S 380.91 W 2.50 760.61 5600.00 50.00 207.58 5354.82 725.62 S 415.72 W 2.50 835.79 5649.54 51.24 207.58 5386.25 759.55 S 433.45 W 2.50 874.08 EOC 6000.00 51.24 207.58 5605.67 1001.7-/ S 559.99 W 0.00 1147.35 6500.00 51.24 207.58 5918.71 1347.33 S 740.52 W 0.00 1537.23 7000.00 51.24 207.58 6231.75 1692.90 S 921.05 W 0.00 1927.10 7500.00 51.24 207.58 6544.79 2038.46 S 1101.58 W 0.00 2316.97 8000.00 51.24 207.58 6857.83 2384.02 S 1282.11 W 0.00 2706.85 8500.00 51.24 207.58 7170.87 2729.59 S 1462.64 W 0.00 3096.72 9000.00 51.24 207.58 7483.91 3075.15 S 16/+3.17 W 0.00 3486.60 9500.00 51.24 207.58 7796.95 3420.71 S 1823.70 W 0.00 3876.47 10000.00 51.24 207.58 8109.99 3766.28 S 2004.23 W 0.00 4266.34 10500.00 51.24 207.58 8423.03 4111.84 $ 2184.76 W 0.00 4656.22 11000.00 51.24 207.58 8736.07 4457.40 S 2365.29 W 0.00 5046.09 11500.00 51.24 207.58 9049.12 4802.97 S 2545.82 W 0.00 5435.96 12000.00 51.24 207.58 9362.16 5148.53 S 2726.36 W 0.00 5825.8/+ 12484.00 51.24 207.58 9665.18 5483.04 S 2901.11W 0.00 6203.24 Top 4 1/2" Liner All data is in feet unless otherwise stated Coordinates from slot #4-9 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 207.88 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform,GP54 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : GP54 Version #4 Last revised : 3-Jan-96 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 12500.00 51.24 207.58 9675.20 5494.10 S 2906.89 W 0.00 6215.71 12643.44 51.24 207.58 9765.00 5593.23 S 2958.68 W 0.00 6327.56 TARGET #1 - T/ C-5 - Begin Final B & T 12700.00 55.05 206.26 9798.92 5633.58 S 2979.15 ~ 7.00 6372.80 12800.00 61.83 204.19 9851.23 5710.64 S 3015.39 W 7.00 6457.86 12900.00 68.63 202.36 9893.11 5794.01S 3051.21 ~ 7.00 6548.30 13000.00 75.45 200.70 9923.93 5882.45 S 3086.08 W 7.00 6642.78 13078.06 80.78 199.48 9(240.00 5954.16 S 3112.30 W 7.00 6718.44 TARGET #2 - B/ C-5 13100.00 82.28 199.14 9943.23 5974.64 S 3119.48 W 7.00 6739.90 13117.79 83.50 198.87 9945.43 5991.34 S 3125.23 ~ 7.00 6757.34 Final EOC 13500.00 83.50 198.87 9988.72 6350.66 S 3248.08 W 0.00 7132.41 14000.00 83.50 198.87 10045.35 6820.73 S 3408.79 W 0.00 7623.07 14500.00 83.50 198.87 10101.98 7290.80 S 3569.50 W 0.00 8113.74 15000.00 83.50 198.87 10158.61 7760.87 S 3730.21 W 0.00 8604.40 15277.12 83.50 198.87 10190.00 8021.40 S 3819.28 W 0.00 8876.34 TARGET ~ / C-5 Exit 15477.12 83.50 198.87 10212.65 8209.43 S 3883.56 ~ 0.00 9072.61 TD All data is in feet unless otherwise stated Coordinates from slot ~4-9 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 207.88 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT P[atform, GP54 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 3 Your ref : GP54 Version #4 Last revised : 3-Jan-96 Con~ents in wellpath MD TVD Rectangular Coords. Comment 500.00 500.00 0.00 N 0.00 E Begin Due West Nudge 800.00 799.86 0.00 S 7.85 W End Angle Build 1200.00 1199.31 0.00 S 28.79 W Begin Angle Drop 1500.00 1499.18 0.00 S 36.64 W End of Directional Nudge 3600.00 3599.18 0.00 S 36.64 W KOP 5649.54 53~.25 7~9.55 S 433.45 W EOC 12484.00 9665.18 5483.04 S 2901.11W Top 4 1/2" Liner 12643.44 9765.00 5593.23 S 2958.68 W TARGET #1 - T/ C-5 - Begin Final B & T 13078.06 9940.00 5954.16 S 3112.30 W TARGET #2 - B/ C-5 13117.79 9945.43 5991.34 S 3125.23 W Final EOC 1527-/.12 10190.00 8021.40 S 3819.28 W TARGET #3 / C-5 Exit 1547-/.12 10212.65 8209.43 S 3883.56 W TD Targets associated with this we[lpath Target name Position T.V.D. Local rectangular coords. Date revised GP54 C-5 Exit 15-nov 259340.000,2536570.000,0.000010190.00 8021.40S 3819.28W 15-Nov-95 GP54 B/C-5 15-Nov-95 260085.000,2538590.000,0.00009940.00 59~.53S 3115.68W 15-Nov-95 GP54 T/C-5 15-Nov-95 260250.000,2538980.000,0.00009765.00 5593.23S 2958.68~ 15-Nov-95 All data is in feet unless otherwise stated Coordinates from slot #4-9 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea [eve[). Bottom hole distance is 9081.68 on azimuth 205.32 degrees from wellhead. Total Dogleg for wel[path is 90.44 degrees. Vertical section is from wellhead on azimuth 207.88 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Ptatform, GP54 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : GP54 Version #4 Last revised : 3-Jan-96 Measured Inc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 0.00 0.00 270.00 0.00 2420.00 S 1289.81 E 0.00 0.00 500.00 0.00 270.00 500.00 2420.00 S 1289.81 E 0.00 0.00 600.00 1.00 270.00 599.99 2420.00 S 1288.94 E 1.00 0.41 700.00 2.00 270.00 699.96 2420.00 S 1286.32 E 1.00 1.63 800.00 3.00 270.00 799.86 2420.00 S 1281.96 E 1.00 3.67 1000.00 3.00 270.00 99<2.59 2420.00 S 1271.49 E 0.00 8.56 1200.00 3.00 270.00 1199.31 2420.00 S 1261.03 E 0.00 13.46 1300.00 2.00 270.00 1299.22 2420.00 S 1256.66 E 1.00 15.50 1400.00 1.00 270.00 139<9.18 2420.00 S 1254.05 E 1.00 16.72 1500.00 0.00 270.00 1499.18 2420.00 S 1253.18 E 1.00 17.13 2000.00 0.00 270.00 1999.18 2420.00 S 1253.18 E 0.00 17.13 2500.00 0.00 270.00 2499.18 2420.00 S 1253.18 E 0.00 17.13 3000.00 0.00 270.00 2999.18 2420.00 S 1253.18 E 0.00 17.13 3500.00 0.00 270.00 349<2.18 2420.00 S 1253.18 E 0.00 17.13 3600.00 0.00 270.00 3599.18 2420.00 S 1253.18 E 0.00 17.13 Begin Due 14est Nudge End Angle Build Begin Angle Drop End of Directional Nudge KOP 3700.00 2.50 207.58 3699.14 2421.94 S 1252.16 E 2.50 19.31 3800.00 5.00 207.58 3798.92 2427.74 S 1249.14 E 2.50 25.85 3900.00 7.50 207.58 3898.32 2437.38 S 1244.10 E 2.50 36.74 4000.00 10.00 207.58 3997.15 2450.87 S 1237.05 E 2.50 51.95 4100.00 12.50 207.58 4095.22 2468.16 S 1228.02 E 2.50 71.46 4200.00 15.00 207.58 4192.35 2489.22 S 1217.02 E 2.50 95.22 4300.00 17.50 207.58 4288.34 2514.02 S 1204.06 E 2.50 123.20 4400.00 20.00 207.58 4383.03 2542.51 S 1189.18 E 2.50 155.34 4500.00 22.50 207.58 4476.22 2574.63 S 1172.39 E 2.50 191.58 4600.00 25.00 207.58 4567.75 2610.32 S 1153.75 E 2.50 231.86 4700.00 27.50 207.58 4657.43 2649.52 S 1133.27 E 2.50 276.08 4800.00 30.00 207.58 4745.09 2692.15 S 1111.00 E 2.50 324.17 4900.00 32.50 207.58 4830.58 2738.13 S 1086.98 E 2.50 376.05 5000.00 35.00 207.58 4913.72 2787.37 S 1061.26 E 2.50 431.60 5100.00 37.50 207.58 4994.36 2839.77 S 1033.88 E 2.50 490.72 5200.00 40.00 207.58 5072.34 2895.25 S 1004.90 E 2.50 553.31 5300.00 42.50 207.58 5147.52 2953.68 S 974.37 E 2.50 619.24 5400.00 45.00 207.58 5219.75 3014.97 S 942.35 E 2.50 688.38 5500.00 47.50 207.58 5288.89 3078.99 S 908.91 E 2.50 760.61 5600.00 50.00 207.58 5354.82 3145.62 S 874.10 E 2.50 835.79 5649.54 51.24 207.58 5386.25 3179.56 S 856.37 E 2.50 874.08 6000.00 51.24 207.58 5605.67 3421.77 S 729.83 E 0.00 1147.35 6500.00 51.24 207.58 5918.71 3767.34 S 549.30 E 0.00 1537.23 7000.00 51.24 207.58 6231.75 4112.90 S 368.76 E 0.00 1927.10 7500.00 51.24 207.58 6544.79 4458.46 S 188.24 E 0.00 2316.97 EOC 8000.00 51.24 207.58 6857.83 4804.03 S 7.7O E 0.00 27O6.85 JAN t 6 l~Jg~ 8500.00 51.24 207.58 7170.87 5149.59 S 172.83 14 0.00 3096.72 9000.00 51.24 207.58 7483.91 5495.16 S 353.36 W 0.00 3486.60 9500.00 51.24 207.58 7796.95 5840.72 S 533.89 W 0.00 3876.47 JtJas~:l HI & Ga~ ~s. ~i~ 10000.00 51.24 207.58 8109.~ 61~.28 S 714.42 W 0.00 42~.34 ~~ 10500.00 51.24 207.58 8423.03 6531.85 S 894.95 14 0.00 4656.22 11000.00 51.24 207.58 8736.07 6877.41 S 1075.48 14 0.00 5046.09 11500.00 51.24 207.58 9049.12 7222.98 S 1256.01 W 0.00 5435.96 12000.00 51.24 207.58 9362.16 7568.54 S 1436.54 14 0.00 5825.84 12484.00 51.24 207.58 9665.18 7903.04 S 1611.30 14 0.00 6203.24 Top 4 1/2" Liner All data is in feet unless otherwise stated Coordinates from N14 Corner of Sec. 13, TION, R12W SM and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 207.88 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimum curvature methed. Presented by Baker Hughes INTEQ Grani UNOCAL GRANITE POINT Platform, GP54 te Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : GP54 Version ~4 Last revised : 3-Jan-96 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 12500.00 51.24 207.58 9675.20 7914.10 S 1617.07 W 0,00 6215.71 12643.44 51.24 207.58 9765.00 8013.24 S 1668.86 W 0.00 6327.56 TARGET #1 - T/ C-5 - Begin Final B & T 12700.00 55.05 206.26 9798.92 8053.59 S 1689.34 W 7,00 6372.80 12800.00 61.83 204.19 9851.23 8130.64 S 1725.57 ~ 7.00 6457.86 12900.00 68.63 202.36 9893.11 8214.02 S 1761.39 ~ 7.00 6548.30 13000.00 75.45 200.70 9923.93 8302.46 S 1796.26 ~ 7.00 6642.78 13078.06 80.78 199.48 9940.00 8374.17 S 1822.49 W 7,00 6718.44 TARGET #2 - B/ C-5 13100.00 82.28 199.14 9943.23 8394.65 S 1829.67 ~ 7,00 6739.90 13117.79 83.50 198.87 9945.43 8411.34 S 1835.42 ~ 7.00 6757.34 Final EOC 13500.00 83.50 198.87 9988,72 8770.67 S 1958.27 ~ 0.00 7132.41 14000.00 83.50 198.87 10045.35 9240.74 S 2118.98 ~ 0.00 7623.07 14500.00 83.50 198.87 10101.98 9710.81 S 2279,68 W 0.00 8113.74 15000.00 83.50 198.87 10158.61 10180.88 S 2440.39 W 0.00 8604.40 15277.12 83.50 198.87 10190,00 10441.41 S 2529.46 ~ 0.00 8876.34 TARGET ~3 / C-5 Exit 15477.12 83.50 198.87 10212,65 10629.44 S 2593.75 ~ 0.00 9072.61 TD All data is in feet unless otherwise stated Coordinates from Ng Corner of Sec. 13, TION, R12W SM and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Vertical section is from we[thead on azimuth 207.88 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT P[atform, GP54 Granite Point Field, Cook Inlet, ALaska PROPOSAL LISTING Page 3 Your ref : GP54 Version ~4 Last revised : 3-Jan-96 Comments in wetlpath MD TVD Rectangular Coords. Comment 500.00 500.00 2420.00 S 1289.81E Begin Due West Nudge 800.00 799.86 2420.00 S 1281.96 E End Angle Build 1200.00 1199.31 2420.00 S 1261.03 E Begin Angle Drop 1500.00 1499.18 2420.00 S 1253.18 E End of Directional Nudge 3600.00 3599.18 2420.00 S 1253.18 E KOP 5649.54 5386.25 3179.56 S 856.37 E EOC 12484.00 9665.18 7903.04 S 1611.30 W Top 4 1/2" Liner 12643.44 9765.00 8013.24 S 1668.86 W TARGET #1 - T/ C-5 - Begin Final B & T 13078.06 9940.00 8374.17 S 1822.49 W TARGET #2 - B/ C-5 13117.79 9945.43 8411.34 S 1835.42 W Final EOC 15277.12 10190.00 10441.41S 2529.46 ~ TARGET ~ / C-5 Exit 15477.12 10212.65 10629.44 S 2593.75 ~ TD Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised GP54 C-5 Exit 15-nov 259340.000,2536570.000,0.000010190.00 10441.41S 2529.46~ 15-Nov-95 GP54 B/C-5 15-Nov-95 260085.000,2538590.000,0.00009940.00 8406.54S 1825.86W 15-Nov-95 GP54 T/C-5 15-Nov-95 260250.000,2538980.000,0.00009765.00 8013.24S 1668.86W 15-Nov-95 ALl data is in feet unless otherwise stated Coordinates from NW Corner of Sec. 13, TION, R12W SM and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Bottom hole distance is 9081.68 on azimuth 205.32 degrees from wellhead. Total Dogleg for wellpath is 90.44 degrees. Vertical section is from wellhead on azimuth 207.88 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform GP54 slot #4-9 Granite Point Field Cook Inlet, Alaska CLEARANCE REPORT by Baker Hughes INTEQ Your ref : GP54 Version #4 Our ref : prop1457 License : Date printed : 29-Dec-95 Date created : 15-Nov-95 Last revised : 29-Dec-95 Field is centred on n60 59 36.731,w151 18 33.112 Structure is centred on n60 57 52.745,w151 20 20.066 Slot location is n60 57 28.914,w151 19 53.944 Slot Grid coordinates are N 2544511.417, E 263322.224 Slot local coordinates are 2420.00 S 1289.81E Reference North is True North Main calculation performed with 3-D Minimun Distance method Object we[lpath GMS <O-10572'>,,13-13,GRANITE POINT Platform PGMS <O-11560'>,,11-13Rd,GRANITE POINT Ptatfor GMS <4025-11653'>,,11-13,GRANITE POINT Ptatfor PMSS <9437 - 10270'>,,32-13Rd,GRANITE POINT Pt PMSS <8478 - 1256-~'>,,32-13Rd~2,GRANITE POINT PGMS <O-10200'>,,32-13,GRANITE POINT Platform GMS <2700 - 11450'>,,33-13,GRANITE POINT Platf ~MSS <8630-11376'> ,,33-23,GRANITE POINT P[atfo -~ GMS <O-12000'>,,32-23,GRANITE POINT Platform GMS <8900-11986'>,,32-23Rd,GRANITE POINT Ptatf GMS/MSS <0-11150-15715'>,,MUC I-1,GRANITE POIN. GMS <0-118~9'> ,,GP-51,GRANITE POINT Platform -~-PGMS <O-12163'>,,GP-50,GRANITE POINT Platform GMS <O-108~O.>,,MUC I-2,GRANITE POINT Platform GMS <O-12200'>,,12-24,GRANITE POINT Platform GMS <O-10560'>,,24-13,GRANITE POINT Platform GMS <9700-10640'>,,24-13Rd,GRANITE POINT Ptatf GMS <O-1147~J.~,,33-14,GRANITE POINT Platform GMS <9200-11410'>,,33-14Rd,GRANITE POINT Ptatf GMS <O-11200'~,,31-23,GRANITE POINT Platform GMS/MSS/GMS <0-124?1'>,,44-11,GRANITE POINT Pt ~ GMS <O-10850'>,,44-14,GRANITE POINT Platform GMS <O-11800'~,,11-24,GRANITE POINT Platform GMS <O-10191'>,,31-14RcJ~2,GRANIT~ POINT Ptatfo GHS/MSS <O-8876'>,,31-14,GRANITE ~OINT Ptatfor GMS <O-11011'>,,31-14Rd~l,GRANI1~ POINT Ptatfo GMS <O-10874'>,,31-13,GRAN[TE POINT Platform GMS/MSS/GMS (O-14544~>,,42-23,GRANITE POINT Pt PMSS <11453 - 13821'>,,22-13Rd2,GRANITE POINT Closest approach with 3-D minimun distance method Last revised Distance M.D. Diverging from M.D. 11-Aug-95 22.9 1040.0 3700.0 11-Aug-95 72.1 650.0 1580.0 11-Aug-95 72.1 650.0 1580.0 13-AUg-95 93.9 380.0 11760.0 13-AUg-95 93.9 380.0 11760.0 13-Aug-95 93.9 380.0 1700.0 13-Aug-95 93.9 380.0 1700.0 11-AUg-95 26.2 1250.0 11200.0 11-Aug-95 26.2 1250.0 10320.0 22-May-91 26.2 1250.0 10340.0 22-May-91 91.0 460.0 13600.0 11-Aug-95 91.0 550.0 3380.0 2-0ct-92 35.1 3360.0 3~60.0 22-May-91 97.1 600.0 1940.0 22-May-91 9.2 800.1 800.1 22-May-91 8~.7 550.0 550.0 22-May-91 8~.7 550.0 550.0 22-May-91 52.5 1300.0 1300.0 22-May-91 52.5 1300.0 1300.0 22-May-91 62.0 200.0 7560.0 22-May-91 66.0 280.0 940.0 22-May-91 54.7 100.0 6380.0 22-May-91 49.6 920.0 6860.0 22-May-91 64.8 650.0 650.0 22-#ay-9t 6&.8 650.0 12060.4 22-Nay-91 64.8 650.0 650.0 22-May-91 90.0 100.0 500.0 22-May-91 78.6 650.0 14200.0 20-Dec-95 93.0 320.0 12380.0 PMSS <6738 - 12036'>,,22-13R~,GRANITE POINT Pl GCT Gyro <O-7002'>,,22-13Rd,GRANITE POINT Plat GP53 Version #4,,GP53,GRANITE POINT Platform GP52 Version #4,,GP52,GRANITE POINT Platform 20-Dec-95 4-Dec-95 29-Dec-95 29-Dec-95 ~3.0 93.0 4.4 11.3 320.0 500.0 500.0 12380.0 320.0 2700.0 3500.0 Cre~ted by ; jones Dote ploEed : 3-Jan-96 Plot Reference is GP54 Version ~4. Coordinates ere in feet reference slot ~4-g. True Vertical Depths ere reference RKB (Rig: ~156). --- Baker Hughes INTEQ --- 20_ 0_3 - 20_ 80_ 120_ - - - 200_ _ 220_ 2~_ 280 300_ 320 _ 3~ I I I UNOCAL Structure : GEANITE POINT Platform Well : GP54 Field : Granite Point Field Location : Cook Inlet, Alaska <-- West Scole 1. lO.OO 280 260 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 2300 4700 1300 1300 1.7~0 1500 1700 30 1500 ~100 5500 5700 1500 4..:7,0 1700 3300 5900 2100 / 3700/ 1700 1900 I I I I I I I I I 280 260 240 220 200 180 1 60 140 120 1 O0 80 60 40 20 0 20 40 <== Wesf Scole 1 ' 10.00 20 -- 0 '' 0 0 2O 0 lO0 I I V 220 _240 340 UNOCAL 36oo .. "-~D 3700I ~ 3~ooJ 59004 4100. 4200_ Structure : GRANITE POINT Platform Well : GP54 Field : Granite Point Field Location : Cook Inlet, Alaska < W e s { ~:o,~ , . ~o.oo 3200 3; O0 5000 2300 2800 2700 2500 2500 2.400 2300 2200 21 O0 2000 ~ 300 1800 1700 1600 , // 4300_ 4400 45001 4600J 59OO 9500 89OO 9O0 9100 8700 ~3OO 3600 3700 _3900 _4000 4100 4200 43O0 - _4400 - .4500 _4600 _4700 _4800 _ _4900 _ _5000 _5100 79oo 3700 85OO 8100 5000_ 9100 5100l 5200-! / _5200 5300t ~/,/9.500 _53O0 54001 i i i I i i i I I I I I 1 I I II I I 1 i I I i i 1 ; i i I I I 5400 3200 3 ! O0 3000 2900 2800 2700 2600 2500 2400 2300 2200 21 O0 2000 1 gl:X) 1800 1700 1600 < - - W e s t Scale 1 ' 50.00 I Created by : jones Date plotted : .~-Jan-96 Plot Reference ~s GP54 Version #4. I Coordinates ore in feet reference slot i~4-9. True Vertical Depths are reference RKB (Rig: ~156). --- Baker Hughes INTEQ --- UNOCAL Structure : GEANIT£ POINT Platform Well : GP54 Field : Granite Point Field Location : Cook Inlet, Alaska < Wes{ 1500 1400 1500 1200 1100 1000 900 800 700 600 500 400 500 100 Scale 1 · 50.00 0 100 900 t 3100 4500 3tO0 3,300 10001 /33~ 4700 3500 1100t-- 700 / t700 ~00 /3900 12001 4900 /41 O0 ~ ~ ~oo , ,oo / ~ ~ / t~ 2400q / 5100 ~6100 /67 / I I I I I I I I I I I I I I I I I I I I I I I I 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 100 < West ~o,e ~. ~o.oo 7OO 80O 9O0 1000 100 ~00 1400 5OO 600 700 800 200 400 5OO 0 I I V .f I. rNOCAL GRANITE POINT PLATFORM FELI~ 452, #53 AND #54 DEPTH INTERVAL 0 - ± 900' 0 - ~ 1100' %53 AND #54 17-1/2" HOLE 13-3/8" CASING MUD TYPE GENERIC MUD #2 HUD ADDITIVES M-I GEL/M*I BAR/SODA/ ASH/CAUSTIC/LINE POTENTIAL PROBLEMS HOLE CLF. A~ING/G~AV~L/ GAS KICK/LOST CIRCULATION TREATMENTS/PROCEDURES Build spud mud system with prehydrated bentonita in fresh water and filtered inlet water. a) Treat drill water with Soda Ash as required to reduce calcium content to 40 ± ppm. b) Frs-hydrate 25 lbs/bbl bentonite and allow to hydrate for 4-6 hours. Just prior to spud add filtered inlet water as required to yield a 50-70 sec/qt spud mud, 2) Drill hole. 3) Drill to ±1100'. Use all solids control equipment. Raise viscosity if gravel sections are encountered. Run 13-3/8" casing. 4) Evaluate quality of mud and i~ possible save the mud from well #52 and reuse it on well #53 in the 13-3/8" Casing Interval. Build additional volume as required. After the 13-3/8" on #53 reuse mud on the 13-3/8" and 9-5/8" Interval on 454. Then move back to #53 and use the mud in the 9-5/8" Interval. Then use the mud on #52 in the 9-5/8" Interval. DM-184 ,wP JAN 16 1~6 Alaska Oil & Gas Cons. Commi~ ANTICIPATED SPUD MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss (AP1) P~ 8.8 - 9.4 ppg 45-100 sec/qt 10-15 cps 10-30 #/100 ft~ 8-20 NO Control 8.5 - 9.5 Note: DO NOT EXCEED M.A.C. oX products or use products not approved in the discharge permit. See letter requesting authorization for list of approved products and M.A.C. DM-184 .WP UNOCAL GRANITE POINT PLATFORM w~I,z..~ I152, #5~ AND #54 DgPTH INTERVAL MUD TYPE MUD ADDITIVES POTENTIAL PROBLEHS ±1100' - ±3500~ (153) ~lloo, ±3500' (#5~) +900' - ~:2700' (#52) 12--1/4" HOLE 9-5/8" CASING GENERIC HUD M-I GEL/M-I BAR/SODA ASH/ POLYPAC/SPER~ENE/XP-20! SODIUM BICARBONATE! CAUSTIC i) 2) 3) 6) 8) TREATMENT PROCEDURES Use the surface mud from well f53 to drill the 13-3/8" collar, cement and shoe. Treat this fluid as required to avoid excessive cement contamination. Build additional volume as required with prehydrated bentonite in fresh water and filtered inlet water. Pump viscous sweeps if required by hole conditions. Control density with barite, F.I.W. water, and solids control equipment. Dump all sand traps as required. Report drill solids analysis on mud check sheet. Report hydraulics calculations on mud check sheet. Use Defoam-X if foaming becomes a problem. Prehydrate all bentonite in freshwater. DM-184 .WP (12/95) lO) Drill to T.D. If hole conditions warrant, spot a viscous pill on bottom. Run 9-5/8" casing. Evaluate quality o~ mud and save for reuse on 9-5/8" casing interval on wells ~53 and #54. ANTICIPATED .9-5/8" MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels API Fluid Loss MBT Drilled Solids 9.0-9.6 ppg 40-70 sec/qt 10-15 cps 10-20 t/100ft' 6/12/18 NO CONTROL 8,5 - 11.0 < 30 ppb < 75 ppb Note~ This mud program is a guideline only. Hole conditions should dictate actual mud properties. DO NOT EXCEED M.A.C. of products or use products not approved in the discharge permit. See letter requesting authorization o~ list of approved products and M.A.C. DM-184 .WP (12/95) DEPTH INTERVAL MUD T~PE MUD ADDITIVES VEmSA.~/ POTENTIAL PROBLEMS C I RCULAT I ON/WATER KICKS/HIGH GELS ~UNOCAL GRANITE POINT PLATFORM ~I. LS #52, #53 #52 2700' - 11395' 8'1/2" 11395' - 14357' t53 3500' - 12800' 6" 12800' - 15700' 6" #5'~ 3500' - 12§$4' 12684' ' 15517' 6" MINERAL OZL BASE VG-69/M-I Bar/CONOCO LVT2-/LOW&TE VERSACOAT! VERSAHRP/VER~ANOD / AI,COMER 274/LIME/CaC12 HOLE CLEANII~O/LOST 1. Mix mineral oil mud system utilizing the following recommendations: Note: Initial volume from G.P. 22-13 will be approximately 800 bbls. Additional volume should be mixed aa follows~ a. Premix and store 10.8 ppg calcium chloride brino. b. Place mineral oil in clean mixing tank. c. Add VG-69 and lime slowly through shear pump to minimize balling. Shear for 30 minutes. d. Add primary emulsifier, versacoat. e. Blend for a minimum of 30 minutes. Add cal=ium chloride brine.g. Blend for a minimum of 30 minutes. h. Add Versawet/check theology/add Versamod. i. Add Barite to required mud weight. Antioipated mud weight in the 8-1/2' hole should be approximately 9.5 ppg. DM-184 .WP j. Blend for a minimum of 30 minutes. Note= The most important aspect in mixing a mineral oil mud is the amount of mixing energy put into the fluids while the brine is being added. The more shear put into the fluoid the smaller the water droplets become and the more viscous the fluid. The emulsions become more stable as more shear is put into the fluid. 2. Displacement Procedure Note~ Use large mesh shaker screens (30 or 40) during displacement and for up to two circulations thereafter. Monitor pump strokes and pump rates continuously during displacement· Conduct a rig team meeting discussing all aspects of displacement· Note: Rig operations should dictate optimum displacement time. be Dilute and lower mud weight ofwater base mud. Pump a 75 bbl brineXCD polymer viscous sweep. Pump a 25 bbl mineral oil viscous sweep pill. Pump mineral oil mud system. c. Displace in turbulent ~low if possible. Reciprocate and rotate drill pipe. Make sure the bit is on bottom as the spacers and mineral oil mud clear the bit. · Drill the 8-1/2 lateral section. If there are indications that a cuttings bed has been deposited in the wellbore, the most effective m~thod to clean the cuttings bed is with mechanical agitation by rotating and reciprocating the drill string. Maintaining high low shear rate theologies will minimize the formation of a cuttings bed. Low shear rate theologies can be elevated with Versamod, Versa HRP, Alcomer 274 and VG-69. I£ required, pump low/hi viscosity sweeps. · Optimize mixing of "dry jobs" in order to minimize the number of wet trips. . After reaching TD, condition the hole for logging by rotating and reciprocating the drill string. If required, pump low/hi viscosity sweeps. 6. Run and cement the 7" liner. · Clean out 7" liner and drill 6" hole· Mud weights should be kept as low as possible. Centrifuge 8-1/2" hole mud and ad4 Conoco LVT 200 to reduce mud weight. Conduct cost estimate prior to reducing mud weight. DM-184 .WP (12/95) · 10. Maintain low shear rate values with VG-69, Versamod, Alcomer 274 and Versa HRP. Run and cement 5" liner. Displace well to diesel after running tubing. (See separate displacement procedure.) Store mineral oil mud for use on next well in sequence. ANTICIPATED MUD PROPERTIS8 Mud Weight ppg 8.5 9.5 PV 12-20 25-55 YP 15-20 15-20 Gels 10/25 10/40 O/W 80/20 8o/2o g.S. 800+ 800+ HT~P @ 225~ F 6 cc 6 cc BASE FORMULATION LVT 200 bbl VG-69 ppb Lime RRb Versacoat ppb Versawet ppb Versamod ppb/Versa HRP/Al¢omer 274 CaC1, Barite/Lowate ppb Varies w/MW & OW ratio 5-8 2 4-6 1-2 0-1 34 As Required DM-184 .WP (12/95) 3 FLOW ,~ FII.I.-UP ~ ~ ~ I , BOP 13%'3000 p~i , I PIPE RAMS 13~?e" §000 psi BI2ND RAMS 13~/s"~000 psi ~T.T ~~ SPOOL ~~ '~ ~~,~000 ~~ CH0~ MNE~ ~E 4" 5000 psi I [ 4' 5000 psi I ~ P~E ~s 1~%'~000 psi J ' COOK INL Z PLATFORMS BOP STACK 13%~ 5000 psi 6" - 150 LB OH RI{; HEAl)ER SEC FRONT VIEW ¢'- 5000, BUFFER lANK FRONT VIEW · TOP GAUGE .~ R~OIE PANEL TRANSMITTER GAFF. FLANGE BEHIk~ tEADER 3 ! 3A i 7 I 9 1 1116" - 5000# A&~D~.~. ~ 1/16" - 5000~ Fi~. X 4" NI~ .~,,. Adap:ex. 4 1/16" - 5000~ 3" NPB NXgyplm 90 ctmq. ;U~D~. 3 1/16" - ZOO00# Ag~,~N, 3 1/16" - IO00O9 Plq. X 3' l~B 1/16' - 5000~ ~==mrFl~, 2 1/16' 5000# W! 2 - 2' LPT 2 Swage CtumY~ 2 9116" - 10. 000# z'..-,.-cm 11 3 5 '* ~ N'PS f-lOW 4X4X3X3Xl i5 2 17 1~ 1 23 Casing Design Summary Well: GP 54 Field: Casing Mud WT Size (PPG) Granite Point Date: M.S.P. (psi) 1.8/95 Design by: Mitchell Damm Max. Kick Tolerance (BBLS) 26" 8.8 61 13-3/8" 9 301 %5/8" 9 1,031 7" 9 2,187 4-1/2" 9 NA 130 95 77 316 NA *** Siot'ted Liner*** Casing Bottom Top Length Wt Size (FEET) (FEET) (FEET) (LB/FF) 26" 329 47 282 TVD 329 47 282 13-3/8" 1,I00 47 1,053 68 TX/T) 1,099 47 1,052 9-5/8" 3,500 47 3,453 47 TVD 3,499 47 3,452 7" 12,684 47 12,637 29 TVD 9,805 47 9,758 4-1/2" 15,477 12,484 2,993 12.6 TVD 12212 9,665 · Grade Thread Connection K-55 Buttress L-80 Buttress L-80 Buttress L-80 SC-Buttress Casing Weight Tension Minimum ' Collapse * Collapse Collapse Size W/O BF Top of Strength TDF Pressure #1 Pressure #2 Resist. Section Tension ~ Bottom ~ Bottom Tesnsion (LBS3 (LBS) (1,O00/LBS) (psi) (ps~ (ps~ CDF#1 CDF #2 "" Burst Pressure (psi) Minimum Yield Strength (psi) BDt 13-3/8" 71,604 71,604 1,069 14.9 314 NA 1,950 9-5/8" 162291 162291 1,086 6.7 1.001 NA 4,760 7" 366,473 366,473 597 1.6 2,804 4,280 7,020 4-1/2" 37,712 37,712 289 7.7 NA NA NA * Collapse pressures are calculated using two methods (checks). 1) Difference between two cement $1umes (i.e. AVG ora 15.8 PPG (tail) & 14,2 PPG (lead) --- 15 PPG. Subtract a mud of 9.5 PPG = 5.5 PPG = .286 psi/FT gradient X TVD of the casing string.) 2) Differenc~ betwe~m Mud Weight on tho outside and gas lift gas (0.0 psbFT) on the inside. (i.e. Multiply (.052 X MW - 0.0 psbFr) x the TVD of the Top of Cement. 6.2 NA 1,750 3,450 2.: 4.8 NA 5,099 6,870 1._ 2.5 1.6 6,350 8,160 I.. NA NA NA Burst pressure is calculated. (BLIP ~ the depth of the next casing X TVD next casing) X (0.5 = half of wellbore evacuated). NA N/ 1/15/96 Maximum Surface Pressure Calculations Well: GP 54 Casing Size: 26" Depth Interval: 0'-1,100' Hole Size: 17.50 " General Information: Anticipated Mud Weight (MW): $.8 PPG Shoe Depth (D,~ 294 MI) Estimated Fracture Gradient (at the Shoe): Total Depth (Dm): 1,100 MD Bottom Hole Pressure Gradient (BHPG): Gas Crmdient (GG); (assumes worse case): Maximum Gas Coltman Height in wellbore when top of gas is at the shoe (Ht): O.4576 psi/iT 294 TVD O.90 psi/FT 1099 TVD 0.35 psi/FT 0.10 psi/FT 500 Feet (@ anticipated Mud Weight) Maximum Surface Pressure Calculations: Thc wellbore volume is determined using the height of gas colttma m wciibore when top of gas bubble is at the shoe- dunng a gas kick situation. A percentage of the gas column height (I-It), found in the Maximum Kick Toleraac~ Calculations, is used. Maximum Surface Pressure = Maximum Bottom Hole Pressure - HycLrostatic Pressure (Gas Volume +Mud Volume) MSP = P~,o'm. GG*Ht - .052*MW*(Dm-Ht) MSP = 61 psi Hydrostatic Pressure at the Shoe Calculations: The greatest hydrostatic pressure at the shoe (Pshoe) is when the gas bubble reaches the shoe. As~nning a constant bottom hole pressure is apphed while circulating out the gas kick. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the Shoe D~th (Dshoe). Pe~, = MSP + .052*MW*D,ao, Pshoe = 195 psi FPa. e = 265 psi The pressure at the shoe (Pshoe) is less than the fracture pressure at the same shoe. Therefore the shoe integrity is sufficient to adequately handle a gas kick. Pressure Differential Across the Shoe: Pressure differential across the casing shoe = Pshoe - Maximum pore pressure at shoe DPshoe = Pshoe - Pmax (~ shoe = Pshoe - BHPG * D~ ,DP shoe = 92 ps!, The DPshoe is less that the internal yield of the casing. KTGP54.XLS 26" MSP 1/9/96 Maximum Kick Tolerat. Ealculations Well: GP 54 Casing Shoe: 26" General Information Variable~ · i i 1 26" Casm~ Shoe (from RT) 294 Feet (TVD). D,~ 2 Fracture pressure Gradient 0.90 psi/FT FPG 3 Fracture pressure at the 26" Shoe 265 psi FP,~,. 4 Proposed TD of the 13-3/8" Casml~ Shoe (TVD) 1,099 Feet 0'VD) Dm 5 Pore pressure smdient 0.350 psi/Ir Pp~ 6 Maximum anticipated pore pressuxe ~. TD 385 psi 7 Mud Weight See table PPG MW 8 Gas Gradient 0.10 psi/FT GG 9 Av~m~¢ open hole size 17.50 Inches OD~ 10 Drillpip~OD 5.00 Inches . OD~ 11 Capacity of open hole by drillpipe 0.2731 BBL/Fr CAP 10 H~ght of gas eolunm in wellbore when top of gas is at th~ shoe HT Feet (TVD) Ht A~sumptions for Granit~ Point Field: All calculations assume that water ba~l mud is u~l and deea not take into account gas solubility in oil based mud. Gas bubble height in wellbore (I-It) calculation with gas bubble top at 26" shoe. FPshoe + Pgas bubble + Proud = Pmax~ 'ID FP~. + GG*Ht + .052*MW*G)r~D~.-Ht) = P~m Gas Volume (GV) calculation at 26" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in weilbore at TD. P1 v 1 = P2V2. Assume constant teml~xatum. Kick Tolerance * Pm~o m = GV * FP Mud Weight Gas Bubble Height Gas Volume (~ Shoe Kick Tolerance (PPG) (Feet) OIBI~) OIBLS) 7.0 655 179 123 , 7.2 661 180 124 7.4 666 182 125 7.6 671 183 126 7.8 676 184 127 8.0 680 '186 ' 128 8.2 684 187 128 8.4 688 188 129 8.6 691 189 130 8.8 694 190 130 , 9.0 698 190 131 9.2 700 191 132 9.4 703 192 132 9.6 706 193 133 9.8 708 193 13:3 , 10.0 711 194 134 ! 10.2 713 195 134 10.4 715 195 134 10.6 717 196 135 10.8 719 196 135 11.0 72I 197 i i KTGP54.XLS 1/9/96 Maximum Kick Tolerar ~ Calculations ~ Well: GP 54 Casing Shoe: 13-3/8" General Information Variables 1 ! 3-3/8" Casing Shoe (from RT~+B6 1,099 Feet (TVD') 2 Fracture pressure Gradient '" 0.85 psi/FT FPG 3 Fracture pressure at the 26" Shoe 934 psi 4 ProPOsed TD of the %5/8" Casing Shoe (TVD) 3,499 Feet (TVD) Dm 5 Pore pressure gradient 0.450 psi/FT PpG 6 Maximum anticipated .pore pressu, re ~' TD , 1,575. psi .Pm~y. 7 Mud Weight See table PPG MW 8 Gas Gradient 0.10 ,psi/I~. GG 90 Average open hole size 12.25 Inches ODou Dffilpipe OD 5.00 ~Inehes OD~ 11 Capacity. of open hole by dnllp~pe 0.1214 BBL/FT CAP 12 Height of gas column in wellbore when top of'~as is at the shoe I-IT Feet (TVD') Ht Assumptions for Granite Point Field: Fracture Pressure Gradient - .9 PSI/Fr. All calculations assume that water based mud is used and does not take into account gas solubility in oil based mud. Gas bubble height in wellbore IHt) calculation with gas bubble top at 13-3/8" shoe. FPshoe * Pgas bubble + Pmud = Pmax~w TI) FP~o. + GG*Ht + .052*MW*(Dm-~Itt) = Gas Volume (GV) calculation at 13-3/8" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in wellbore at TD. P 1 v 1 = P2V2. Assume constant temperature. Kick Tolerance * P~-~ ~v = GV * FP Mud Weight Gas Bubble Height Gas Volume(~Shoe KickTolerance (PPG) (Feet) (BBLS) (BBLS) 7.0 883 107 64 7.2 ~41 114 68 7.4 994 121 72 7.6 1.044 127 75 7.8 1,090 132 79 , 8.0 1.133 138 82 8.2 1,173 142 85 8.4 1,211 147 87 8.6 1,247 151 90 8.8 1,280 155 92 , 9.0 1,312 159 95 9.2 1,342 163 97 9.4 1,370 166 ~9 9.6 1,397 170 101 9.8 1,422 173 102 10.0 1,447 176 104 10.2 1,470 178 106 I0.4 1,492 181 107 · 10.6 1,513 184 109 10.8 1,533 186 110 11.0 1,552 188 112 KTGP54.XLS I/15/96 Maximum Surface Pressure Calculations Well: GP 54 Casing Size: 13'3/8" Depth Interval: 0'-3,500' Hole Size: 12.25 General Information: Anticipated Mud Weight (MW): 9.0 PPG Shoe Depth (D~o,~: 1100 MD Estimated Fracture Gradient (at the Shoe): Total Depth (Dm): 3500 MD Bottom Hole Pressure Gradient (BId?G): Gas Gradient (GG); (assumes worse case): Maximum Gas Column Height in wellbore w~hen top of gas is at the shoe (Hr): - 0.468 psi/leT 1099 TVD 0.85 psi/Ir 3499 TVD 0.45 psi/F'-r o. 10 psi/Ir 988 Feet (@ anticipated Mud Weight) Maximum Surface Pressure Calculations: The wellbore volume is determined using the height of gas column in wellbore when top of gas bubble is at the shoe- during a gas kick situation. A percentage of the gas column height (Ht), found in the Maximum Kick Tolerance Calculations, is used. Maximum Surface Pressure = Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume) MSP = Pm~m- GG*Ht - .052*MW*(DrD-Ht) MSP = 301 psi Hydrostatic Pressure at the Shoe Calculations: The greatest hydrostatic pressure at the shoe I Pshoe) is xvhen the gas bubble reaches the shoe. Assuming a constant bottom hole pressure is applied while circulating out the gas kick. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the Shoe Depth (Dshoe). Pe~ = MSP + .052*MW*D~o, Pshoe = 815 psi FPa, oe = 934 psi The pressure at the shoe (Pshoe) is less than the fracture pressure at the same shoe. Therefore the shoe integrity is sufficient to adequately handle a gas kick. Pressure Differential Across the Shoe: Pressure differential across the casing shoe = Pshoe - Maximum pore pressure at shoe DPshoe = Pshoe - Pmax ~ shoe = Pshoe - BHPG * DP shoe = 320 psi The DPshoe is less that the internal yield of the casing. Alaska Oil & Gas Cons. Comm'mion KTGP54.XLS 13-38" MSP 1/15/96 Maximum Surface Pressure Calculations Well: GP 54 Casing Size: 9-5/8" Depth Interval: 0'-12,684' Hole Size: 8.50 General Information: Anticipated Mud Weight (lvlV~: 9.0 PPG Shoe Depth (I2ht~}: 3500 MD Estimated Fracture C. madient (at the Shoe): Total Depth (D-m): 12,684 MD Bottom Hole Pressure Gradient (BI-lPG): Gas Gradient (GG); (assumes worse case): Maximum &as Column Height m wellbore when top of gas is at the shoe (I-It): 0.468 psiJFT 3499 TVD 0.85 psi/FT 9805 TVD 0.50 psi/F r 0.10 psi/FT 1,950 Feet ((~ anticipated Mud Weight) Maximum Surface PressUre Calculations: The wellbore volume is determined using the height of gas column m weilbore when top of gas bubble is at the shoe- dunag a gas kick situation. A percentage of the gas column height (I-It), fouad in the Maximum Kick Tolerance Calculations, is used. Maximum Surface Pressure = Max/mum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume) MSP = P.~m. GG*Ht - .052*MW*(Dm-Ht) MSP = 1,031 psi Hydrostatic Pressure at the Shoe Calculations: The gre~_~t_~x hydrostatic pre~sta~ at the shoe (Pshoe) is when the ga~ bubble reaches the shoe. Asmmfing a constant bottom hole pressuxe is applied while circulating out the gas kick. A comservafive estimate would be the maximum sm'fa~ pressure plus the hydrostatic pressure at the Shoe Depth (Dalme). P~ = MSP + .052*MW*Da~ Pshoe = 2,669 psi FP.,oe = 2,974 psi The pressure at the shoe (Pshoe) is less than the fractm'e pressm'e at the same shoe. Therefore the shoe integrity is sufficient to adequately handle a gas kick. Pressure Differential Across the Shoe: Pressure differential aa'oss the casing shoe = Pshoe - Maximum lX~ pressure at shoe DPShoc = Pshoe - Pmax ~ shoe = Pshee - BHPG * D~ DP shoe= 919 psi The DPshoe is less that the internal yield of the casing. KTGP54.XLS %58" MSP 119196 Maximum Kick Tolerant ~'alculations ~ Well: GP 54 Casing Shoe: 9-5/8" General Information Variable~ 1 9-5/8' Casm~ Shoe (from R~ 3,499 Feet (TVD.) D,~ 2 Fraetuxe pressure Gradient 0.85 psi/FT FPG 3 Fracture ~ at the 9-5/8" Shoe 2,974. psi FP~,, _ 4 Proposed TD of the 7' Casin~: Shoe (TVD) 9,805 F. eet ,~VD) Dm 5 Pore tnessuxe ~mdient . 0.50 psi/FT PpG 6 Maximum anticipated pore Fresstwe ~ TD 4,903 psi 7 [Mud W~i~ht , See table .PPG MW 8 Gas Cnaaient . 0.10 ?si/F'r 9 Avexa~e open hole size 8.50 Inches . OD~ 10 Drilll~ OD 5.00 Inches ODu, 11 Ca~ of open hole by drillpipe '0.0459 BBL/F~ CAP 12 Height of~gaa ~olunm, in wellbore when top of gas is at th~' sl~oe lit Feet (TVD) ,, Ht Assumpt~ona for Granit~ Point Field: Fractul~ Pr~aum Gradient = .9 PSI/F'r; and Maximum Por~ Pre~aur~ Gradient = .52 Psi/Fr. (GP 13-13; 1967} All calculations assume that water baaed mud is used and do~ not ~ into account gas solubility in oil based mud. i Gas bubble height in wellbore Ott) calculation with gas bubble top at 9-5/8" shoe. FPshoe + Pgas bubble + Proud = Pmax~ TD FP~,. + GG*Ht + .052*MW*(Dm-D.~,.-Ht) = P~.,~,~ Gas Volume (GV) calculation at 9-5/8" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in weilbore at TD. P1V1 = P2V2. Assume eonstaat tem~tm'e. Kick Tol~anc~ * P,.~ = GV * FP Mud Weight Gas Bubble Height Gas Volume (~ Shoe Kick Tolerance (PPG) (Feet) (BBLS) ~.0 1,390 64 39 7.2 1,577 72 44 7.4 1,749 80 49 7.6 1,910 88 53 7.8 2,059 94 57 · 8.0 2,!99 . 101 61 8.2 2,330 107' 65 8.4 2,453 113 68 8.6 2,568 118 71 , 8.8 2,677 123 75 9.0 2,780 128 77 9.2 2,876 132 80 9.4 2,968 136 83 9.6 3,055 140 85 ' 9.~ 3,338 , 10.0 3,216 148 9_0 10.2 3,291 151 92 10.4 3,.362 , 154 94 10.6 3,430 157 95 10.8 3,495 160 97 11.0 3,557 163 99 ! KTGP54.XLS 1/9/96 Maximum Kick Tolerance Calculations Well: GP 54 Casing Shoe: 7" General Information Variables 1 7" Casing Shoe (from RT) 9,805 Feet (TVD) D~o~ 2 Fracture pressure Gradient 0.85 psi/FT FPG 3 Fracture pressure at the 7" Shoe 8,3:}4 psi FP,~o~ 4 Proposed TD of the 4-1/2" Casing Shoe (TVD) 10,212 Feet O'VD) Dm 5 Pore pressure gradient 0.52 psi/FT PpG 6 Maximum anticipated pore pressure ~ TD 5,:}10 psi Pm~m 7 Mud Weight See table PPG MW 8 Gas Gradient 0.10 psi/FT GG 9 Average open hole size 6.00 Inches ODo. 10 Drillpipe OD :}.50 Inches OD~p 11 Capacity of open hole by drillpipe 0.02:}1 BBL/FT CAP 12 Height of gas column in wellbore when top of gas is at the shoe HT Feet (TVD) Ht Assumptions for Granite Point Field: Fracture Pressure Gradient = .9 PSI/FT; and Maximum Pore Pressure Gradient = .52 PSI/FT. (GP 1:}-1:}; 1967) Ail calculations assume that water based mud is used and does not take into account gas solubility in oil based mud. Gas bubble height in wellbore 0tt) calculation with gas bubble top at 7" shoe. FPshoe + Pgas bubble + Pmud = Pmax~ TD FP~hoc + GG*Ht + .052*MW*(Dxr~De~Ht) = Pm~m Gas Volume (GV) calculation at 7" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in wellbore at TD. P1 V1 = P2V2. Assume constant temperature. Kick Tolerance * Pm~ ~ = GV * FP Mud Weight Gas Bubblelteight Gas Volume~Shoe KickTolerance (PP~) ~eeO (BBLS) (BBLS) 7.0 12,016 277 435 7.2 11,576 267 419 7.4 11,168 258 404 7.6 10,789 249 390 7.8 10,436 241 378 8.0 10,105 233 366 8.2 9,796 226 355 8.4 9,506 219 344 8.6 9,234 213 334 8.8 8,977 207 325 9.0 8,735 201 316 9.2 8,506 196 308 9.4 8,289 191 300 9.6 8,084 186 293 9.8 7,889 182 286 10.0 7,704 178 279 10.2 7,528 174 272 10.4 7,360 170 266 10.6 7,199 166 261 10.8 7,046 162 255 11.0 6,900 159 250 KTGP54.XLS 1/9/96 Maximum Surface Pressure Calculations Well: GP 54 Casing Size: 7" Depth Interval: 0'-15,477' Hole Size: 6.00 General Information: Anticipated Mud Weight (MW): 9.0 PPG Shoe Depth (D.~: 12,684 MD Estimated Fracture C_nadient (at the Shoe): Total Depth (Dm): 15,477 MI) Bottom Hole Pressure Gradient (BHPG): Gas Gradient (GG); (assum~ worse case): Maximtun Gas Column Height m wellbore when top of gas is at the shoe (Fit): 0.468 psifr-T 9805 TVD 0.85 psi/Y'r 10212 TVD 0.52 psi/FT o. lo psi/rr 4,500 Fee~ I (@ anticipated Mud Weight) Maximum Surface Pressure Calculations: The welibore volume is detcrrni_ned using thc hmght of gas column m wellbore when top of gas bubble is at the shoe- during a gas kick situation. A percentage of the gas column height (Ht), found in the Maximum Kick Tolerance Calculations, is used. Maximum Surface Pressure = Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume) MSP = P~ro-GG*Ht - .052*MW*(Dm-Ht) MSP = 2,187 psi Hydrostatic Pressure at the Shoe Calculations: The gre~__t_~ hydrostatic pressuxe at the shoe (Pshoe) is when the gas bubble reaches the shoe. Assuming a ~t bottom hole pressure is applied while c~ out the gas kick. A conservative estimate would be the maximum surface pressure plus the hydrostatic pressure at the Shoe Depth (Dshoe). P,~ = MSP + .052*MW*D,~ Pshoe = 6,776 psi FP,a.e = 8334 psi · The pressure at the shoe (Pshoe) is less than the fractuxe pressure at the same shoe. Therefore the shoe integrity is sufficient to adequately handle a gas kick Pressure Differential Across the Shoe: Pressure differential across the casing shoe = Pshoe - Maximum pore pressure at shoe DPshoe = Pshoe - Pmax (~ shoe = Pshoe - BHPG * Dm, DP shoe = 1,677 psi The DPshoe is less that the internal yield of the casing. KTGP54.XI~ 7" MSP 1/9/96 Fracture Pressure Data Granite Point Field Platform Well Date Casing Frac Csg Shoe EMW Notes Size Gradient Depth PPG Psi/ft. TVD GPP 11-13rd 2J14/92 9-5/8' 0.96 9,966 18.4 GPP 51 ' 8/7/92 13-3/8' ' 1 3,803 19.2~ ' , ~ GPP 51 7/28/92 18-5/8" 0.87 1,010 16.81 , G?P 51 8/25/92 9-5/8" 1.05 9,592 20.21 GPP 50 5/27/92 18-5/8" 0.91 982 17.5! ,,, GPP 50 6/4/92 13-3/8" 0.84 4,208 16.2: , GPP 50 6/27/92 9-5/8~ 0.931 9,877 17.9 Anna 1 ltd 10/23/94 13-3/8' 0.891 2,976 17.2 Anna 1 ltd 11/11/94 9-5/8' 0.92! 8,750 17.7 ', 'Anna 3rd 12/10/94 9-5/8" i).75! 7,839 14.5 Anna 50 2./8/95 i8-5/8' 1.38' 1,160 26.6 ' Anna 50 2./13/95 13-3/8" 1.01 4,251 19.5 Anna 50 3/8/95 9-5/8' 0.86 9,844 16.5 , Alma 51 1/29/95 18-5/8" 1.36 1,130 26.2 Anna 51 5/15/95 13-3/8" 0.71 3,796 13.6 Anna 51 6/3195 9-5/8" 0.88 9,842 17 * · Anna 52 2.13195 18-5/8" 1.41 1,153 27 , Anna 52 3/27195 13-3/8" 0.84 3,940 16.15 Anna 52 4/15/95 9-5/8" 0.91 9,470 17,6 * Anna 7rci2 8125/95 9-5/8" 0.96 4,439 18.5 Anna 7rcL2 9/6/95 7" 0.82 9,589 15.8 Notes: All framure gradients reported have been corrected for air and water gaps. · Indicates a (FIT)-Formation Integrity Test was achigved, not actual leak off. FRACDATA.XI.3 114/96 1,000 2,000 3,000 Granite Point Field Fracture Gradient Data 4,000 5,000 6,000 7,000 8,000 9,000 10,000 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6 gneture Gradient (PSI/F~ F1LtCDAT~X:I~ 1/4/96 600 _ O O c~ - O ~3 0 _ ,, ~ 600 _ - 1200 _ UNOCAL IStructure : GRANITE POIHT Platform Well : GP54 I Field : Granlte Point Field Location : Cook Inlet, Alaska 1800 240O 3000 _ - 3600 _ 4200 _ C) 48oo _ _ 5~oo_ 6000 6600 7200 _ - 7800 _ _ 8400 _ 9000 _ 9600 <-- West Scale I : 300,00 4200 3600 3000 2400 1800 1200 600 0 600 10200_ 10800 Point Tie on End of Hold End of Build End of Hold End of Drop KOP End of Build Target End of Build Target End of Hold 'tie on 1.00 Begin Due ~'est Nudge 2.00 End Angle Build 2.00Begln Angle Drop 1.00 End of Directional Nudge KOP 5.00 10.00 15.00 20.00 25.00 35.00 40.00 45.00 50.00 EOC SURFACE LOCATION: WELL PROFILE DATA /' MD Inc Oir TVD North East Deg/lO0 2420' FNL, 1290' FWL / 0 0.00 270.00 0 0 0 0.00 . _ / 500 0.00 270.00 500 0 0 0.00 SEC. 13, TION, R12W / 800 3.00 270.00 800 - 0 -8 1.00 ~ / EOC 1200 3.00 270.00 1199 0 -29 0.00 1500 0.00 270.00 1499 0 -37 1.00 3600 0.00 270.00 3599- 0 -37 0.00 5650 51.24 207.58 5386 -760 -433 2.50 12643 51.24 207.58 9765 -5593 -2959 0.00 13118 83.50 198.87 9945 -5991 -3125 7.00 / 1 5277 83.50 198.87 10190 -8021 -3819 0.00 / 83.50 198.87 10213 -8209 -3884 0.00 15477 Cre~ted by : j .... For: M DA~IMJ Date plotted : 3-Jan-g6 Plot Ret ..... is GP54 Version ~4-. J I Coordinates are in feet reference slot ~4-9. J ,~,/ rrue Verticol Depth ...... f ...... RKB (Rig: 1~156).'J ~/ S 27.88 DEG W / 90?3' (TO TD) ***PLANE OF PROPOSAL*** / / TARGET #1 - T/ C-5 - Begin Final B & TF°~ 4 1/2 gner / TARGET #2 - B/ C-5~Fina, EOC TARGET #1 LOCATION: / _ SEC. 2~, T10N, R12W TARGET #3 / C-5 Exit~ TD MAXIMUM ANGLE 51.24 DEG TD LOCATION: 69' FNL, 2594' FEL SEC. 26, TION, R12W Top 4 TARGET ANGLE TARcET #1 - T/o-6 - Beg, ~,'~ TARGET #2 - B/ C--5 .q.c~' 83.5 D~G %~ 600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 Scele 1 ' 300.00 Vertical Section on 207.88 azimuth with reference 0.00 N, 0.00 E from slot #4-9 _ 600 " - _1200 _ _1800 _2400 _3000 (.~ - O _3600 (~ 4200 4800 J - I _5400 V -- _6000 _6600 _7200 7800 _8400 __._ ,-'ERMIT CHECKLIST FIE,,D ,, POOL GEOL AREA redrll [] serv [] ON/OFF SHORE ADMINISTk~%TION 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 drlg 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. . .Y 13. Can permit be approved before 15-day wait ....... REMARKS N N APPR OATE 14. 15. 16. 25° Conductor string provided ............... Surface casing protects all known USDWs ........ CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg . . CMT will cover all known productive horizons ...... C~sing designs adequate for C, T, B & permafrost .... Adequate t~nkage or reserve pit ............. If a re-drili'~ has a 10-403 for abndnmnt been approved. Adequate wellbore separation proposed .......... If diverter required, is it adequate ........... Drilling fluid program schematic & equip list adequate BOPEs adequate ..................... BOPE press rating adequate; test to ~QOO psig.~ N Choke manifold complies w/API RP-53 (May 84) ...... ~ N Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............. Y ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y N/ 32. Seismic analysis of shallow gas zones .......... Y//N 33. Seabed condition survey (if off-shore) ........ /~ N 34. Contact name/phone for weekly progress reports . . ./¢ . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: T~ Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * · ALASKA COMPUTING CENTER * . * ****************************** . ............................ * · ....... SCHLUMBERGER ....... * . ............................ * ****************************** COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO UNION OIL COMPANY OF CALIFORNIA G~TS PO~ WE~ ~ ~4 ~ GRANITE POINT KENA I ALASKA 50-733-20470 97048 LIS Tape ficaCicn Listing Schlumberger Alaska Computing Center 30-J~-1997 _~ : 2~ .OAGE : **** REEL H~-~ER **** SERVICE NAME : DATE . 00/00/00 ORIGIN : CSU REEL NAME : CONTINUATION # : O0 PREVIOUS REEL : COI~qENT : SCHLUMBERGER WELL SERVICES CSU TAPE **** TAPE HEA~ER **** SERVICE NAME : GP54 DATE : 97/01/20 ORIGIN . CSU TAPE NAME CONTINUATION # : O0 PREVIOUS TAPE : COIPqENT : SCHLUI4BERGER WELL SERVICES CSU TAPE **** FILE H~.2_DER FILE NAME : TOH SERVICE : VERSION : DATE : MAX REC SIZE : 8192 FILE TYPE : LAST FILE : .019 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ~£PE REPR CODE VALUE I 66 0 2 66 0 3 79 148 4 66 1 5 66 1 6 73 -528 7 65 INCH 8 73 60 9 65 .liN i1 66 55 12 68 13 66 1 14 65 .lin 15 66 73 16 66 1 D 66 0 LIS Tape ';.fication Listing Schi'~?J~er~_r Alaska Computing Center 50-JAN-199~, FAJE: ** SET TYPE - CHAN ** x\i~IE SERV UNIT SERVICE API API API API FILE NU~!B NOWB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAM? ELEM CODE (HEX) SS TOH IN 07 282 O1 0 19 1 1 2 49 8000000000 .iS TOH F/HR 07 636 21 0 19 1 1 2 49 8200000000 T~¥S TOH LBF 07 635 21 0 19 1 1 4 68 8000000000 ~£~RK TOH F 07 150 O1 0 19 1 1 2 49 8000000000 ~LI TOH IN 07 280 O1 0 19 1 1 2 49 8400000000 ii~W TOH F3 07 282 O1 0 19 1 1 2 49 8400000000 i;~Z TOH F3 07 282 O1 0 19 1 1 2 49 8400000000 SHVD TOH V 07 354 O0 0 19 1 1 2 49 9000020000 ~ TOH V 07 354 O0 0 19 1 1 2 49 9000020000 RLUUTOH CPS 07 354 02 0 19 1 1 2 49 8000020000 · L~ TOH CPS 07 354 O1 0 19 1 1 2 49 8000000000 LU TOH CPS 07 354 O1 0 19 1 1 2 49 8000000000 LS TOH CPS 07 354 O1 0 19 1 1 2 49 8000000000 LITH TOH CPS 07 354 O1 0 19 1 1 2 49 8000000000 SSI TOH CPS 07 354 02 0 19 1 1 2 49 8000000000 SS2 TOH CPS 07 354 02 0 19 1 1 2 49 8000000000 LSHV TOH V 07 354 O0 0 19 1 1 2 49 9000020000 SSHVTOH V 07 354 O0 0 19 1 1 2 49 9000020000 FFSS TOH 07 354 O0 0 19 1 1 2 49 8000020000 FFLS TOH 07 354 O0 0 19 1 1 2 49 8000020000 QRLS TOH 07 354 O1 0 19 1 1 2 49 8100000000 QRSS TOH 07 354 O1 0 19 1 1 2 49 8100000000 QLS TOH 07 354 O1 0 19 1 1 2 49 8100000000 QSS TOH 07 354 O1 0 19 1 1 2 49 8100000000 PEF TOH 07 358 O1 0 19 1 1 2 49 8402040000 S1RH TOH G/C3 07 350 02 0 19 1 1 2 49 8400000000 LSRH TOH G/C3 07 350 02 0 19 1 1 2 49 8400000000 LO-RHTOH G/C3 07 350 02 0 19 1 1 2 49 8400000000 ,VRHO TOH G/C3 07 350 02 0 19 1 1 4 68 8002040000 DALP TOH G/C3 07 350 02 0 19 1 1 4 68 8200020000 PJ~.OBTOH G/C3 07 350 02 0 19 1 1 4 68 8202040000 DRHO TOH G/C3 07 356 O1 0 19 1 1 4 68 8200000000 DPHI TOH V/V 07 890 O1 0 19 1 1 4 68 8402040000 iDQF TOH 07 000 O0 0 19 1 1 2 49 8000000000 IMQF TOH 07 000 O0 0 19 1 1 2 49 8000000000 SFBP TOH MA 07 000 O0 0 19 1 1 2 49 8000000000 I~VDB TOH 07 000 O0 0 19 1 1 2 49 8000020000 DERS TOH 07 000 O0 0 19 1 1 2 79 8000020000 IFRE TOH 07 000 O0 0 19 1 1 2 79 8000000000 CIDP TOH f~4/M 07 110 46 0 19 1 1 2 49 8000000000 CIMP TOH I4M/M 07 110 44 0 19 1 1 2 49 8000000000 IDPH TOH OH~4M 07 120 46 0 19 1 1 2 49 8000000000 iMPH TOH O~ 07 120 44 0 19 1 1 2 49 8000000000 IIRD TOH ~/M 07 000 O0 0 19 1 1 2 49 8000000000 IiXD TOH k~I/M 07 000 O0 0 19 1 1 2 49 8000000000 IIRM TOH .~4/M 07 000 O0 0 19 1 1 2 49 8000000000 iIXM TOH k~4/M 07 000 O0 0 19 1 1 2 49 8000000000 IXD TOH OHT~4 07 120 46 0 19 1 1 2 49 8000000000 IX~I TOH OHIZi¢l 07 120 44 0 19 1 1 2 49 8000000000 CILD TOH l~4/M 07 110 46 0 19 1 1 2 49 8000000000 tis Tape ification Lis~ing Schlumberger Alaska Computing Center 3£-J~¥-1997 _=:28 PAGE NAME SERV UNIT SERVICE API API API API FILE NU~B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD z~JMB SAMP ELEM CODE (HEX) CII~4 TOH [~4/M 07 110 44 0 19 1 1 2 49 8000000000 ILD TOH OH~ 07 120 46 0 19 1 1 2 49 8000000000 ILM TOH OH~ 07 120 44 0 19 1 1 2 49 8000000000 QLRA TOH 07 935 04 0 19 1 1 2 49 8000000000 CSFL TOH [~4/M 07 210 O1 0 19 1 1 2 49 8000000000 CSFA TOH [Vl~/M 07 210 O1 0 19 1 1 2 49 8000000000 SFLU TOH OH]V~4 07 220 O1 0 19 1 1 2 49 8000000000 SFLA TOH OH~4 07 222 O1 0 19 1 1 2 49 8000000000 GR TOH GAPI 07 310 O1 0 19 1 1 2 49 8400000000 STSG TOH 07 000 O0 0 19 1 1 2 79 8000000000 HTEN TOH LBF 07 000 O0 0 19 1 1 2 49 8000000000 fVZ~ESTOH OPi~4~ 07 000 O0 0 19 1 1 2 49 8000000000 ITT~4TOH DEGF 07 000 O0 0 19 1 1 2 49 8000000000 AMTE TOH DEGF 07 000 O0 0 19 1 1 2 49 8400000000 DTEM TOH DC/K 07 000 O0 0 19 1 1 2 49 8000000000 CTE~ TOH DEGF 07 660 21 0 19 1 1 2 49 9000010000 HV TOH V 07 000 O0 0 19 1 1 2 49 9000010000 SP TOH MV 07 010 O1 0 19 1 1 2 49 8800000000 ** DATA ** ** DEPTH = 14087.500 FEET ** BS.TOH 6.000 CS. TOH 1400.000 TENS. TOH CALI.TOH 3.564 IHV. TOH 0.000 ICV. TOH LHVD. TOH 1488.000 RLUU. TOH 6.910 LL. TOH LS.TOH 283.750 LITH. TOH 86.188 SS1.TOH LSHV. TOH 1488.000 SSHV. TOH 1453.000 FFSS. TOH QRLS. TOH 0.549 QRSS.TOH 0.717 QLS. TOH PEF. TOH 16.172 S1RH. TOH 2.250 LSRH. TOH NRHO. TOH 2.450 DALP. TOH 0.255 RHOB. TOH DPHI.TOH 0.121 IDQF. TOH 3.000 IMQF. TOH INDB. TOH 4.148 DERS. TOH 220 IFRE. TOH CIMP. TOH 10.523 IDPH. TOH 110.000 IMPH. TOH IIXD.TOH 3.371 IIRM. TOH 10.398 IIX~.TOH IXM. TOH 87.250 CILD.TOH 9.664 CILM. TOH ILM. TOH 91.500 QLRA.TOH -151.125 CSFL.TOH SFLU. TOH 9696.000 SFLA.TOH 9696.000 GR.TOH HTEN. TOH 262.000 I~P~ES. TOH 14.523 MTE~.TOH DTEM. TOH 0.000 CT~.TOH 191.375 HV. TOH ** DEPTH = 11841.500 FEET ** BS. TOH 6.000 CS. TOH 59.906 TENS. TOH CALI.TOH 6.305 IHV. TOH 464.500 ICV. TOH LHVD.TOH 1488.000 RLUU. TOH 3.959 LL. TOH LS.TOH 265.750 LIT~.TOH 29.688 SS1.TOH LSHV. TOH 1488.000 SSHV. TOH 1458.000 FFSS. TOH QRLS. TOH 0.694 QRSS. TOH 0.676 QLS. TOH 1545 000 0 000 148 500 238 375 -0 011 -0 095 2 395 2. 450 2.000 20 95.000 11.453 10.922 0.000 43.938 171.625 248.250 1240.000 163.875 145.500 68.375 -0.081 0.051 MARK. TOH SHVD.TOH LU. TOH SS2.TOH FFLS.TOH QSS.TOH LURH. TOH DRHO. TOH SFBP. TOH CIDP.TOH IIRD.TOH IXD.TOH ILD.TOH CSFA.TOH STSG. TOH AMTE. TOH SP.TOH MARK. TOH SHVD. TOH LU. TOH SS2.TOH FFLS.TOH QSS.TOH 50.250 1453. 000 270.500 342. 250 -0. 036 O. 026 2. 363 O. 064 545.500 9. 086 8.844 296.500 103. 375 O. 090 176 171. 625 72. 250 50.250 1458.090 240.500 121.250 0.035 -0.015 LIS Taps '~ficatien Listing Schlumberger Alaska Computing Center 30-JAN-1997 :28 PAGE: PEF. TOH 16.172 Si RH. TOH NRHO. TOH I. 598 DAL P. TOH DPHI. TOH O. 632 IDQF. TOH INDB. TOH 4.910 DERS. TOH CIMP. TOH -1 61 . 875 IDPH. TOH IIXD. TOH - 6. 723 IIRM. TOH IX~I. TOH 1950. 000 CILD. TOH ILM. TOH 1950. 000 QLRA . TOH SFLU. TOH 9696. 000 SFLA. TOH HTEN. TOH 754 . 000 I~ES. TOH DTEM. TOH O. 000 CTEM. TOH 3. 953 -2.274 O. 000 148 15.375 -161. 875 67. 125 -210. 125 9696. 000 14. 523 190.250 LSRH. TOH RHOB.TOH IMQF. TOH IFRE. TOH IMPH. TOH IIXI4. TOH CILM. TOH CSFL.TOH GR.TOH MTEM. TOH HV. TOH 2.393 1 . 608 O. 000 20 1950. 000 -364. 750 -167. 750 0.000 32. 781 169. 750 249. 375 LURH. DRHO. SFBP. CIDP. IIRD. IXD. ILD. CSFA. STSG . AMTE. SP. TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH 2.420 -0.783 545.500 65.000 60.344 1950.000 14.891 0.000 176 169.750 2.799 END OF DATA ** **** FILE T~ILER FILE NAME : TOH SERVICE : VERSION : DATE : MAX REC SIZE : 8192 FILE TYPE : LAST FILE : **** .019 **** FILE~ER **** FILE NAME : TOH .020 SERVICE : VERSION : DATE : MAX REC SIZE : 8192 FILE TYPE : LAST FILE : ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 79 148 4 66 1 5 66 1 6 73 -528 7 65 INCH 8 73 60 9 65 .1 IN 11 66 55 LIS Taps ification Lis~ing Schlumberger Alaska Computing Center 30-JAN-1997 ._, :28 PAGE: TYPE REPR CODE VALUE 12 68 13 66 1 14 65 .liN 15 66 73 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NU~B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BS TOH IN 07 282 O1 0 20 1 1 2 49 8000000000 CS TOH F/HR 07 636 21 0 20 1 1 2 49 8200000000 TENS TOH LBF 07 635 21 0 20 1 1 4 68 8000000000 MARK TOH F 07 150 O1 0 20 1 1 2 49 8000000000 CALI TOH IN 07 280 O1 0 20 1 1 2 49 8400000000 IHV TOH F3 07 282 O1 0 20 1 1 2 49 8400000000 ICV TOH F3 07 282 O1 0 20 1 1 2 49 8400000000 SHVD TOH V 07 354 O0 0 20 1 1 2 49 9000020000 LHVD TOH V 07 354 O0 0 20 1 1 2 49 9000020000 RLUUTOH CPS 07 354 02 0 20 1 1 2 49 8000020000 LL TOH CPS 07 354 O1 0 20 1 1 2 49 8000000000 LU TOH CPS 07 354 O1 0 20 1 1 2 49 8000000000 LS TOH CPS 07 354 O1 0 20 1 1 2 49 8000000000 LITH TOH CPS 07 354 O1 0 20 1 1 2 49 8000000000 SSI TOH CPS 07 354 02 0 20 1 1 2 49 8000000000 SS2 TOH CPS 07 354 02 0 20 1 1 2 49 8000000000 LSHV TOH V 07 354 O0 0 20 1 1 2 49 9000020000 SSHVTOH V 07 354 O0 0 20 1 1 2 49 9000020000 FFSS TOH 07 354 O0 0 20 1 1 2 49 8000020000 FFLS TOH 07 354 O0 0 20 1 1 2 49 8000020000 QRLS TOH 07 354 O1 0 20 1 1 2 49 8100000000 QRSS TOH 07 354 O1 0 20 1 1 2 49 8100000000 QLS TOH 07 354 O1 0 20 1 1 2 49 8100000000 QSS TOH 07 354 O1 0 20 1 1 2 49 8100000000 PEF TOH 07 358 O1 0 20 1 1 2 49 8402040000 S1RH TOH G/C3 07 350 02 0 20 1 1 2 49 8400000000 LSRH TOH G/C3 07 350 02 0 20 1 1 2 49 8400000000 LURHTOH G/C3 07 350 02 0 20 1 1 2 49 8400000000 NRHO TOH G/C3 07 350 02 0 20 1 1 4 68 8002040000 DALP TOH G/C3 07 350 02 0 20 1 1 4 68 8200020000 RHOB TOH G/C3 07 350 02 0 20 1 1 4 68 8202040000 DRHO TOH G/C3 07 356 O1 0 20 1 1 4 68 8200000000 DPHI TOH V/V 07 890 O1 0 20 1 1 4 68 8402040000 IDQF TOH 07 000 O0 0 20 1 1 2 49 8000000000 IMQF TOH 07 000 O0 0 20 1 1 2 49 8000000000 SFBP TOH MA 07 000 O0 0 20 1 1 2 49 8000000000 IN-DB TOH 07 000 O0 0 20 1 1 2 49 8000020000 DERS TOH 07 000 O0 0 20 1 1 2 79 8000020000 IFRE TOH 07 000 O0 0 20 1 1 2 79 8000000000 LIS Tape ficacicn Listing Schlumberger Alaska Computing Center . . 30-JAN-1997 _ .28 NAME SERV UNIT SERVICE API API API API FILE NL'?d~B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~B SAMP ELE~! CODE (HEX) CIDP TOH MM/M 07 110 46 0 20 1 1 2 49 8000000000 CIMP TOH F~4/M 07 110 44 0 20 1 1 2 49 8000000000 IDPH TOH OH~I 07 120 46 0 20 1 1 2 49 8000000000 IMPH TOH 0~94 07 120 44 0 20 1 1 2 49 8000000000 IIRD TOH ~4/M 07 000 O0 0 20 1 1 2 49 8000000000 IIXD TOH ~94/M 07 000 O0 0 20 1 1 2 49 8000000000 IIRM TOH ~4~I/M 07 000 O0 0 20 1 1 2 49 8000000000 IIXM TOH I~4/M 07 000 O0 0 20 1 1 2 49 8000000000 IXD TOH OH~V~f 07 120 46 0 20 1 1 2 49 8000000000 IXM TOH OPR4~ 07 120 44 0 20 1 1 2 49 8000000000 CILD TOH I4~/M 07 110 46 0 20 1 1 2 49 8000000000 CILM TOH F~f/M 07 110 44 0 20 1 1 2 49 8000000000 ILD TOH OHS~I 07 120 46 0 20 1 1 2 49 8000000000 ILM TOH OH~M 07 120 44 0 20 1 1 2 49 8000000000 QLRA TOH 07 935 04 0 20 1 1 2 49 8000000000 CSFL TOH ~i~I/M 07 210 O1 0 20 1 1 2 49 8000000000 CSFA TOH 14PI/M 07 210 O1 0 20 1 1 2 49 8000000000 SFLU TOH OH~4~ 07 220 O1 0 20 1 1 2 49 8000000000 SFLA TOH OH~4~ 07 222 O1 0 20 1 1 2 49 8000000000 GR TOH GAPI 07 310 O1 0 20 1 1 2 49 8400000000 STSG TOH 07 000 O0 0 20 1 1 2 79 8000000000 HTEN TOH LBF 07 000 O0 0 20 1 1 2 49 8000000000 FIRES TOH OPfMM 07 000 O0 0 20 1 1 2 49 8000000000 MTEMTOH DEGF 07 000 O0 0 20 1 1 2 49 8000000000 AMTE TOH DEGF 07 000 O0 0 20 1 1 2 49 8400000000 DT~M TOH DC/K 07 000 O0 0 20 1 1 2 49 8000000000 CT~ TOH DEGF 07 660 21 0 20 1 1 2 49 9000010000 HV TOH V 07 000 O0 0 20 1 1 2 49 9000010000 SP TOH MV 07 010 O1 0 20 1 1 2 49 8800000000 ** DATA ** BS.TOH CALI.TOH LHVD.TOH LS.TOH LSHV. TOH QRLS.TOH PEF. TOH NRHO. TOH DPHI.TOH INDB.TOH CIMP. TOH IIXD. TOH IX~.TOH ILM. TOH SFLU. TOH ** DEPTH = 14083.500 FEET ** 6.000 6.305 1488 000 279 500 1488 000 0 619 16 172 2 575 0 372 4 137 10 117 3 105 84 250 95 125 9696 000 CS.TOH 911.000 TENS.TOH 1240.000 MARK. TOH IHV. TOH 0.000 ICV. TOH 0.000 SHVD. TOH RLUU. TOH 3.959 LL.TOH 153.250 LU. TOH LITH. TOH 44.344 SSl. TOH 126.938 SS2.TOH SSHV. TOH 1453.000 FFSS. TOH 0.047 FFLS. TOH QRSS.TOH 0.718 QLS.TOH -0.025 QSS. TOH S1RH. TOH 3.102 LSRH. TOH 2.381 LURH. TOH DALP. TOH -1.297 RHOB. TOH 2.037 DRHO.TOH IDQF. TOH 3.000 IMQF. TOH 2.000 SFBP. TOH DERS.TOH 44 IFRE. TOH 20 CIDP.TOH IDPH. TOH 116.875 IMPH. TOH 98.750 IIRD. TOH IIRM. TOH 10.008 II3C4. TOH 11.867 IXD. TOH CILD. TOH 9.102 CILW. TOH 10.500 ILD. TOH QLRA.TOH -149.250 CSFL.TOH 0.000 CSFA. TOH SFLA.TOH 9696.000 GR.TOH 33.875 STSG.TOH 50.250 1453.000 252.375 196.500 -0.039 0.027 2.396 -0.338 545.500 8.555 8.328 321.750 109.813 0.000 176 LIS Tape ifica~ion Listing Schlumberger Alaska Computing Center 30-JAN-1997 ~o:28 PA GE: HTEN. TOH 754.000 MRES.TOH DTEM. TOH 0.000 CTEM. TOH BS.TOH CALI.TOH LHVD. TOH LS.TOH LSHV. TOH QRLS. TOH PEF. TOH NRHO. TOH DPHI.TOH INDB.TOH CIMP. TOH IIXD. TOH IXM. TOH ILM. TOH SFLU. TOH HTEN. TOH DTEM. TOH ** DEPTH = 13769. 000 FEET 6.000 6. 043 1488. 000 282. 250 1488. 000 0.559 3. 195 2. 445 0.129 4. 156 10 977 3 584 88 063 95 188 9696 000 518 000 0 000 CS.TOH IHV. TOH RLUU. TOH LITH. TOH SSHV. TOH QRSS.TOH S1RH. TOH DALP. TOH IDQF. TOH DERS.TOH IDPH. TOH IIRM. TOH CILD.TOH QLRA.TOH SFLA.TOH MRES. TOH CTEM. TOH 14.523 MTEM. TOH 190.250 HV. TOH 1021 500 63 344 4 184 85 438 1453 000 0 747 2 281 0 094 0 000 52 121.063 10.000 8.805 -148.250 9696.000 14.523 191.500 TENS.TOH ICV. TOH LL. TOH SS1.TOH FFSS. TOH QLS.TOH LSRH. TOH RHOB. TOH IMQF. TOH IFRE. TOH IMPH. TOH IIXM. TOH CILM. TOH CSFL.TOH GR.TOH MTEM. TOH HV. TOH 169."50 249.3?5 1640.300 21.172 149.!25 233.250 0.083 -0.084 2.396 2.436 0.000 20 91.063 11.352 10.500 0.000 61.031 172.000 249.375 A~FFE. TOH SP. TOH MARK. TOH SHVD. TOH LU. TOH SS2.TOH FFLS. TOH QSS. TOH LURH. TOH DRHO. TOH SFBP. TOH CIDP. TOH IIRD. TOH IXD. TOH ILD. TOH CSFA. TOH STSG. TOH AMTE. TOH SP. TOH 169.750 2.799 71.313 1453.000 266.500 322.500 -0. 017 O. 056 2. 369 0.048 545.000 8.258 8.016 278.750 113.500 0.000 176 172.000 58.156 ** END OF DATA ** * * * * FILE TRAILER FILE NAME : TOH SERVICE : VERSION : DATE : MAX REC SIZE : 8192 FILE TYPE : LAST FILE : .020 **** FILE HEADER **** FILE NAME : TOH .022 SERVICE : VERSION : DATE : MAX REC SIZE : 8192 FILE TYPE : .LAST FILE : LIS Tape fication Listing Schlumberg=£ Alaska Computing Ce.-.--er 30-JAN-1997 PAGE: ** DATA FORMAT SPECIFICATION RSCORD ** ** SET TYPE - 64EB ** TYPE REPR CCEE VALUE 1 66 0 2 66 0 3 79 146 4 66 1 5 66 1 6 73 906 7 65 INCH 8 73 60 9 65 .liN 11 66 56 12 68 13 66 1 14 65 .liN 15 66 73 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG ~YPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) CS TOH F/HR 07 636 21 0 22 1 1 2 49 4200000000 TENS TOH LBF 07 635 21 0 22 1 1 4 68 4000000000 MARK TOH F 07 150 O1 0 22 1 1 2 49 4000000000 CALI TOH IN 07 280 O1 0 22 1 1 2 49 4400000000 IHV TOH F3 07 282 O1 0 22 1 1 2 49 4400000000 ICV TOH F3 07 282 O1 0 22 1 1 2 49 4400000000 SHVD TOH V 07 354 O0 0 22 1 1 2 49 5000020000 LHVD TOH V 07 354 O0 0 22 1 1 2 49 5000020000 RLUUTOH CPS 07 354 02 0 22 1 1 2 49 4000020000 LL TOH CPS 07 354 O1 0 22 1 1 2 49 4000000000 LU TOH CPS 07 354 O1 0 22 1 1 2 49 4000000000 LS TOH CPS 07 354 O1 0 22 1 1 2 49 4000000000 LITH TOH CPS 07 354 O1 0 22 1 1 2 49 4000000000 SSI TOM CPS 07 354 02 0 22 1 1 2 49 4000000000 SS2 TOH CPS 07 354 02 0 22 1 1 2 49 4000000000 LSHV TOH V 07 354 O0 0 22 1 1 2 49 5000020000 SSHVTOH V 07 354 O0 0 22 1 1 2 49 5000020000 FFSS TOH 07 354 O0 0 22 1 1 2 49 4000020000 FFLS TOH 07 354 O0 0 22 1 1 2 49 4000020000 QRLS TOH 07 354 O1 0 22 1 1 2 49 4100000000 QRSS TOH 07 354 O1 0 22 1 1 2 49 4100000000 QLS TOH 07 354 O1 0 22 1 1 2 49 4100000000 QSS TOH 07 354 O1 0 22 1 1 2 49 4100000000 PEF TOH 07 358 O1 0 22 1 1 2 49 4402040000 S1RH TOH G/C3 07 350 02 0 22 1 1 2 49 4400000000 LSRH TOH G/C3 07 350 02 0 22 1 1 2 49 4400000000 LIS Tap~ ification Listing Schlumberger Alaska Computing Center 30-JAN-1997 _z:28 PA GE: NAME SERV ~IT SERVICE API API API API FiLE NL~.:B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD N[~.--r~ S~.P ELEM CODE (HEXj LURH TOH G/C3 07 350 02 0 22 1 1 2 49 4400009000 NRHO TOH G/C3 07 350 02 0 22 1 1 4 68 4002049000 DALP TOH G/C3 07 350 02 0 22 1 1 4 68 4200020000 RHOB TOH G/C3 07 350 02 0 2£ 1 1 4 68 4202049000 DRHO TOH G/C3 07 356 O1 0 22 1 1 4 68 42000~900 DPHI TOH V/V 07 890 O1 0 22 1 1 4 68 4402040000 IDQF TOH 07 000 O0 0 22 1 1 2 49 4000090000 IMQF TOH 07 000 O0 0 22 1 1 2 49 4000000000 SFBP TOH MA 07 000 O0 0 22 1 1 2 49 4000000000 INDB TOH 07 000 O0 0 22 1 1 2 49 4000020000 DERS TOH 07 000 O0 0 22 1 1 2 79 4000020000 IFRE TOH 07 000 O0 0 22 1 1 2 79 4000009000 CIDP TOH t4~/M 07 110 46 0 22 1 1 2 49 4000000000 CIMP TOH ~4~/M 07 110 44 0 22 1 1 2 49 4000000000 IDPH TOH OH~I 07 120 46 0 22 1 1 2 49 4000000000 IMPH TOH 0H2~4 07 120 44 0 22 1 1 2 49 4000000000 IIRD TOH I~4/M 07 000 O0 0 22 1 1 2 49 4000000000 IIXD TOH I~I/M 07 000 O0 0 22 1 1 2 49 4000000000 IIRM TOH I~I/M 07 000 O0 0 22 1 1 2 49 4000000000 IIX~I TOH I~I/M 07 000 O0 0 22 1 1 2 49 40000~000 IXD TOH OH~4~ 07 120 46 0 22 1 1 2 49 4000090000 I~ TOH 0H7~4 07 120 44 0 22 1 1 2 49 4000000000 CILD TOH I~J4/M 07 110 46 0 22 1 1 2 49 4000000000 CILM TOH 14~/M 07 110 44 0 22 1 1 2 49 4000000000 ILD TOH OHF~4 07 120 46 0 22 1 1 2 49 4000000000 ILM TOH OH~4 07 120 44 0 22 1 1 2 49 4000050000 QLRA TOH 07 935 04 0 22 1 1 2 49 40000~0000 CSFL TOH I4~/M 07 210 O1 0 22 1 1 2 49 4000000000 CSFA TOH I~4/M 07 210 O! 0 22 1 1 2 49 4000000000 SFLU TOH OH~4~ 07 220 O1 0 22 i 1 2 49 4000000000 SFLA TOH OFB~4 07 222 O1 0 22 1 1 2 49 4000000000 GR TOH GAPI 07 310 O1 0 22 1 1 2 49 4400000000 STSG TOH 07 000 O0 0 22 1 1 2 79 4000000000 HTEN TOH LBF 07 000 O0 0 22 1 1 2 49 4000090000 14~ES TOH 0H7~4 07 000 O0 0 22 1 1 2 49 4000000000 MTE~ITOH DEGF 07 000 O0 0 22 1 1 2 49 4000000000 AMTE TOH DEGF 07 000 O0 0 22 1 1 2 49 4400090000 DTE~I TOH DC/K 07 000 O0 0 22 1 1 2 49 4000090000 CTE~I TOH DEGF 07 660 21 0 22 1 1 2 49 5000010000 HV TOH V 07 000 O0 0 22 1 1 2 49 5000010000 SP TOH MV 07 010 O1 0 22 1 1 2 49 4800000000 ** DATA ** ** DEPTH = 13976.500 FEET ** LIS Tape ficarion Listing Schlumberger Alaska Computing Center 30-JAN-1997 .J :28 PAGE: CS.TOH 1654.000 TENS. TOH IHV. TOH 0.000 ICV. TOH RLUU. TOH 7.980 LL.TOH LITH. TOH 115.063 SS1.TOH SSHV. TOH 1452.000 FFSS.TOH QRSS. TOH 0.795 QLS.TOH S1RH. TOH 1.805 LSRH. TOH DALP. TOH 0.500 RHOB.TOH IDQF. TOH 3.000 IMQF. TOH DERS.TOH 172 IFRE. TOH IDPH. TOH 146.750 IMPH. TOH IIRM. TOH 8.688 IIXI4. TOH CILD. TOH 7.266 CILM. TOH QLRA.TOH -142.375 CSFL.TOH SFLA.TOH 9696.000 GR.TOH ~I~ES.TOH 13.492 MTEM. TOH CTEM. TOH 186.125 HV. TOH ** DEPTH = 11853.500 FEET CS.TOH 942.000 TENS.TOH IHV. TOH 147.250 ICV. TOH RLUU. TOH 5.758 LL.TOH LITH. TOH 36.938 SS1.TOH SSHV. TOH 1460.000 FFSS.TOH QRSS.TOH 1.095 QLS.TOH S1RH. TOH 2.172 LSRH. TOH DALP. TOH -0.688 RHOB.TOH IDQF. TOH 0.000 IMQF. TOH DERS.TOH 212 IFRE. TOH IDPH. TOH 41.563 IMPH. TOH IIRM. TOH 9.617 IIXM. TOH CILD. TOH 25.250 CILM. TOH QLRA. TOH -180.375 CSFL.TOH SFLA.TOH 9696.000 GR.TOH I4~ES.TOH 12.461 ITTEM. TOH CTEM. TOH 183.750 HV. TOH 835.000 M~K. TOH 0.000 S:~/D.TOH 250.500 LU. TOH 296.500 SS2.TOH -0.030 FFLS.TOH -0.062 ~SS.TOH 2.148 LS~H. TOH 2.327 ~P~O.TOH 2.000 SFBP. TOH 20 CIDP. TOH 113.813 IIRD.TOH 10.977 iXD.TOH 9.117 ILD. TOH 0.000 CSFA.TOH 41.875 STSG.TOH 166.125 ~.~TE. TOH 249.375 SP. TOH 140.000 I~_~K. TOH 0.000 SHVD. TOH 162.000 LU. TOH 245.125 SS2.TOH 0.058 FFLS.TOH -0.083 QSS. TOH 2.326 LtrRH. TOH 2.332 ERHO. TOH 0.000 SFBP. TOH 20 CIDP. TOH 102.813 IIRD. TOH -96.250 IXD.TOH 10.094 ILD. TOH 0.000 CSFA.TOH 43.969 STSG. TOH 161.500 P_~TE. TOH 245.875 SP. TOH 10.750 1452.000 430.250 393.000 0.051 0.104 2.143 O. 187 546.500 6.809 6.648 337.000 137.625 0.000 176 166.125 61.938 10.750 1460 000 288 750 235 875 -0 080 0 404 2 332 0 013 546 500 24047 22 984 10766 39 594 0.000 176 161.500 10.953 CALI.TOH LHVD. TOH LS.TOH LSHV. TOH QRLS.TOH PEF. TOH NRHO. TOH DPHI.TOH INDB. TOH CIMP. TOH IIXD.TOH IXM. TOH ILM. TOH SFLU. TOH HTEN. TOH DTt~4. TOH CALI.TOH LHVD. TOH LS.TOH LSHV. TOH QRLS.TOH PEF. TOH NRHO. TOH DPHI.TOH INDB.TOH CIMP. TOH IIXD.TOH IX~4. TOH ILM. TOH SFLU. TOH HTEN. TOH DTEM. TOH 3.564 1486.000 465.750 1486.000 O. 582 3. 973 2. 327 0.196 4.148 8.781 2.965 91.000 109.563 9696.000 418.000 0.000 3.564 1491.000 306.500 1491.000 0.561 15.711 2. 363 O. 193 4. 816 9. 719 92.813 1950.000 99.000 9696.000 466.000 0.000 ** END OF DATA ** **** FILE TRAILER FILE NAME : TOH SERVICE : VERSION : DATE : MAX REC SIZE : 8192 FILE TYPE : LAST FILE **** .022 LIS Tape ification Listing Schlumberger Alaska Computing Center 30-JAIV~i997 15:28 PAGE: **** TAPE TRAILER **** SERVICE NAME : GP54 DATE : 97/01/20 ORIGIN : CSU TAPE NAME : CONTINUATION # : O0 PREVIOUS TAPE : COFkJENT : SCHLUMBERGER WELL SERVICES CSU TAPE **** REEL TRAILER **** SERVICE NAME : DATE : 00/00/00 ORIGIN : CSU REEL NAME : CONTINUATION # : O0 PREVIOUS REEL : COI4~ENT : SCHLUMBERGER WELL SERVICES CSU TAPE
