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Home My WebLink About196-014DSR-4/2/2020SFD 4/2/2020 xG 4Itq/'14e Pf- 253 Regg, James B (CED) 1cq�01" From: Regg, James B (CED) Sent: Thursday, June 20, 2019 3:46 PM To: Bob Mize - (C) Subject: RE: [EXTERNAL] RE: AOGCC Test Witness Notification Request: BOPE, Rig 404, GP -53, Granite Point Platform Granite Pt 53 PTD 1960140; Sundry 319-088 Requirement to test BOPE (due 6/21) is waived unless the plug verification tag/test fails and well will be reentered. Jim Regg Supervisor, Inspections AOGCC 333 W.7 1h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.reaa(aalaska.eov. From: Bob Mize - (C) <bmize@hilcorp.com> Sent: Thursday, June 20, 2019 3:28 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: [EXTERNAL] RE: AOGCC Test Witness Notification Request: BOPE, Rig 404, GP -53, Granite Point Platform Jim, We will be out of the hole ready to pick up our cement stinger by 8:00 tonight. That should put us in the hole and ready to spot our balanced plug in the early morning hours tomorrow. Estimating cement in place (4547' to 4200' , 9-5/8" casing shoe@ 4551') and waiting on cement around 10:00-11:00 tomorrow morning. Should have casing tested and pulling out of hole laying down pipe around 1:30 am the morning of Saturday the 22nd At this time we have fog and the choppers are not flying so that may have an impact on our timing if we are not able to get the cementers out to us. Bob Mize Granite Point Platform (907) 776-6658 or 6659 Office (907) 529-0151 Cell From: Regg, lames B (CED) [mailto:iim.reg alaska.gov] Sent: Wednesday, June 19, 2019 10:13 AM To: Bob Mize - (C) <bmize@hilcorp.com> Subject: [EXTERNAL] RE: AOGCC Test Witness Notification Request: BOPE, Rig 404, GP -53, Granite Point Platform Thanks. Please give us an update with the status tomorrow afternoon/early evening. Jim Regg Supervisor, Inspections AOGCC 333 W.70 Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.re¢a@alaska.Qov. From: Bob Mize <noreply@formresponse.com> Sent: Wednesday, June 19, 2019 9:33 AM To: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bay@alasl<a.gov> Subject: AOGCC Test Witness Notification Request: BOPE, Rig 404, GP -53, Granite Point Platform Question Answer Type of Test Requested: BOPE Requested Time for 06-21-2019 6:00 PM Inspection Location Rig 404, GP -53, Granite Point Platform Name Bob Mize E-mail bmize@hilcorp.com Phone Number (907) 776-6658 Company Hilcorp We are laying down 7" casing. Will have a scraper run, cmt job, csg Other Information: test and nipple down. We may be done before test is due. Submission ID: 4367747821313893267 F - x O (L w W Z O F U LU a N Z T Od 0 (D O a) > a) c c > O O U) a) a O U a E a -o aa, N uNi -o n o a N m o�) > o- 3 m -- E a w a U m m m= C C a C C7> Qa o a o)> o N Eaa a) -)Y c o).a- -o ma io 0 0 3 (1)@ .o c c m a B O LL a` n Ir¢ m U U i o f z v AAeeeA��eee��eeeee (U _ ooN� w > H g O O'- -O i� N O ° ` m Y C c a) J C c c U) (1) in c LL 0 — c.am N mf N a>uo o o > _ c 4t N m a> m m 3 o Q N m O c Ol N ❑ U) -UU�T U ED O ) U a)COO O LN m o U)❑O N E (D O OO N O aO �U a C ❑w)aC7 QU(If H Yam C9=Y rn m o w E <o m co Q M CL O O O O UJU 0 0 N O V U Z cL U o z E Q c o c O a U m CP � Q _ m d O O = a N 0 �m m N N C w 0" E m o o N N m m> > O j N> O N a a a N E 0 U C ~> m o- a C Y Y 0� of y N c_ >( m Z O C O a V U Y0 ¢dminv2F-=2LL0LLc) U) O LU Z a J J LU U N S Mal Cl) W z 0 LL L) U THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Point 53 Permit to Drill Number: 196-014 Sundry Number: 319-088 Dear Mr. Golis: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.oloska.gov Enclosed is the approved application for the 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, 42f� Daniel T. Seamount, Jr. Commissioner �� DATED this J day of March, 2019. 0DN1S4-'' MA 0 51019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED FEB 2 5 2019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill P1 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service Q 196-014 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20471-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ Granite Point 53 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018761 . D l%Jz 7 O`' y 41 Granite Point Field / Middle Kenai Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 16,657 11,071 14,530 10,735 1,483 psi 14,530 & 15,112 N/A Casing Length Size MD TVD Burst Collapse Structural 229' 33" 229' 229' Conductor 294' 26" 294' 294' Surface 1,031' 13-3/8" 1,031' 1,031' 3,450 psi 1,950 psi Intermediate 4,551' 9-5/8" 4,551' 4,089' 6,870 psi 4,760 psi Production 13,323' 7" 13,323' 10,472' 8,160 psi 7,020 psi Liner 3,725' 51. 16,634' 1 11,065' 8,290 psi 7,250 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13,339 - 14,500 10,479 - 10,730 3-1/2" 19.2 / L-80 12,970 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Halliburton VLT Versatrieve Packer & N/A 12,900 (MD) 10,259 (TVD) & N/A 12. Attachments: Proposal Summary Q Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑✓ ' 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/15/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Michael Quick Authorized Title: Operations Manager Contact Email: m nick hiloor .Com Contact Phone: (907) 777-8442 Authorized Signature: �-�l� � Q�v Date: 2-/ �' � � 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: vlq.. Plug Integrity I/ BOP Test 0/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: * 3sov �$ BC) PE . J�S1— /4 lf: % (4c e ��, p r o rc.Q Zo .4A- A-Post X Io ,,f l�`t % PostInitial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes No Subsequent Form Required: RBDMS't'MAR 0 5 2019 ❑ APPROVED BY / l Approved bye)/-W y: COMMISSIONER THE COMMISSION Date. .J`5 J J 1 J 3'y r1 /�,�(�y� �� R I Submit Form and V` -)' Form 10-403 Revised 4!2017 Approv application Is v fAr T2�rr h o he of approval yttachment; i , Duplicate / K Hi1wrp Alaska, LLC Well Work Prognosis Well: GP 53 Date: 02/12/2019 Well Name: GRANITE PT FIELD 53 (GP 53) API Number: 50-733-20471-00 Current Status: Shut In —Water Injector Leg: Leg #4 Estimated Start Date: March 15, 2019 Rig: HAK 404_) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Monitor well to ensure it is static. Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 196-014 First Call Engineer: Mike Quick (907) 777-8442 (0) (907) 317-2969 (M) Second Call Engineer: Dan Marlowe 1 (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 4,354 psi @ 10,221' TVD 0.426 lbs/ft (8.2 ppg) based on 6/2013 SIBHP Maximum Expected BHP: 4,354 psi @ 10,221' TVD 0.4261bs/ft (8.2 ppg) based on 6/2013 SIBHP Maximum Potential surface Pressure: 1,483 psi Using longterm shut in pressures of 0 psi tubing, 0 psi casing, 480 psi CA at 4550' TVD, less 0.1 psi/ft gradient per 20AAC25.280(b)(4) Brief Well Summary GP 53 is a shut in water injector, injecting into the Tyonek C sands. Well was drilled and completed in 1997, and converted to a water injector in 1999. GP 53 has been shut in since December 2004, due to loss of the ability to inject into the well. This well also has a history of tubing x IA communication. The workover will prepare the well for a side track. k/ Last Casing Test: 11/8/2000 2600 psig MIT IA on 7" casing. While injecting under an approved AOGCC waiver, the IA pressure was held at +/-4000 psi (equal to the tubing pressure) during water injection, through 2004. Procedure: Phase I 1. MIRU Rig. 2. Monitor well to ensure it is static. FIW will be circulated as necessary to balance well, BOP's will be closed as needed to circulate the well. 3. ND Wellhead. 4. NU BOP and test to 250psi low/3,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). S. Monitor well to ensure it is static. 6. Pick up 3-1/2" tubing hanger (may require 100,000 lbs to break shear pins) and pull seals out 3 of packer seal bore. Rig Up Hilcorp Casing Jacks if needed to pull tubing hanger. Y L, 7. Rig up cementers. Plug #1: Spot balance cement plug from +/- 12,950' to 12,450' with +/- ,3 (L 18 b Is of Class G, slowly pull out of plug with tubing to +/-12,000' and circulate clean. 8. WOC 12 hours and RIH to tag top of cement at +/- 12,450'. 9. 10. . Pressure Test plug toS<i)'si for 30 minutes. POOH. Ot POOH and L/E 3-1/2" ing. Cub g 11. Pick up workstring and RIH with bit and 7" casing scraper to +/- 5000'. POOH (yo µ RIH and Set at 13. RIH with casin12. g cutter and d cut 7" casing at +/-4800'. �utT 14. Circulate KWF down 7" casing taking returns from the 9-5/8" casing. (Punch 7" casing if needed to obtain adequate circulation rates) 7' 1_ 0 3 8 z ��/ C-7" i Well Work Prognosis Z� f'P r.. Well: GP 53 Hik.q punka cm = 3 �L %bS Date: 02/12/2019 15. POOH with 7" casing from +/-4800'; casing jacks may be utilized if needed to move casing. 16. RIH with cement stinger and spot a balanced kick off cement plug from +/-4800' to +/-4200' (+/- 45 bbl of Class G cement). 17. WOC a minimum of 12 hours. Tag TOC at +/-4200'. 18. Pressure test 9-5/8" to 1500 psi for 30 minutes, chart test. 19. ND BOPE and NU dry hole tree and test. 20. Rig down and move HAK 404 off location 21. Suspend operations until drilling rig moves on location. 'Remaining Procedure to be included on the Permit to Drill for the sidetrack' Phase 11 D�� 'Itt' General sequence of operations pertaining to drilling procedure: (informational only) 22. Resume operations with drilling rig. 23. MIRU drilling rig. 24. Monitor well to ensure it is static. 25. ND Wellhead, NU BOP and test to 250psi low/3,500psi high. (Note in advance of test to allow them to witness test). 26. PU 8-1/2" Sidetrack BHA and RIH to TOC. 27. Swap well to drilling fluid. 28. Kickoff cement clue into new formation. drill 20' of new hole. 29. Perform FIT. 30. Drill 8-1/2" hole per directional plan. 31. Run/Cement/ and cleanout 7" casing. 32. Swap to completion sundry. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current 4. BOP Drawing — HAK 404 5. Fluid Flow Diagrams— HAK 404 6. RWO Sundry Revision Change Form Notify AOGCC 48 hours•` L nf RKB to MLLW 114.75'; RKB to Mudline =189.75' PBTD: 14,539 TD- 16,657 Granite Point Field Well: GP 53 SCHEMATIC PTD:Last 96 0114 d: 08/29/1997 API: 50-733-20471-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 33" Outside Driven Conductor Welded 14,500' 47' 229' 26" Inside Driven Conductor Welded 14,590' 47' 294' 13-3/8" 68 K-55 BTC 12.415" 47' 1,031' 12,889' 47 L-80 BTC 8.681" 46' 73' 9-5/8" 53.5 P-110 BTC 8.535" 73' 4,551' 12,913' 29 P-110 TKC-BTC 6.184" 45' 6,989' 7„ 29 L-80 TKC-BTC 6.184" 6,989' 13,323' 5" 15 L-80 SC-TKC-BTC 1 4.408" 12,909' 16,634' TUBING DETAIL 3-1/2" 9.2 L-80 SC -BTC 2.992' 43' 12,914' 3-1/2" 9.2 L-80 STL li 2.992" 12,914' 12,970' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 1 43.44' 43.44' 13,339' 14,500' Kvaerner Tubing Hanger(ABTC-4S Up X STDVAM OWN) 2 47.69' 47.69' C-5 14,590' STD VAM x Buttress Pup Jt 3 12,857' 10,236' 2.813" 3.500" HES "X" Nipple 16,400' 12,889' 10,253' 2.992" 4.270" HES Straight Slot Locator 12,900' 10,259' 2.970" 3.850" HES Seal Assembly (13.12') (stabbed through packer) 4 12,913' 10,267' 2.970" 3.850" XO to 3.5" STL 12,970' 1 10,298' 2.970" 1 3.530" 1 Mule Shoe Guide(stabbed through packer) 4 12,906' 10,263' 3.880" 3.880" 3.880" 4.770" 5.900" 6.000" HES Seal Bore Extension Bottom Sub Halliburton VLT Versatrieve Packer 5 14,530' 10,735' EZSV Cement Retainer 6 15,112' 10,801' EZ5V Cement Retainer PERFORATION DETAIL .one Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C-5 13,339' 14,500' 10,479' 10,730' 1,161' 08/15/97 Existing Interval C-5 14,590' 14,595' 10,743' 10,744' 5' 08/14/97 Squeezed C-5 15,250' 16,400' 10,817' 11,020' 1,650' 08/04/97 Squeezed Updated By: JLL 02/07/19 . ff flilwr0 Alaska, LLC RKB to MLLW 114.75; RKB to ktdlim =189.75 33" 26' 1}3/8" TOC@ Wt Grade 11,1w ID Top Btm 33" c . Pi Welded Top (TVD) 47' 229' 26" Inside Driven Conductor Welded 13,339' 47' 294' 13-3/8" 68 K-55 BTC 12.415" 47' 1,031' 14,595' 47 L-80 BTC 8.681" 46' 73' 9 5/8 53.5 P-110 Er, 8.535" 73' 4,551' 08/04/97 29 P-110 TKC-BTC 6.184" 45' 6,989' 7„ 29 L-80 TKC-BTC 6.184" 6,989' 13,323' 5" 15 L-80 SC-TKC-BTC 4.408" 12,909' 16,634' 14,530' 10,735' EZSV Cement Retainer 6 15,112' 10,801' 0BP# 48W PROPOSED SCHEMATIC Granite Point Field Well: GP 53 Last Completed: 08/29/1997 PTD: 196-014 API: 50-733-20471-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 33" Outside Driven Conductor Welded Top (TVD) 47' 229' 26" Inside Driven Conductor Welded 13,339' 47' 294' 13-3/8" 68 K-55 BTC 12.415" 47' 1,031' 14,595' 47 L-80 BTC 8.681" 46' 73' 9 5/8 53.5 P-110 BTC 8.535" 73' 4,551' 08/04/97 29 P-110 TKC-BTC 6.184" 45' 6,989' 7„ 29 L-80 TKC-BTC 6.184" 6,989' 13,323' 5" 15 L-80 SC-TKC-BTC 4.408" 12,909' 16,634' TUBING DETAIL JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C-5 13,339' 14,500' 10,479' 10,730' 1,161' 08/15/97 Isolated C-5 14,590' 14,595' 10,743' 10,744' 5' 08/14/97 Squeezed C-5 15,250' 16,400' 10,817' 11,024 1,650' 08/04/97 Squeezed 4 12,906' 10,263' 3.880" 3.880" 3.880" 4.770" 5.900" 6.000" HES Seal Bore Extension Bottom Sub Halliburton VLT Versatrieve Packer 5 14,530' 10,735' EZSV Cement Retainer 6 15,112' 10,801' EZSV Cement Retainer 5 c 058srd 6 PBTD: 14,534 TD: 16,657 Updated By: MJQ02/07/19 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C-5 13,339' 14,500' 10,479' 10,730' 1,161' 08/15/97 Isolated C-5 14,590' 14,595' 10,743' 10,744' 5' 08/14/97 Squeezed C-5 15,250' 16,400' 10,817' 11,024 1,650' 08/04/97 Squeezed 6 PBTD: 14,534 TD: 16,657 Updated By: MJQ02/07/19 H Hilx q Alaseks,1.11; Granite Point Platform GP -53 133/8x95/8x 1 x 31/2 Valve, Swab, National -MS, 31/1610M FE, HWO, FF trim Valve, Mager, National -MS, 31/1610M FE, H WO, FF in. Valve, Mager, National -MS, 31/16IOM FE, HWD, FF trim I Unihead, Kvaerner SMS, 3 step system, 13 5/8 SM API Hub top K 13 3/8 BTC asing bottom, w/ 2- 2" LPO, L 21/16 SM S5O Granite Point Platform GP -53 Current 01/21/2019 Tubing hanger, National SMS, 135/85M K3 iTCAS lift % 3 %RS Vann susp threads, w/ 3" NSCO "B" BPV profile, %non continuous control Ilne port, 6 M extended neck w/ DA carrier pocket Adapter, 13 5/8 5M #13 API hub X 7 1/16 SM, prepped f/ DA carrier assy, and DHSV port w/shutoff U Hilmrp Alar&*, I.M. Granite Point Platform GP -53 13 3/8 x 9 5/8 Unihead, Kvaerner SMS, 3 step system, 13 5/8 5M API Hub top X 13 3/8 BTC casing bottom, w/ 2- 2" LPO, 4- 21/16 SM SSO Granite Point Platform GP -53 Proposed 02/25/2019 Temporary abandonment H Granite Point Platform 2019 BOP Stack (404) 01/21/2019 rar,aele rams 2 )/8-5 Blind Rams g rams e3 T C r C A cz o r - D `> w m�zm y o z p r AJ m CZ / ai0D-n m�rr ik N z -a Oj M Z A n D � CPDD y2--jG)1� 1G)ODA z C cn K -0 T 3c �I ❑ � E�{l'7III C ryr -00 W T m� Z ti O Z D Z 0 T m �W 1 � 1 n� O A � Dm T om o ✓/ n O A ZD S 0. OZ A W 09 m m� �. fJ 9 2 mF5 0> 4i L W J �O N O i 3a 3 3�3 3 33a 0 nnonnono 00 nonoonnn e3 �< o 0 c D o Z D m � 0 Z T > y N w OOH S Z K 0 r C � a O co 0 0 N ZZ-u*;7 D D DT�G�A A Z > > � Z I D mo Z Z O z D N D Z 0 T mm W �m 1 1 Zi } ja N A A T A p < D0 �O <A m 0g nm x� A W xm m mA r9 zz m� m N 2 L W J cp N Er n x n_3 3 3 33 3 3 <<-- f7f gaga :a C K n n 0 n 0 n 0 n 0 0 n 0 0 0 n.0 n 0 Rig 404 BOP Test Procedure uak„�P.w.A., ccc Attachment #1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) NO tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift -threads d) For ESP wells - Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and / or a penetrator leaks, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) H xarop.u„k,, 11c Rig 404 BOP Test Procedure Attachment #1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same- RIH with test plug on joint of tubing. Install a pump -in sub w/ test line plus an open TIW or lower Kelly valve in top of test joint w/ open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) fill stack and all lines with rig pump- install chart recorder on test line connected to pump -in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder (test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close V valve on standpipe manifold, close valves 1, 2, 10 on choke manifold and close the annular preventer, open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer, close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross, open I' valve of standpipe, close valves 3, 4 & 9 on choke manifold, open valves 1 & 2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/ open outside valve on kill side of mud cross, close valves 5 & 6 /open valves 3 & 4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke / open valves 5 & 6 on choke manifold. Pressure up to —1200 psi and bleed off 200 — 300 #s recording change and stabilization. If passes after 5 minutes, bleed off pressure back to tank. f) Close HCR (outside valve on choke side of mud cross), open manual & super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. Rig 404 BOP Test Procedure Attachment #1 g) Close inside valve / open outside valve (HCR) on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off- open pipe rams and pull test joint leaving test plug/ 2 -way check in place. Close blind rams and attach test line to valve 30 on choke manifold, close valve 7 & 8 / open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves (TIW or Lower Kelly Valve) and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/ -3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2"d set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre - charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/-30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto', not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well: Granite Point 53 (PTD 196-014) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first calf' engineer. AOGCC written approval of the change is required before implementing the change. , Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step I Task Res onsibl 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and d initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial the it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engin6ers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. JUN-01-06 05:33 AM MARK. ATKINS0 GPP .' I e I ! ,i I ~ranlte I ~oint Platform I ~~ell GP-63 Pressuret Date "~IJM~~oa Date Tb tI PI'888. 185/8" Csa p..... 13 3f8" Caa Press. I able. Injected Comments 1 0 120 31 0 2 .' 0 120 31 0 3 0 120 32 0 4' 0 120 32 0 5 0 120 32 0 I 6 . 0 120 32 0 7: 0 120 31 0 8. 0 120 31 0 I 9 : 70 120 31 0 10. 0 130 32 0 11 · 0 130 32 0 12 0 130 31 0 13 0 130 32 0 14, 0 140 31 0 15 0 140 31 0 16 0 140 31 0 17 0 140 31 0 18 0 150 31 0 19 0 150 31 0 20 0 158 31 0 21 0 180 31 0 22 0 180 31 0 23 : 0 160 31 0 24 0 160 31 0 25 0 160 31 0 26 0 160 31 0 27 0 160 31 0 128 0 180 31 0 29 0 175 32 0 30 0 180 32 0 31 : 0 180 32 0 otal 70 4433 971 0 0 Avg: 2.2 5806452 143 31.32258065 0 #DIVIOI Oopies to Tc m Maunder/Jim Regg; Fax 276-7542 I 1 I j I ! ; ; - 907 776 6653 e P.03 , : I· , , Iq~ 6/<f ) \ II f ,~_c.~ti'." ~!" " , -, \ø¡'~"~lt~,,",~ (" ", ' Granite Point Platform Well GP·53 Pr888urn ' DattM,aY-05 D~~ Tba p~~ ~9 S~8~; C~a'Pr~~ 13 3.!~n Cs¡P'''. ...lbli.lnJ.ct8cl 1 0 220 ". ,~2 ".' 0 2 0 220 - J"1 ,,,,..0 3 0 220 ' 31 " 0 4 ' '''0 220 31 ' '" 0 l' "5 '·'t) 220 30 0 6 0 22Q 31 0 7 0 220 31 0 8 0120 30 0" Ì"" 9 ,0 220 30 0 10 Õ 220 3Ö 0 ,'1'1 0"" 220 30 '0 12 0 n~20 'iõ' "Q 13 0 220 30 0 "·""14"" 0 '220 30 Ö ~ "'5 Ò 22'0 "~O 0 16 0 210 30 0 ~ ". "f1 '·"0 2ÖO 30 0 18 0 200 ~O 0 19 0 200 3,º 0 20 0 200 3Ó" '0 21 0 ~OO 3Ö º 22 0 2'ÖO 30 0 . "'-VI ~ .. , 23 '0·' 2,10 30 0 '24'Ö 216 30 "(I 25 ' 0 ., 210 30 0 28 . T' 0 200 ~õ 0 "'27 0 200 31 0 28 cf ~iQO 3'1 0 . 29 0 200 31 0 . 30 0 200 30 0 ,3.J 0 'I. ..'~ 200 31 .._. 0 total 0 . 6540. ,,941 ". 0 Avg P 210.~,677419 .~, 30.354~3871 0 Copies to Tom Maunder/Jim Regg; Fax 278-7542 SCJ~NNED ,JUN ~~ 1 ZOOS 10-d ££99 9¿¿ ¿06 dd~ 0SNI~~~ ·~~~W Wd 8Þ:~0 £0-10-Nnî ) C'õmmeri... ,., , '·""'·"·~r'''·'''''·''·_· . ..___..... n .A. ·-Vi·..·· . _ .""111 W'" y~ -- - ......_\.. I·"·~-· - ...JftI ...._., """.' n.,.,.. , ......,,""_..-...,,.,.-'1,,,.. .. ·""aA¡"¡MN~.".. . ~ ....,. ..:-.;......... ~ _, . "--'II. 'io, " _, "-__, r,· ... i , ....... ".,. ....,......,.,," ..¡¡\;n..r,I"'''''',-;..,..,.,- .._,....MN ,,'+" .- _.... . """1" o #Dïvìò' .,." V'~ AU~--01--02 88:48 AM ~RANITE.POINT.PLATFORM 19077766654 P.04 Grmnite Point Platform Well GP-B3 Pre~ure~ Date Jul-,,02 D~ Tbl) P ~r~-~_ 9 ~B" C~ P _tee__-.t3 ~8" C_-~ P _reee__.I Bbls. Infer, ed Co,,,,,,,,,,,~ 900 900 480 0 , , .- 2 800 800 460 0 ........ 3 3850 3100 490 0 --~ 3950 3950 500 213 , , ..-- 5 4000 4000 ' 500 253 , 6' 4000 4000 50d 255 ,,, · --- 7 4000 4000 495 244 .... .......... 40'bO " 8 4000 , 495 , 236 , , .... ....... -g ..... 4050 4000 490 244 , 10 4000 .4000 4,90 11 4000 4000, ,4,9,,0 212 , -- i2 4000 4000 490 207,, 13 4000 4000 490 194 ..... 4{t;0 - " 14 4000 4000 178 --~5 4000 4000 I 465 ' 1~2 16 4000 4000 480 ..... ]i-,7~,I- --3700 3700 480 i 170 18 4100 4100 480 199 ,, 19 :3800 3800 ,,,480 200 20 4100 4100 460 212 ,, , '2-1 4000 4000 .... ;180 200 ....... ~ 4000 4000 480 ..... 48 , . 23 "~600 4000 480 i 200 24 4000 4050 480 206 .-- ...... 25 3950 4000 470 197 ..... 26 ......... 3900 3900 470 185 , , .- 27 3850 3900 470 2'12 , , , 28 4125 4200 47~ 252 .... 410'~ ,, , 29 4100 470 229 ~ I 4~0 4100 ' II470 209 ,,, ~--~i 41010,, .... 41 O0 470 ' 252 TOtal ,,, iii , ,, Avg Jy Mahan; Fax 276-7542 j°1~' a ~ ~ J ~ ~ ~ { ~ ( ~ ~ ~ ~ ~ ~ ' ~ ~ ~ ,~ ~ ~ , ~ ~ '; ~'~ FRANK H. MURKOWSK/, GOVERNOR ~ ~ ~ ~+ i~ ~t ~ ~ r', ~aT ~RA OII. A1~TD Vra--7 `~ 333 W. T" AVENUE, SUITE 100 COIITSER~ATIOI~T COMMISSIOI~T ANCHORAGE, ALASKA 99501-3539 t PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 11.003 Mr. Larry Greenstein Production Technician Unocal Alaska P.O. Box 196247 Anchorage, AK 99519-6247 RE: Granite Point Field GP-53 (PTD 196-014) Request for Administrative Approval AIO 11 Dear Mr. Greenstein: ;~~~~' ~~ JAS ~ ~ 20~ Per Rule 8 of Area Injection Order ("AIO") 11, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Unocal Alaska. ("Unocal")'s request for administrative approval for water injection in the subject well. AOGCC finds the following: 1. This well was originally reported to have "slight" tubing x annulus communica- tion in March 1999 and verbal approval was given to keep the well in service. 2. Unocal performed a temperature survey in June 2002 and made Sundry permit application to keep the well in service. 3. Analysis of the temperature log indicated that fluids were being confined to the intended injection zone and Unocal was approved to continue injection by sundry permit 302-191 approved August 13, 2002. 4. As required by the Sundry permit, Unocal has been recording daily injection rate- sand well pressures and has been reporting this information to the Commission monthly. In support of this application, Unocal has submitted the results of a new temperature log and a graphical maximum operating pressure determination. 5. Based upon analysis of the submitted logging information, there are no tempera- ture anomalies indicated. The monthly rate/pressure information has not indi- cated any further pressure integrity loss. 6. At this time, Unocal is not proposing to repair the well to restore full integrity. 7. An aquifer exemption is in effect below Cook Inlet for Granite Point Field [40 CFR 147.102(b)(2)(i).] Mr. Larry Greenstein March 29, 200 Page 2 of 2 Based on analysis of the submitted information, the Commission concludes that GP-~3 exhibits two competent barriers to release of well pressure. Accordingly, the Commis- sion believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Granite Point Field GP- 53 is conditioned upon the following: 1. Injection is limited to WATER ONLY; 2. Unocal shall monitor and record wellhead pressures [T/I/O] (tubing/inner annu- lus/outer annulus) and injection rate daily and submit this information to the Commission monthly; 3. Unocal shall perform a temperature log every two years to demonstrate continued production casing integrity; 4. Unocal shall immediately shut in the well and notify the AOGCC upon any meas- urable change in well outer annulus pressure or any change in the rate/pressure re- lationship for the tubing/IA; and 5. After well shut in, AOGCC approval shall be required to restart injection. As provided in AS 31.0.080, 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 consid- ered 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 Commiesion decision to Superior Court unless rehearing has been requested. a ch age, Alaska and dated March 29, 2005. rman Daniel T. Seamount, 3r. Chairman ~,~ Commissioner t r'2 ~.i-i.~, 7 i t ~_ r~ t f C • C^~ ~ a'w ~~ ' y~ '~ ~_ ~__ ~: ~::3 t ~d Unocal Alaska Union Oil Company of Californi 909 West 9`h Avenue, P.O. Box 'i 47 Anchorage, Alaska 99519-6247 Telephone (907) 263-7661; Fax (907) 263-7847 uNOCa~~ Larry P. Greenstein Prodction Technician Date: February 25, 2005 Commission Chair John Norman Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite #100 ~ ~~ JllN ~ ~~ 2D0~ Anchorage, AK 99501-3539 Attn: Tom Maunder Administrative Approval Request We!! No. GP-53 Injector Granite Point Platform Granite Point Field Dear Chair Norman, Unocal requests administrative approval under Area Injection Order 11, Rule 8 for the continuation of injection of non-hazardous Class II fluids for the Grantite Point Platform W~•il No. GP-53 Injector (Permit # 196-014) in Granite Point Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Temperature survey comparison plot (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief/relevant well history (below and attached). This well was drilled and completed as a producer in August of 1997. Per the attached well history, it was almost immediately converted to an injection well and has been injecting with a variance since March of 1999. In addition, please note that Granite Point Field has an auquifer exemption per EPA 40 CFR 147.102 (b)(2)(i). The temperature survey run on 12/21/2004 matches the last survey run on 6/08/2002 in character showing no cooling anomalies above the packer. This indicates that injection is occurring only into the Tyonek C Sands. The plotted daily monitoring, which is reported monthly, hasn't shown any unexplainable rate or pressure responses from this well. Unocal will continue to monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. • Thank you for your consideration and if you have any questions regarding this, please contact me at 263-7661 or Steve Lambert at 263-7658. Sincerely, ~ ~~ r ~~ Larry P. Greenstein cc: MIT book Well File ` ~'~~}~~, ~ ~ GRAN POINT PLATFORM 1. WELL 3-Water Injector V N.®CA` X76 Final Completion: 8/29/97 RKB = 114.75"; Kvaerner SMS Wellhead CASING AND TUBING DETAIL TOl MAX HOLE ANGLE ± 80 ° @ 13,800' SIZE WT GRADE CONN TOP BOTTOM 33" Outside conductor 47 229 26" Inside Conduct or 47 294 13-3/8 68 K-55 BTC 47 1,031 9-5/8 47 L-80 BTC 46 73 9-5/8 53.5 P-110 BTC 73 4,551 7" 29 P-110 KC-BTC 45 6,989 7" 29 L-80 KC-BTC 6,989 13,323 5" 15 L-80 SC-KC-BTC 12,909 16634 Baker 5" HMC liner hanger @ 12,921 3-1/2" 9.2 L-80 SC-Buttre ss 43.44 12,914 3-l/2" 9.2 L-80 STL 12,914 12,970 JEWELRY DETAIL NO. ITEM DEPTH 1 Kvaerner Tubing Hanger 43.44 (AB TC-4S Up X STD VAM DWN) 2 STD VAM x Buttress Pup JT 47.5 3 HES "X" Nipple ID = 2.813" 12,857 4 Halliburton VLT Versatrieve Packer with 12,900 seal bore extension. 5 Seal Assy. (Length = 13.12') crossed over 12900 to 3-1/2" STL tubing. 6 Mule-shoe guide 12,971 7 EZSV Cement Retainer 14,530 8 EZSV Cement Retainer 15,112 PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 13,339 14,500 C-5 6 8/15/97 Exisiting Interval 14,590 14,595 C-5 6 8/14/97 Squeezed 15,250 16,900 C-5 6 8/4/97 Squeezed GP 53 final 8-29-97.doc REVISED: 9/16/97 DRAWN BY: MWD PDTD = 14,530 VI -VV 1 GIItr./~i1QI,WI~i VWI Y~irJ ' ~ • ' ~ 618/02 vs 12/21/04 • Pressure (psia) 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 0 1000 2000 3000 4000 5000 ~ 6000 M- ... ~ 7000 t ~ 8000 d 9000 10000 11000 12000 13000 14000 i I , - -- ~ ~'~ I i I i 40 50 60 70 80 90 100 110 120 130 140 150 160 170 Temperature (Deg. F) -12-21-04 Pressure - Perfs x PKR - 9-5/8" ~„ 5„ -Tbg 12-21-04 Temp 6-8-02 Temp O:\OOE\OOEFields\GPF\Granite Point\Wells\Gp 53\Surveys\Temperature\GP-53-Temp Survey 6-8-02 & 12-21- 04.x1s ulc. rase lceview .. n~.te: Duly l4, 2o4z Subject: Unocal Granite. Point{GP) Wa1153 (Water Inaector} PTD #r 196140 ~~~~p^- ~ prders CQ 6 AlQ l l r'~~nff~~~~~~ Reviewers: Tom Maunder, P.E. ~~ - /~ Jim Regg, `.7 ~'~'~ Initiating Action:: Application for 'V'ariance Review Summary 1. According to the: availablerecords, Unocal reported rninQr {tl psilminute) communication in -early March 1.999, shortly after the well was'converted to injection service. The well :file. (FTD #19614fl} -does notinclude documents .regarding the MIT failure... Per Unocal, diagnostics. determined that-the pac[cerseals were leaking. Unocal continued operation in March 1999 with equal pressures in tubing and inner annulus (IA)A. Un 1`Iovember $, 2400, Jeff3ones (AOGCC Inspector} witnessed a I1~lT for a variance u$ing annulus pressure monitoring (APM} that noted the tubing and IA pressures dropped simultaneously at 5~ psill5 minutes. 2. Unoca[ submitted rrcquest dated $/l8l02 (received b119/42) to continue injection; provided temperature survey and well performance data {injection rate, tubing and IA pressures) 3. Chronological Review offiles revealed: a. CQ 76 tSeptember 12, 1969) b. ATO l l .(September Z9, 198d} -Class II underground. injection authorized. for sma11 "project area" as described in AIC7 G. AIa i 1.1 (October 28, 1986) - claxif ication of Rula 6 ("Well Integrity Failure") d. Sundry Application (Fornn 14-403; August 27, 1.997)--convert GP-53 from producer to water injector; request'amendrnent of AI0 11 since GP-S3 inj action zone is outside area authorized. e. AOGCC Sundry approval (September S, l 997) -Sundry approved; -well c~:nnot be operated as.an injection until CQ 7d and AI{311 expansions approved f, iPublic Notice {September 25, 1997} - public. conuncnt solicited on Unocal application for expansion of CG 76 and AIa l 1. g. Administrative Approvals C© 76,32 and A1:4 11.2 October 23,.1997} -expansion of Qrders approved 4. Technical Evaluation of. Request- Temperature survey indicates water injection confined to intended target; tubing and IA pressure: communication evident fmm perfortnancs data;.pressures less than 7Q°~o MIYP of adjacent and next outer. casing. R.ecommeudation File review indicates compliance with .provisions of 24 AAC 25, Cf}, and'AIC) {as amended}. Approval of Unocal's request is recommended subject to following coriditians: a. Monitor'alE casing annuli daily; report monthly unless there is a 10°Jo change in pressure .attributable to other than well performance {AIa Rule 3 requir$s weekly check of JA only) b. '~.un temp survey every 2 yearn anniversary date is dateofvariance appmusl}.and provide results to Commission. c:. Perform combination MIT (tubing and IA) every 2 years (AIa Rule 5~. Ida plug~cannot be set to isolate the tuning and annulus, an "observation" test may be performed~by. SI~ffia well and observing the pressure decline of the tubing and annulus. GP-53 Maximum Allowable Operating Pressure Graph Pressure (PSI) 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 0' 1,000 000 2 , 3,000 4,000 5,000 6 000 , 7,000 ~ 6,000 ~_ f+ 6 a x,000 10,000 11,000 12,000 13 000 , 14,000 15,000 16,000 17,000 Ru date : 2 3/2005 10:08:41 AM Saf eranng p ssures (surface gauge) Protl ck = 5]12 psi. 70% nominal wring yieltl Into etlla = 1088 psi. ketl by hadure pressure et Cu ant Pr aura rea gs TBG RESS = 1 0 CS REBS = 0 CSG RESS2= Ca ng Details Han r = 5" #, intemal M = WA p9 rom 18633' l0 1 34' MO' Line axing = 5" 15#, L- infernal yie = 8290 psi fro 11588' l0 16634' M ' Floe hoe = 5" k, internal W = WA ps rom 16632' b 6634' MD' Protl Uion Segment = 7" 2 L-80 imam ieM = 8160 5i hom 5962' 1013323 D' Sh = ]"#, intemal yieltl = psi hom 1 1'to 133 ' MD' Into etliate = 8.625" 4]k, L-8 'nternal yieb 88]0 psi om 4524'to 4551' MD' Into iate = 9,625" 53.Sk, P-1 infernal yie = 10 psi hom ]3'to 1551' MD' Into etliale shoe = 9.625" #, in nal yield = psi fr 4550' to 4551' MD' Surface Shoe = 13.3]5" k, internal yieltl = WA psi om 29'to 1031' MO' Insitle ContluUar = 26" #, intemal ylekl = N/A psi h 4 'to 294' MD' Shce = 26" 150k, INS-150 internal yieltl = 1500 psi 82' l0 294' MD' Oulsitle coMUCtor = 33" 150N, INS-150 intemal yieltl 00 psi hom 47' to 229' MD' Protlupion wsirp a na cart rrng .43 W o Inlermetliate wain yield ®45% of nominal with Ouitl weigl of 0.433 #/ft Sudaw casing yiel ~ 45%of nominal wkh fluitl weigh o! 0. 33 #/fl ' Fracture gratlienl D.7 #/fl API :50]33204] 00 Pertn4: 1960140 ~ ~ W,Odcbook GP-53 axing Pressure Anatysis X70 perwnt 20050223. s Variable Definitions RP =ReSeNOir Pressure CVP =Casing VieM Pressure' SF :Safety Factor (70%brworking annulus; 45%(or outer ahnul'Q HP. = Inlamal Fluitl Hytlreulic Preseure NMSP=7#atimOmallpwabkfENfece'worklnB Dressme ._. _. -~.._.- Graphical calculation method ' Insitle pressure polen5al == OWSitla pressure containment Therefore HP. MASP=RP~(CYP'S~ ___ _.. ,........ . - RSatrangin9 MASP=RP~(CVP'SF)-HP -Internal Fluid Hytlreulic Pressure --'--- Formation facture pressure ~ 0.7 #/fl Production CVP ~ 70% Outside Containment for Praduawn casing MASP (production casing) -Intermediate CVP ~ 45 -Outsitle Containment for Intermediate casing -MASP (Intermediate casing) -Surface CYP ~ 45% - Outsitle Containment for Surface casing -MASP (Surface weing) • Cunent Pressure Reatlings Disclaimers (fine DDri~t) Cesilg yield values taken irom publphetl sources where spe~wlions are known. If sper3fiwlions are unknown men values are fhe lowest value o/ probable materials. ND inlerpoletM from Opemrorks tlireclbnal surveys. Values shah be i/- 25 ft ~ 10,000 ft. MD Gfa hlcal Cain Pf656Ure Mal siS Ver 22%.X16 RE: GP-53 (196-014) -_ .. Subject: RE: GP-53 (196-014) From: "Dolan, Jeff J" <dolanjj@unocal.com> Date: Tue, 06 Jan 2004 08:05:36 -0900 To: Thomas Maunder <tom maunder@admin.state.ak.us> CC: Hal Martin <martinh@unocal.com>, Jim Regg <jim regg@admin.state.ak.us>, Larry Greenstein <greensteinlp@unocal.com> Tom; GP-53 is an issue of data management.. We have been converting from the old Field Data Capture Program (FDC) to the new FDCxtra. The old program had 3 columns for annulus pressure readings, CSGPRESS, CSGPRESSI and SURF_PRESS. The new program has 6 columns, explicitly tied to a specific casing diameter. Unfortunately, CSGPRESS is now used for the 7" casing whereas in the old FDC it was generally used for the 9 5/8". In September I modified the wavered Well Report to start picking up data from the new database locations which fixed some problems but since different facilities were in different phases of the transition caused new ones to appear. The good news is that as of 12/31/2003 the old FDC was removed from the system. All the facilities are now using the new program. The FDCxtra allows us to collect data on all the casing annuli and validate the data as it is keyed in. GP-53 is particularly confusing since it has 7", 9 5/8" and 13 3/8" casings. Most of the GGP wells have 9 5/8", 13 3/8" and 16" or 18" casings. I have attached a spreadsheet with the charts (last 180 days) for GP 53 and GPP Muci 2. The case of GP 53 the plots show the data was collected and entered into the system but not in consistent database columns. In regards to your earlier email about GP Muci2; we have been slowly bleeding off pressure on the tubing and 9 5/8" while monitoring fluid production. The 13 3/8" has been controlled by slowly bleeding to maintain its pressure below the 1200# relief value pressure. As the 9 5/8" pressure has come down it has been noted that the rate of increase on the 13 3/8" annulus has decreased. As of this morning the pressures are: Tubing: 2250# decreasing 9 5/8" casing: 2125# decreasing 13 3/8" casing: 690# slowly increasing As we move into the new year, I will be revising the Wavered Well Report to retrieve data from the specific casing now that the field capture procedure has stabilized. Regards; Jeff Dolan Technical Support Cook Inlet Assets Alaska Business Unit Unocal 76 Voice 907.263.7807 Fax 907.263.7847 Email dolanjj,~unocal.com -----Original Message----- From: Thomas Maunder [mailto:tcm maundercadmin.state.ak.us] Sent : Monday, January O5, 2004 2 : 52 --PM ----- _.._.._...._..._....__.._..__...._.______. _. _. To: Larry Greenstein; Jeff Dolan Cc: Hal Martin; Jim Regg Subject: GP-53 (196-014) Larry, Jeff and Hal, We got a fax of the pressure information for GP-53 for the month of 1 of 2 3/11/2005 1:28 PM RE: GP-53 (196-014) • • December. The tubing x casing annulus (IA) pressure is essentially equal to the tubing pressure for the entire month. I checked back through the monthly reports and it appears that with the September report (looks at July - Sept information) that the IA pressure "became" zero. In the July and August reports, the IA pressure is essentially equal to the tubing pressure. Did a valve get closed that has now been opened?? My file research also shows that there is a sundry approval in effect for GP-53, although the specific information on the excel sheet does not show the sundry number. Could one of you please look into the discrepancy on the pressure information for the IA on GP-53?? Also, it would be appropriate to update/verify the sundry approval information for all the wells presently reported. Thanks for your attention to this matter. Please call with any questions. Tom Maunder, PE AOGCC Granite Point 180 day data for GPP-53 and Muci 2.zip Content-Description• Granite Point 180 day data for GPP-53 and Muci 2.zip Content-Type: application/x-zip-compressed Content-Encoding: base64 2 oft 3/11/2005 1:28 PM .. • Very High Range PSI °o °o °o °o °o °o ~ 0 0 0 0 0 0 £0/ L £/Z l £0/bZ/Z L £01L l/Z l £010 L/Z l £0/£0/Z L £0/9Z/ l l £0!6 L/ l l £0/Z L/ L l £0190/ l l £0/6Z/0 L £0/ZZl0 l ~ £0/9 l/0l ^^1 FBI £0180/0 L a £0/ LO/0 L £0/4Z/60 £0/L L/60 £0/0 L/60 £0/£0/60 £0/LZ/80 £0/OZ/80 £0/£ l/80 £0/90/80 £010£/LO £0/£Z/LO £0/9 L/LO £0/60/LO °o ion o ~°n °o ~°n °o .°n o ~ M ch N N ~'- ~ ISd eBUBa MOI li ~ I m U N 7 I N N D_ L m O O m N C N N N U_ L v 0 0 N p1 ~ c_ O y N o U M p0 ~ N O 00 ~ ° N m m ~ ~ ~ O (O O rn U c M O) O O) ~ c ~ ~ U o n U f9 ~ O ~ ~ ~ M O y ~' E U W ~ m f '` ~ ~ O N o ~ ~ ~ . ~ Q Q cA RE: GP-53 minor leak first indications 3/10/99 Subject: RE: GP-53 minor leak first indications 3/10/99 From: "Dolan, Jeff J" <dolanjj@unocal.com> Date: Thu, 20 Jun 2002 12:13:59 -0700 To: "'Tom Maunder"' <tom maunder@admin.state.ak.us> Tom, Nothing from Blair. I have a fax receipt that shows Steve Tyler faxed Blair the 3/10199 MIT on 3/31/99. We checked Steve's email records and mine but have nothing either way. I think in those days most communication was by fax or voice. I also looked in the basement well files but found nothing. Jeff -----Original Message----- From: Tom Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, June 20, 2002 10:26 AM To: Dolan, Jeff J Subject: Re: GP-53 minor leak first indications 3/10/99 Thanks Jeff. Do you have anything from Blair in the March, 1999 time frame?? "Dolan, Jeff J" wrote: Tom, Looking back through the records I find notes indicating that we first recognized GP-53 had minor leaks from an MIT conducted 3/10/99. The well passed but showed a 1 psi/min. one way leak. Diagnostics were run during the 2 weeks following the MIT from which we concluded that the packer seals were probably leaking. New guidelines were issued 3/27/99 which were to operate the well @4,000 psi on the tubing and casing to minimize movement in the packer seals and minimize any further damage. This is my tracking spreadsheet with all the Unocal injector wells on it, dates, status etc. There are two rows of buttons across the top. They either hide all the rows or expose a certain group, such as the Dolly wells or wells needing MITs in 2002. Push the Hide button first since this will initialize some variables the macros use. The macro also formats the page for my printer. I commented out my printer assignment to prevent the macro from croaking when it can't find my printer. «MIT INFO.v7.XLS» Regards; Jeff Dolan Water Flood Technician Oil Asset Group Alaska Business Unit Unoca176 Voice 907.263.7807 1 of 2 3/11/2005 1:29 PM 1ZE: GP-53 minor leak first indications 3/10/99 i i Fax 907.263.7884 Email dolanjj@unocal.com 2 oft 3/11/2005 1:29 PM UIC File Review Date: July 10, 2002 • Subject: Unocal Granite Point (GP) We1153 (Water Injector) PTD #: 196014 Orders: CO 76 AIO 11 Reviewers: Tom Maunder, P.E. Jim Regg Initiating Action: Application for Variance Review Summary 1. According to the available records, Unocal reported minor (<1 psi/minute) communication in early March 1999, shortly after the well was converted to injection service. The AOGCC well file does not include documents regarding the MIT failure. Per Unocal, diagnostics determined that the packer seals were leaking. Unocal continued operation after approval subject to pressure monitoring. On November 8, 2000, Jeff Jones (AOGCC Inspector) witnessed a MIT for a variance using annulus pressure monitoring (APM) that noted the tubing and IA pressures dropped simultaneously at 50 psi/15 minutes. 2. Unocal submitted request dated 6/18/02 (received 6/19/02) to continue injection; provided temperature survey and well performance data (injection rate, tubing and IA' pressures) 3. Chronological Review of files revealed: a. CO 76 (September 12, 1969) b. AIO 11 (September 29, 1986) -Class II underground injection authorized for small "project area" as described in AIO c. AIO 11.1 (October 28, 1986) -clarification of Rule 6 ("Well Integrity Failure") d. Sundry Application (Form 10-403; August 27, 1997) -convert GP-53 from producer to water injector; request amendment of AIO 11 since GP-53 injection zone is outside area authorized. e. AOGCC Sundry approval (September 5, 1997) -Sundry approved; well cannot be operated as an injection until CO 76 and AIO 11 expansions approved f. Public Notice (September 25, 1997) -public comment solicited on Unocal application for expansion of CO 76 and AIO 11 g. Administrative Approvals CO 76.32 and AIO 11.2 (October 23, 1997) -expansion of Orders approved 4. Technical Evaluation of Request -Temperature survey indicates water injection confined to intended target; tubing and IA pressure communication evident from performance data; pressures less than 70% MII'P of adjacent and next outer casing. ' IA -inner annulus; annulus between tubing and next outer protective casing ~ ~ Recommendation File Review indicates compliance with provisions of 20 AAC 25, CO, and AIO (as amended). Approval of Unocal's request is recommended subject to following conditions: a. Monitor all casing annuli daily; report monthly unless there is a 10% change in pressure attributable to other than well performance (AIO Rule 3 requires weekly check of IA only) b. Run temp survey every 2 years (anniversary date is date of variance approval) and provide results to Commission. c. Perform combination MIT (tubing and IA) every 2 years (AIO Rule 5). If a plug cannot be set to isolate the tubing and annulus, an "observation" test may be performed by SI the well and observing the pressure decline of the tubing and annulus. 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: Pull tubing: Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: 114.75 RKB (MLLW) feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: x Granite Point Field 4. Location of well at surface Leg 4, Slot #3 8. Well number 3980' W and 2854' N from SE corner Sec. 13, T10N, R12W, SM 53 ADL 1786/374045 At top of productive interval 9. Permit number 96-0014 At effective depth 10. APl number 50- 733-20471 At total depth 11. Field/Pool Granite Point Field/Middle Kenai "C" Sands 12. Present well condition summary Total depth: measured 16,657' feet Plugs (measured) true vertical 11,071' feet Effective depth: measured 16,513' feet Junk (measured) true vertical 11,042' feet Casing Length Size Cemented Measured depth True vertical depth Structural 182 33" Driven 229 229 Conductor 247 26" Driven 294 294 S u rfa ce 984 13-3/8" 1213 sx 1031 1030 Intermediate 4,506 9-5/8" 1369 sx 4551 4088 Production 13,275 7" 500 sx 13323 10471 Lin er 3,725 5" 377 sx 16634 10266-11067 Perforation depth: measured 13,339'-14,500; 14,590'-14,595' (Squeezed); 15,250'-16,900' (Squeezed) true vertical 10,478'-10,730'; 10,743'-10,744(Squeezed); 10,817'-11,123'(Squeezed) Tubing (size, grade, and measured depth) 3-1/2" 9.2 Ib/ft L-80 12,972' Packers and SSSV (type and measured depth) HES Versatrieve Packer @ 12,900' 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: Directional Program Temperature survey X Schematic X Op characteristics plot X 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service:X 17. I hereby certify that, h~ foregoing is true and correct to the best of my knowledge. Signed: f Title: Water flood technician Date: 6/18/2002 f/ y I ~v -,~ FOR COMMISSION USEONLY Conditions of approval: Notify Commission so representative may witness _ -- lApproval No - Plug integrity .... BOP Test_ __ Location clearance Mechanical Integrity Test__~._7_.' ~'~ ~ Subsequent form required 10-_t~;,¢~*,.~,¥,.\~ ~---~.~: ~'~~'~,~ O~nal S~gned By Anchorage C~mmy Oech~ T~ Form 10-403 Rev 06/15/88 ORIGIh ALa SUBMIT IN 2000 4000 6OOO 8000 10000 12000 14000 GP 53 6/8/2002 Temperature Survey Temp F 0 20 40 60 80 100 120 140 160 180 --Temp. F __ ~acko 12,~00 Top po~or~tion 6/18/2002 7:20 AM SCANNED AU G 2 i 2D 02 GP#53QT1 20020608.xls POOH 5OOO Monthly Review * Well GPP GP-53 1000 45OO 4000 350O 3000 2500 20OO 1500 1000 5OO 0 900 800 700 60O 500 ~ 40O 30O 200 lO0 0 RKB = 114.75"; Kvaerner SMS Wellhead 'OL ~ 12,909 5 6 POINT PLATFORM WELL # 53--Water Injector Final Completion: 8/29/97 CASING AND TUBING DETAIL SIZE V~'T GRADE CONN TOP BOTTOM 33" Outside conductor 47 229 26" Inside Conductor 47 294 13-3/8 68 K-55 BTC 47 1,031 9-5/8 47 L-80 BTC 46 73 9-5/8 53.5 P-110 BTC 73 4,55l 7" 29 P-110 KC-BTC 45 6,989 7" 29 L-80 KC-BTC 6,989 13,323 5" 15 L-80 SC-KC-BTC 12,909 16634 Baker 5" HMC liner hanger ~ 12,921 3-1/2" 9.2 L-80 SC-Buttress 43.44 12,914 3-1/2" 9.2 L-80 STL 12,914 12,970 JEV~ELRY DETAIL NO. ITEM DEFI'H Kvaemer Tubing Hanger 43.44 (AB TC-4S Up X STD VAM DWN) STD VAM x Buttress Pup JT 47.5 HES "X" Nipple ID = 2.813" 12,857 Halliburton VLT Versatrieve Packer with 12,900 seat bore extension. Seal Assy. (Length = 13.t2') crossed over 12900 to 3-1/2" STL tubing. Mule-shoe guide 12,971 7 C-5 SAND 7 EZSV Cement Retainer 14,530 8 EZSV Cement Retainer t 5,112 PDTD = 14,530 MAX HOLE ANGLE _+ 80 o ~ 13,800' PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 13,339 141500 C-5 14,590 14,595 C-5 15,250 16,900 C-5 6 8/15/97 Exisiting Interval 6 8/14/97 Squeezed 6 8/4/97 Squeezed GP 53 final 8-2%97.doc REVISED: 9/16/97 DRAWN BY: M~VD Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 l' 'k''~ /1 i -9- &2 UNOCAL ) June 18,2002 State of Alaska Alaska .Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Attn: Tom Maunder Re: Granite Point Injection Well,GP-53 Dear Mr. Maunder: A temperature survey was run on 6/8/02 for the purpose of demonstrating that Granite Point 53 (Permit # 1960140, API# 50-733-20471-00) is injecting into the desired Tyonek C-5 reservoir and there is no flow into any fresh water aquifers or shallow reservoirs. I am enclosing a plot of the temperature survey, a plot of the operating characteristics over the last year, and a current well bore schematic. The temperature survey plot starts approximately 100 feet below the packer and 30 feet above the perforated interval. No significant departures from the geothermal gradient are apparent on the plot. We believe there is minor tubing / casing communication due to leaking packer seals. We have been operating this well with the tubing and casing at equal pressure, 4000 psi. to minimize further damage. The 70% burst strength of the 9 5/8 casing is 5700 psi. It is Unocal's opinion that the well can be operated safely with no risk to shallow fresh water aquifers or gas zones. Please grant us permission to continue injection into this well under the assumption that we will monitor the various annuli daily and report this data monthly, and we will run a temperature survey every two years. Also enclosed is a 10-403 for your approval. If you have any questions regarding this, please contact myself at 263-7807 or Hal Martin at 263-7675. Sj ienC~ffery J tDolan Waterflood Technician Cook Inlet Waterflood Management Enclosures SCANNED AUG % 1 2002 ORIGINAL AOGCC Granite Point GP-53 Application for Variance jjd UNDE~I[GROUND INJECTION CONTROL PR~RAM ALASKA OIL AND GAS CONSERVATION COMMISSION Authorization to Inject with an Integrity Loss Sundry application ~C)~-\~\ forwell Q.~na~c~ ~ ~'~ ,PTD ~'a,~o©\~is approvedto allow the well to remain in injection service. This approval is subject to the following conditions: Confirmed T x IA communication, rate not quantifiable. Water Injection ONLY 4 Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. Annual MITIA/LLRT 4 year CMIT T x IA Confirmed T x IA communication, > 10 gpm. ..~ Water Injection ONLY 3 Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. ,.. 2 y'em~MIT T ~bing leakj--or..l~T TI~.k~ leak)~2~( x Production Casing l~eak Water Injection ONLY Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. Annual MITT Annual CMIT IA x OA IA x OA Communication Water Injection ONLY Daily Pressure (tubing and all annuli) and Rate Monitoring with a 1 monthly report of this information to the Commission. Annual MITT Annual CMIT IA x OA Alarm w/injection shutdown on OA. Set point minimum 1000 psi < minimum burst strength of outside casing. This approval is specific for the identified integrity loss. Should pressure/rate monitoring indicate a change in the well conditions, the following applies: Type 4 changes to Type 3, notify Commission on next business day and secure permission to continue operations. If well already has Type 4 or 3 integrity loss and monitoring indicates Type 2 or 1 may have developed, secure well immediately and notify the Commission on the next business day. By Order of the Commission Re: Permission to continue ~nject~on ~n L~'-b~ Subject: Re: Permission to continue injection in GP-53 Date: Thu, 10 Jan 2002 16:27:23 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Ruff, Christopher ^" <ruffc@unocal.com> Chris, Your request and justification are appropriate. You correctly note that were a problem to develop that the change in the monitored parameters would be a flag. By copy of this email, you have approval to resume injection and conduct the temperature survey. Tom Maunder, PE AOGCC "Ruff, Christopher A" wrote: Tom, I don't know if you are handling GP-53's 10-403 which requests permission to continue injection and time extension. Please move this one to the front of my requests if at all possible. We currently have this well shut-in and would like to tum it back on so the injection intervals will stay cool. This will allow us to run the temperature survey to prove the integrity of the wellbore. There is no risk to any fresh water aquifers or any shallow hydrocarbon intervals (there aren't any of either present), so continued injection causes no risk. For that matter the results of the temperature survey are somewhat academic for the same reasons. Never the less we want to run the survey to be thorough, then apply for the variance. The only real risk is a shallow leak that allows pressure to be transmitted to the backside of nearby we//bores, if this were to occur I would expect a rapid increase in injection rate coincident with a drop of injection pressure which would be caught by our daily surveillance system. Attached is a copy of the letter that was submitted with the 10-403. <<Aogcc GP53 Time extension 12-31-01.doc>> Thanks Chris Name: Aogcc GP53 Time extension 12-31-01.doc Aogcc GP53 Time extension 12-31-01.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder@admin.state.ak.us> sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 6/20/2002 11:13 AM TONY KNOWLE$, GOVEBNOB ALASKA OIL AND GAS CONSERVATION COMMISSION October 23, 1997 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ADMINISTRATIVE APPROVAL AIO NO. 11.2 Re: The application of Union Oil Company of California to expand the affected area of Area Injection Order No. 11. Rick D. Cross Landman Unocal Alaska Resources UNOCAL Corporation P. O. Box 196247 Anchorage, AK 99519-6247 Dear Mr. Cross: The drilling and completion of well Granite Point No. 53 (GP No. 53) has demonstrated that the originally established affected area of Area Injection Order No. 11 did not include the southern extent of the Granite Point Middle Kenai Oil Pool. The portion of the accumulation penetrated by GP No. 53 has been depleted; however, operation of the well as an injector will increase ultimate recovery from the Granite Point Middle Kenai Oil Pool. Pursuant to your wTitten request dated August 27, 1997, and subsequent correspondence from UNOCAL dated September 23, 1997, the Alaska Oil and Gas Conservation Commission herebv authorizes the expansion of the affected area of Area Injection Order No. 11 to include the north half of Sections 25 and 26 and the northeast quarter of Section 27 in Township 10 North, Range 12 West, Seward Meridian. David W. Johm Chair~ha~,,.~ laska this day October 23, 1997. / v Robert N. Christenson. P.E. Commissioner ' Cammy O~chsli Commissioner TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION October 23.1997 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 76.32 Re: The application of Union Oil Company of California to expand the affected area of Conservation Order No. 76. Rick D. Cross Landman Unocal Alaska Resources UNOCAL Corporation P. O. Box 196247 Anchorage, AK 99519-6247 Dear Mr. Cross: The drilling and completion of well Granite Point No. 53 (GP No. 53) has demonstrated that the originally established affected area of Conservation Order No. 76 did not include the southern extent of the Granite Point Middle Kenai Oil Pool. The portion of the accumulation penetrated by GP No. 53 has been depleted; however, operation of the well as an injector xvill increase ultimate recovery from the Granite Point Middle Kenai Oil Pool. Pursuant to your written request dated August 27, 1997, and subsequent correspondence from UNOCAL dated September 23, 1997, the Alaska Oil and Gas Conservation Commission herebv authorizes the expansion of the affected area of Conservation Order No. 76 to include the north half of Sections 25 and 26 and the northeast quarter of Section 27 in Township 10 North, Range 12 West, Seward Meridian. DONE i! chor._age? Alaska this day October 23, 1997. hnst~n Robert N. Christenson, P.E. Chairm~.....__~ Commissioner C~~v echsl~' Commissioner AUG 2 1 2002 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re~ The application of Union Oil Company of Califomia (Unocal) for expansion of the affected areas of Conservation Order No. 76 and Area Injection Order No. 11 in the Cook Inlet offshore Granite Point Oil Field in Southcentral Alaska. Unocal by letter dated September 22, 1997 has requested an expansion of the affected areas of Conservation Order No. 76 and Area Injection Order No. 11. Information obtained through the recent drilling of Granite Point well No. 53 indicates that recoverable reserves within the Granite Point Middle Kenai Oil Pool may be present on lease Nos. ADL 374044 and ADL 374045 which are currently outside the affected areas of the subject orders. The requested action would allow Unocal to operate Granite Point well No. 53 as an injector or as a producer within the C-5 Middle Kenai reservoir. The well-encountered oil saturations that indicate the Middle Kenai oil Pool may have originally extended through the proptpsed area of expansion. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 pm October 9, 1997 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 October 28, 1997 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 October 9, 1997. 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 October 21, 1997. Chairman Published September 25, 1997 ADN 02814008 ALASKA OIL AND GAS CONSERVATION COMMISSION September 5, 1997 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dale Haines Drilling Manager Union Oil Company of California P.O. Box 196247 Anch. Ak. 99519 Mr. Haines: The attached approval to convert well Granite Point No. 53 to a Class II water injector is limited to the downhole operations described in your application. Operation of the well as an injector is not approved herein. Expansion of the affected areas of Conservation Order No. 76 and Area Injection Order 'No. I i is required prior to operating the well as an injector. We have been in contact with Rick Cross of your office concerning these matters, he or Bob Crandall at the AOGCC can provide any additional intbrmation you may require. D, avid W. Joh~,~ ) Chairman ~ Attachment Unocal Alaska Resou,-~s Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL,6 ¢¢ · August 27, 1997 Mr. Bob Crandall ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, AK 99501-3192 ORIGINAL Granite Point Field PROPOSED CHANGE TO AREA INJECTION ORDER #11 & CONVERSION OF GRANITE POINT #53 ADL 374045 Dear Mr. Crandall: On September 29, 1986 the AOGCC issued Area Injection Order No. 11 establishing area wide injection covering Section 18 & 19 of T10N, R11W, S.M., and Section 2,11,13, 14, 23, &24, and E/2 SE/4 of Section 15, NE/4 NE/4, S/2 NE/4, SE/4, & SE/4 SW/4 of Section 22 ofT10N, R12W, S.M. Unocal, as operator of the Granite Point Field, requests that Area Injection Order No. 11 be amended to include the N/2 of Sections 25 & 26, and the NE/4 of Section 27 of T1 ON, R12W, S.M. The additional area is needed to encompass a structural high that dips southwesterly across a portion of Sections 25 & 26 and into Section 27. Injection of produced water into this area will enhance the recovery of hydrocarbons, and may eliminate the need to drill additional wells. Enclosed in triplicate is our "Application for Sundry Approvals" (form 10-403) to coven the Granite Point #53 development well to an injection service well. Also enclosed is a "Verification of Application" by the undersigned stating that the applicant is acquainted with the facts pursuant to 20 ACC 25.280. Enclosures Sincerely, UNION OIL COMPANY OF CALIFORNIA, d.b.a. UNOCAL / ~. "'... /'.~ " '-~ / !-/ . . - , ' Y( I~ICK' U. I, grosff ' '~ / ~' ~ , I I 'ON ~3~0 NOI~3PNI' .. ~ , , , , .:.::. :: . . ~' . ti *1 Sl 91 Zl ~1 itl *1 $1 :91:~'~:~ ":.'.' ':.'. ': /. ,.',:, ;,' ~,.'. ~.. *r .-. ~1 II OI 6 I Z II II OI '.6. . · .. . .~ · ..:..,,' .', ~ :. .', .- ... . ..· . . .... · . ~ · . · .. 4 ~ .. . . . . /---~. '.C' ...-~ ." .. · .. .. . ... Ol N I1 Oq lA &NlOd i]N¥ D 1997 GRANITE POINT DRILLING PROGRAM C-5 STRUCTURE MAP iii i I II II I · ..', ~ '~/~~ t// ' ~~ .C'L-~,~ + -~,. x2' -~s. ~' -~s. ~' ii ii i i i I Area Injection Order 11 http://www, state ~" us/local/akpages/ADMIN/ogc/oindex/aio/aio l 1.htm STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE REQUEST OF UNION OIL ) COMPANY OF CALIFORNIA for ) an Area Injection Order ) for the portion of the ) Granite Point Field ) developed by the Granite ) Point Platform ) Area Injection Order No. 11 Southern Portion of Granite Point Field September 29, 1986 IT APPEARING THAT: 1. Union Oil Company of California (Union) requested the Alaska Oil and Gas Conservation Commission to issue an area injection order permitting the underground injection of fluids within a portion of the Granite Point Field for purposes of enhanced hydrocarbon recovery. 2. Notice was published in the Anchorage Daily News on September 12, 1986 of an opportunity for a public hearing on October 13, 1986. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly, the Commission will, in its discretion, issue an order without a public hearing. FINDINGS: 1. An order permitting the underground injection of fluids on an area basis, rather than for each injection well individually, provides for efficiencies in the administration and surveillance of underground fluid injection operations. 20 AAC 25.460 provides the Commission with the authority to issue an order governing underground injection operations on an area basis. 2. The portion of the Granite Point Field developed by Union's Granite Point Platform constitutes a compact "project area" which can readily be described by governmental subdivisions. Union is the sole operator of this Project Area. 3. The Project Area encompasses approximately the southern one-third (1/3) of the Granite Point Field, Middle Kenai Oil Pool. The Project Area includes all existing injection wells and injection well sites planned for enhanced recovery of oil from this portion of the Middle Kenai Oil Pool. 4. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Granite Point Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(A) and 20 AAC 25.440(c). 5. Less stringent requirements for well construction, operation, monitoring, and reporting of 1 of 3 6/19/2002 3:49 PM -, Area Injection Order I I http ://www. state-'- us/local/akpages/ADMIN/ogc/oindex/aio/aio 11 .htm injection operations may be more appropriate than would be required when injection occurs into, through or above portions of aquifers not exempted. 6. The vertical limits of injection strata and confining formations may be defined in the Mobil Granite Point well No. 1. 7. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. 8. Statewide regulations and conservation orders govern field operations except as modified by this order. 9. To ensure that fluids injected are confined to injection strata, the mechanical integrity of injection wells should be demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions. 10. Injection wells existing on the date of this order were constructed and completed in accordance with regulations which conform to the requirements of 20 AAC 25.412. NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the following described area referred to in this order as the affected area: SEWARD MERIDIAN TION R11W T1ON R12W Sections 18 and 19. Sections 2, 11, 13, 14, 23 & 24. Section 15: E 1/2 SE 1/4. Section 22:NE1/4 NE1/4, S1/2 NE1/4, SE1/4 and SE1/4 SW1/4. Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non-hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in the Mobil Granite Point well No. 1 between the measured depths of 7,725 feet and 10,800 feet. Rule 2 Fluid Injection Wells The underground injection of fluids must be: 1) through a well permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through a well approved for conversion to a service well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. Rule 3 Monitoring the Tubing/Casing Annulus Pressures The tubing/casing annulus pressure of each injection well must be checked weekly to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a SGANNE~ AUG % 11 2002 2 of 3 6/19/2002 3:49 PM Area Injection Order i 1 http ://www. state ~'- us/local/akpages/ADMIN/ogc/oindex/aio/aio 11 .htm hoop stress greater than 70% of the casing's minimum yield strength. Rule 4 Reporting the Tubing/Casing Annulus Pressure Variations Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 5 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi, or, assuming a 0.465 psi/ft gee-pressure gradient, a surface pressure that imposes a differential pressure gradient across the casing of 0.25 psi/ft at the vertical depth of the packer, whichever is greater; but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength. The test pressure must be held on the tubing/casing for 30 minutes with no more than a 10% decline. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Rule 6 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Note: Rule 6 has been amended by Administrative Approval No. 11.t. Rule 7 Plugging and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accordance with 20 AAC 25.105. Rule 8 Administrative Relief Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated September 29, 1986 C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission Lonnie C. Smith, Commissioner Alaska Oil d Gas Conservation Commission W. W. Barnwell, Commissioner Alaska Oil & Gas Conservation Commission Area Injection Order Index 3 of 3 6/19/2002 3:49 PM Administrative Approval No. 11. I http://www.state.~' "s/local/akpages/ADMIN/ogc/oindex/aio/aal 1 - 1 .htm October 28, 1986 ADMINISTRATIVE APPROVAL NO. 11.1 Re' Amend Rule 6 of Area Injection Order (AIO) No. 11 Mr. Gerry Graham District Operations Manager Union Oil Company of California P. O. Box 190247 Anchorage, AK 99519-02479 Dear Mr. Graham: The Commission has determined that Rule 6 of AIO No. 11 as set forth is unclear as to the Connnission's intent. Therefore, Rule 6 is amended to read: Rule 6 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must [IMMEDIATELY CEASE INJECTION,] notify the Commission on the first working day following the observation, [AND] obtain Commission approval [FOR CORRECTIVE ACTION] of a plan for corrective action, and when an USDW is not endanqered, obtain Commission approval to continue injection. Sincerely, C. V. Chatterton Chairman Return to AIO No.11 1 of 1 6/19/2002 3:49 PM STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Re: The motion of the Alaska) Oil and Gas Conservation Com- ) mittee to determine if waste ) is occurring, to hear testi- ) mony on the initiation of a ) pressure maintenance project, ) the beneficial use of gas and ) other relevant matters; and ) the application of Mobil Oil ) Corporation and Pan American ) Petroleum Corporation for an ) order authorizing water in- ) jection for pressure mainten- ) ance or secondary recovery ) purposes and for the consoli- ) dation and revision of Con- ) servation Orders No. 59 and ) No. 60; Granite Point Field. ) Conservation Order No. 76 Granite Point Field: Pressure Maintenance Project, Field Rules and Beneficial Use of Gas Granite Point Middle Kenai Oil Pool September 12, 1969 IT APPEARING THAT: 1. The Alaska Oil and Gas Conservation Committee moved to hold a public hearing to hear testimony by the operators of the Granite Point Field to determine if waste is occurring as a result of producing the Middle Kenai Pool and to hear testimony on the initiation of a pressure maintenance project for the Middle Kenai Pool, the beneficial use of gas produced as the result of crude oil production and any other matters relevant to the proper development and operation of this pool. 2. Notice of the hearing was published in the Anchorage Daily News on July 17, 1969. 3. Mobil Oil Corporation and Pan American Petroleum Corporation, as operators of the Granite Point Field, by application received July 22, 1969, petitioned the Committee for an order authorizing water injection for pres- sure maintenance or secondary recovery purposes in the Granite Point Field and for the consolidation and revision of Conservation Orders No. 59 and No. 60. 4. A public hearing was held in the City Council Chambers of the Z. J. Loussac Library, Anchorage, Alaska, on August 15, 1969. Testimony was pres- ented in response to the motion and in support of the petition, and affected and interested parties were heard. CONSERVATION ORDER NO. 76 Page 2 September 12, 1969 AND IT FURTHER APPEARING THAT: 1. The Middle Kenai Pool should be re-named the Granite Point Middle Kenai Oil Pool. 2. Development of the Granite Point Middle Kenai Oil Pool is essentially complete and the pool limits have been reasonably well defined. 3. The reservoir fluids are undersaturated and maximum recovery of oil will not be achieved unless some additional recovery method is used. 4. Water injectivity tests indicate the feasibility of injecting fluids into the Granite Point Middle Kenai Oil Pool to supplement the natural reservoir energy and thereby achieve increased oil recovery. 5. There is a substantial variance in permeability between crestal wells and downdip or flank wells and more than one injection pattern may be advisable. 6. Lease line injection wells should confine reservoir fluids to each operator's leases and thereby protect correlative rights. 7. The value of the additional recovery from a fluid injection project will exceed the cost of such a project. 8. The operators have increased their use of produced gas but some gas is being flared. 9. Negotiations with potential purchasers of produced gas indicate there is no market for the flared gas and the findings of Conservation Order No. 61 with respect to the Granite Point Field have not materially changed. 10. Conservation Orders No. 59 and No. 60 should be revised and consoli- dated herein. CONSERVATION ORDER NO. 76 Page 3 September 12, 1969 NOW, THEREFORE, IT IS ORDERED that the rules herein set forth apply to the following described area: Township 10 North~.. Range ll..W.est~ S. M. Sections 5, 6, 7, 8, 18 and 19: All .T..o_wnship ..10 ..N..orth, Range 12 West, S. M. Sections 1, 2, 11, 12, 13, 14, 23 and 24: Ail Section 15: E 1/2 SE 1/4 Section 22: NE 1/4 NE 1/4, S 1/2 NE 1/4, SE 1/4, SE 1/4 SW 1/4 Township 11 North,._ Range ._!1 West, S. M. Sections 29, 30, 31 and 32: Ail Tqwnship ,1! Nort.h~, R..ange 12. Wes.t.~ .S.. M. Section 25: E 1/2 NE 1/4, SE 1/4 Section 35: E 1/2 Section 36: Ail Rule 1. Definition of Pool. The Granite Point Middle Kenai Oil Pool is defined as the accumulation of oil common to and which correlates with the accumulation found in the Mobil-Union Granite Point No. 1 well between the drilled depths of 7,725 feet and 10,800 feet. Ru 1 e 2. Sp ac inK. (a) Not more than two completed wells shall be allowed in any govern- mental quarter section. (b) No pay opened to the well bore shall be nearer than 500 feet to any property line nor nearer than 1,000 feet to any well drilling to or capable of producing from the same pool. Rule 3. Casing and Cementing Requirements. Surface casing must be set and cemented to a depth of at least 1600 feet. Sufficient cement must be used to circulate to the surface. The production string must be cemented with a sufficient volume of cement to extend at least 500 feet above the shoe or a volume sufficient to cover 100 feet above the top of the uppermost producing zone encountered in the well, whichever is greater. Rule 4. Bottom Hole Pressure Surveys. A key well bottom hole pressure survey shall be made upon Committee request; provided, however, such surveys shall not be required more often than twice in any calendar year. The time and length of survey, number and location of wells, datum and other details will be determined by the Committee upon consultation with the operators. CONSERVATION ORDER NO. 76 Page 4 September 12, 1969 Rule 5. Gas-Oil Ratio Tests. A gas-oil ratio test of 24 hours duration shall be made annually on each producing well. The tests will be made during the months of June and July and the results will be reported on Committee Form P-9 prior to September of each year. The requirementst of this rule will be waived if monthly reported oil and gas production is based on a gas-oil ratio test made at least every six months in each producing well. Rule 6. Press~qre Maint.enance Project.. The injection of water for the purpose of pressure maintenance, secondary recovery or of conducting injectivity tests is hereby permitted in the Granite Point Middle Kenai Oil Pool. A semi-annual progress report detailing project operations and results shall be submitted to the Committee in January and July of each year. Rule 7. Administrative Approval. Upon request of the applicants and a showing that the affected parties have been notified of such request, the Committee may authorize the conver- sion or drilling of any well at any location, the termination or suspension of the project, or any operation reasonably designed..to further the purposes of the project. Rule 8. Other Conservation Orders. Conservation Orders No. 59 and No. 60 are hereby revoked. Ail other Conservation Orders affecting the Granite Point Middle Kenai Oil Pool shall remain in full force and effect, except as modified hereby. DONE at Anchorage, ~laska, and dated September 12, 1969. Tbo~~~. R, .Mar sha~ f,%r-.', 'Ex'ecutiv~/~S';c'r'et 'a'ry Alaska Oil and Gas Conservation Committee Concurrence: Homer L. Burrell, Chairman Alaska Oil and Gas Conservation Committee 07 K. Gilgreth, Jr.,-~~r Alaska Oil and Gas Conservation Committee RE: GP-53 minor leak first indications 3/1U/UU Subject: RE: GP-53 minor leak first indications 3110199 Date: Thu, 20 Jun 2002 12:13:59 -0700 From: "Dolan, Jeff J" <dolanjj@unocal.com> To: "'Tom Maunder'" <tom_maunder@admin.state.ak.us> Tom, iNoDing from Blair. I have a fax receipt that shows Steve Tyler faxed Blair the 3/10/99 MIT on 3/31/99. We checked Ste{/~r~email records and mine but have nothing either way. I think in those days most communication was by fax or voige [also looked in the basement we, ll t~les.but, fogncl, notbing LO'O~ng back ttirough the recoms irma notes Inmcating ma]:~ve first recognized GP-53 had minor leaks from an MIT conducted 3/10/99. The well passed but showed a 1 psi/min, one way leak. Diagnostics were run during the 2 weeks following the MIT from which we concluded that the packer seals were probably leaking. New guidelines je ere issued 3/27/99 which were to operate the well @4,000 psi on the tubing and casing to minimize movement in the packer seals and minimize any further damage. This is my tracking spreadsheet with all the Unocal injector wells on it, dates, status etc. There are two rows of b.~j~~~t_op_. They either hide all the rows or expose a certain group, such as the Dolly wells or wells -'-~c~i~°l~'~~'~'.'P. ush the Hide I~utton first since tbisw, ill initialize some variables the macros use The rr m: IOl al 'o an ell n sr.a iK.U ' Se : ire~.~ ]cr~[mnh~e~ ?u~-Jmy printer assignment to prevent the macro from t S~:_~l~l~?.~Lr~>r~r leak first indications 3/10/99 Regards; Th,~t~~~~u have anything from Blair in the March, 1999 time fi~ame?? Oil Asset Group Alaska Business Unit Unocal 76 Voice 907.263.7807 Fax 907.263.7884 Email dolanjj~unocal.com I of I 6/20/2002 11:22 AM UIC File Review Date: Subject: PTD #: Orders: Reviewers: Initiating Action: July 10, 2002 Unocal Granite Point (GP) Well 53 (Water Injector) 196140 CO 76 AIO 11 Tom Maunder, P.E. YO---~c2~V IV'$"t'3 ''> Jim Regg Application for Variance Review Summary 1. According to the available records, Unocal reported minor (<1 psi/minute) communication in early March 1999, shortly after the well was converted to injection service. The well file (PTD # 196140) does not include documents regarding the MIT failure. Per Unocal, diagnostics determined that the packer seals were leaking. Unocal continued operation in March 1999 with equal pressures in tubing and inner annulus (IA)~. On November 8, 2000, Jeff Jones (AOGCC Inspector) witnessed a MIT for a variance using annulus pressure monitoring (APM) that noted the tubing and IA pressures dropped simultaneously at 50 psi/15 minutes. 2. Unocal submitted request dated 6/18/02 (received 6/19/02)to continue injection; provided temperature survey and well performance data (injection rate, tubing and IA pressures) 3. Chronological Review of files revealed: a. CO 76 (September 12, 1969) b. AIO 11 (September 29, 1986) - Class II underground injection authorized for small "project area" as described in AIO c. AIO 11.1 (October 28, 1986) - clarification of Rule 6 ("Well Integrity Failure") d. Sundry Application (Form 10-403; August 27, 1997) - convert GP-53 from producer to water injector; request amendment ofAIO 11 since GP-53 injection zone is outside area authorized. e. AOGCC Sundry approval (September 5, 1997) - Sundry approved; well cannot be operated as an injection until CO 76 and AIO 11 expansions approved f. Public Notice (September 25, 1997) - public comment solicited on Unocal application for expansion of CO 76 and AIO 11 g. Administrative Approvals CO 76.32 and AIO 11.2 (October 23, 1997) - expansion of Orders approved 4. Technical Evaluation of Request- Temperature survey indicates water injection confined to intended target; tubing and IA pressure communication evident from performance data; pressures less than 70% MIYP of adjacent and next outer casing. ~ IA - inner annulus; annulus between tubing and next outer protective casing Recommendation File Review indicates compliance with provisions of 20 AAC 25, CO, and AIO (as amended). Approval of Unocal's request is recommended subject to following conditions: a. Monitor all casing annuli daily; report monthly unless there is a 10% change in pressure attributable to other than well performance (AIO Rule 3 requires weekly check of IA only) b. Run temp survey every 2 years (anniversary date is date of variance approval) and provide results to Commission ........... .~.~" · . . '~', ./~" . ,:~ ;, ;. ~'~., .L ',' .. c. Perform comb,nat,on MIT (tub,ng and IA) every 2 years (AIO Rule 5).~.-t~ti~ ~6t~ be set to isolate the tubing and annulus, an "observation" test may be performecfb~-/'~S'[~'~ well and observing the pressure decline of the tubing and annulus· DRILL 6" HOLE WITH GEODIAMOND IMPREGNATED DIAMOND BIT AND TURBINE TO 15,953'. POOH. PU DBS BIT AND RIH. DRILL 6" HOLE TO 16,223'. DAY 76 (7/28/97) CURRENT DEPTH 16,635' MD / 11,060'TVD DRILL 6" HOLE TO 16,635'. DAY 77 (7/29/97) CURRENT DEPTH 16,657' MD / 11,069'TVD DRILL 6" HOLE TO 16,657'. POOH TIGHT. RIH PUMP HIGH WEIGHT SWEEP. PULL OUT OF HOLE WITH NO PROBLEMS. LD BHA. PU DITE/SLP/LDT-D/CNTH/GR/AMS LOGGING TOOLS. TEST WET CONNECT. DAY 78 (7/30/97) CURRENT DEPTH 16,657' MD / 11,069'TVD RIH WITH LOGGING TOOLS ON DRILLPIPE. LOG 6" HOLE FROM 16,630' TO 13,108'. MAKE REPEAT PASSES AND POOH. LD LOGGING TOOLS. CSDL. DAY 79 (7/31/97) CURRENT DEPTH 16,657' MD / 11,069'TVD RIH WITH 5" 15 LB/FT L-80 CASING TO 16,630. (TOL = 12905') SET LINER HANGER AND RELEASE. PUMP 441 CF (377 SX) OF CEMENT AND BUMP PLUGS. POOH TO 11,425'. CBU. DAY 80-82 (8/1-8/3/97) CURRENT DEPTH 16,657' MD / 11,069'TVD RIH 7" CLEANOUT ASSEMBLY. DRILL CEMENT F/12,000' TO 12,909'. PRESSURE TEST 7" CASING AND LAP TO 3,500 PSI FOR 30 MINUTESmOK. POOH. RIH WITH 5" CLEANOUT ASSEMBLY AND TIE-BACK RECEPTACLE MILL. CLEANOUT 5" CASING TO 16,513. POLISH TIE-BACK RECEPTACLE. PRESSURE TEST 5" LINER AND LAP TO 3,500 PSI FOR 30 MINUTES--OK. CHANGE WELL OVER TO DIESEL. POOH. RIH WITH 3-3/8" TCP GUNS. DAY 83 (8/4/97) CURRENT DEPTH 16,657' MD / 11,069'TVD RIH WITH 3-3/8" TCP GUNS. RU FLOW HEAD AND TAKE BASELINE FLUID LEVEL. PERFORATE C-5 SAND FROM 16,400' TO 15,250'. TAKE FLUID LEVEL READINGS. RELEASE PACKER. REVERSE CIRCULATE OUT GAS. ClRC LONG WAY. POOH WITH GUNS. DAY 84-85 (8/5-8/6/97) CURRENT DEPTH 16,657' MD / 11,069'TVD LD 2-7/8" DP AND 3-3/8" GUNS. RIH WITH 3-1/2" GAS LIFT COMPLETION AND STAB INTO LINER HANGER TIE-BACK RECETACLE. INSTALL HANGER AND CONTROL LINER. LAND HANGER AND SET PACKOFF. TEST SEAL ASSEMBLY TO 1,000 PSlwOK. TEST HANGER PACKOFF TO 5,000 PSlwOK. SET BPV AND ND BOPE AND NU TREE. LD 3-1/2" DP AND CLEAN PITS. RELEASE RIG @ 24:00 HRS 8/6/97. LAST REPORT DAY 86 (8/10/97) CURRENT DEPTH 16,657' MD / 11,069'TVD SKID RIG FROM GP 52 TO GP 53. PULL SCSSV AND BOTTOM ORFICE FROM GLM. KILL WELL WITH FIW. PU 3-1/2" DRILLPIPE FOR WORKOVER. DAY 87-88 (8/11-8/12/97) CURRENT DEPTH 16,657' MD / 11,069'TVD PU 3-1/2" DP. NU BOPE. TEST BOPE--OK EXCEPT ANNULAR FAILED. CHANGE OUT ELEMENT AND RETEST--OK. MU LANDING JOINT AND ATTEMPT TO PULL PACKOFF--NO GO. PU JARS AND JAR PACKOFF LOOSE. RELEASE HANGER AND PULL OUT OF TIE-BACK RECEPTACLE. CIRCULATE WELL. ESTABLISH INJECTION RATE: 4 BPM @ 1950 PSI. POOH STANDING BACK 3-1/2" COMPLETION. DAY 89 (8/13/97) CURRENT DEPTH 16,657' MD / 11,069'TVD RIH AND SET CEMENT RETAINER AND SET @ 15,100'. ESTABLISH INJECTION RATE @ 2 BPM @ 2,500 PSI. SQUEEZE 44 BBLS INTO PERFS~ FINAL INJECTION RATE .5 BBL/MIN @ 4,500 PSI. REVERSE CIRCULATE OUT 14 BBLS. POOH. DAY 90 (8/14/97) CURRENT DEPTH 16,657' MD / 11,069'TVD POOH AND LAY DOWN RTTS. RIH WITH TCP PERF GUNS AND TAGE CEMENT RETAINER @ 15,112'. PU AND SHOOT SQUEEZE PERFS @ 14,595'TO 14,590'. ESTABLISH INJECTION RATE: .5 BBL/MIN @ 3,000 PSI. POOH. RIH WITH EZSV CEMENT RETAINER. DAY 91-93 (8/15-8/17/97) CURRENT DEPTH 16,657' MD / 11,069'TVD SET EZSV @ 14530'. ESTABLISH INJECTION RATE. PUMP 15 BBLS OF CEMENT. DISPLACE TO STINGER. STAB INTO RETAINER AND CONITNUE DISPLACEMENT. PULL OUT OF EZSV RETAINERS AND REVERSE OUT 14 BBLS OF CEMENT. POOH. RIH WITH TCP PERF GUNS AND PERFORATE C-5 SAND @ 14,500' TO 13,339'. SHOOT BASE LINE FLUID LEVEL. SHOOT GUNS AND CONTINUE TO TAKE FLUID LEVEL READINGS. OPEN BYPASS AND REVERSE OUT PERF GAS. UNSEAT PACKER AND POOH. RU SWS, RIH WITH RETRIEVABLE PACKER AND SET @ 12,891'. POOH. RIH WITH SEAL ASSEMBLY AND 3-1/2" 9.2 LB/FT L-80 GAS LIFT COMPLETION. LAND HANGER AND SET PACKOFF. PRESSURE TEST HANGER AND PACKOFF TO 5,000 PSI. SET BPV AND ND BOPE. NU TREE. RELEASE TO PRODUCTION. LD 3-1/2" DP. DAY 94 (8/18/97) CURRENT DEPTH 16,657' MD / 11,069'TVD CONT LAYING DOWN 3-1/2" D.P. WORKING TO CLEAN MUD TANKS. PREP EQUIPMENT FOR RIG SKID. RIG RELEASE TO G.P. WELL #55 AT 08:00 HRS. Report Date : 09- -CArtographic System : sta _ ~ e 4 Directional Survey For : GP-53 UWI : 507332047100 Log Datum Elevation : 115.0000 X Surface Location : 263333.78 Y Surface Location : 2544505.77 Longitude : -151.33159 Latitude : 60.95802 Operator : UNOCAL Total Depth : 16688.00 Completion Date : Common Well Name : GP-53 LT MEASURED TVD X Offset 0.00 0.00 0.00 83.00 83.00 0.00 176.00 176.00 0.00 296.00 295.99 -0.47 358.00 357.99 -0.87 447.00 446.97 -1.19 539.00 538.94 -1.53 629.00 628.90 -2.19 720.00 719.83 -2.59 810.00 809.76 -2.81 900.00 899.68 -2.69 990.00 989.60 -1.90 1145.00 1144.46 0.16 1226.00 1225.43 0.72 1326.00 1325.41 0.85 1364.00 1363.40 0.91 1417.00 1416.40 1.10 1547.00 1546.38 1.35 1639.00 1638.35 1.69 1672.00 1671.31 1.91 1766.00 1765.17 2.66 1792.00 1791.11 2.94 1887.00 1885.75 4.19 1981.00 1979.08 6.38 1999.00 1996.90 6.97 2107.00 2103.48 10.60 2201.00 2195.65 13.78 2265.00 2258.08 15.85 2358.00 2348.01 18.41 2452.00 2437.65 20.34 2547.00 2527.12 21.00 2637.00 2610.43 20.59 2682.00 2651.51 20.31 2731.00 2695.83 19.97 2824.00 2777.77 18.66 2917.00 2857.32 17.19 3014.00 2938.00 15.91 3107.00 3012.90 14.10 3198.00 3083.72 11.78 3292.00 3155.19 9.50 3385.00 3226.02 7.28 3478.00 3295.93 4.03 3569.00 3362.81 0.22 3662.00 3430.66 -3.47 3756.00 3499.35 -7.25 3851.00 3569.17 -11.34 4130.00 3775.20 -24.34 4513.00 4060.49 -42.03 4596.00 4122.60 -46.06 4690.00 4192.46 -51.34 4878.00 4330.29 -62.31 4969.00 4396.73 -66.87 5062.00 4465.68 -70.15 5155.00 4536.03 -71.97 5249.00 4607.56 -73.09 Y Offset X Coordinate -0.02 263333.78 -0.02 263333.78 -0.02 263333.78 -1.02 263333.31 -1.77 263332.91 -3.52 263332.59 -5.77 263332.25 -8.52 263331.59 -11.77 263331.19 -15.52 263330.97 -19.27 263331.09 -23.02 263331.88 -29.02 263333.94 -31.52 263334.50 -33.27 263334.63 -33.77 263334.69 -34.77 263334.88 -36.52 263335.13 -39.02 263335.47 -40.52 263335.69 -45.52 263336.44 -47.27 263336.72 -55.52 263337.97 -66.52 263340.16 -68.77 263340.75 -86.02 263344.38 -104.02 263347.56 -118.02 263349.63 -141.52 263352.19 -169.77 263354.12 -201.77 263354.78 -235.77 263354.37 -254.02 263354.09 -275.02 263353.75 --318.77 263352.44 -367.02 263350.97 -420.77 263349.69 -475.77 263347.88 -533.02 263345.56 -594.02 263343.28 -654.27 263341.06 -715.52 263337.81 -777.02 263334.00 -840.52 263330.31 -904.52 263326.53 -968.77 263322.44 -1156.52 263309.44 -1411.52 263291.75 -1466.27 263287.72 -1529.02 263282.44 -1656.27 263271.47 -1718.27 263266.91 -1780.77 263263.63 -1841.52 263261.81 -1902.52 263260.69 Y Coordinate 2544505.75 2544505.75 2544505.75 2544504.75 2544504.00 2544502.25 2544500.00 2544497.25 2544494.00 2544490.25 2544486.50 2544482.75 2544476.75 2544474.25 2544472.50 2544472.00 2544471.00 2544469.25 2544466.75 2544465.25 2544460.25 2544458.50 2544450.25 2544439.25 2544437.00 2544419.75 2544401.75 2544387.75 2544364.25 2544336.00 2544304.00 2544270.00 2544251.75 2544230.75 2544187.00 2544138.75 2544085.00 2544030.00 2543972.75 2543911.75 2543851.50 2543790.25 2543728.75 2543665.25 2543601.25 2543537.00 2543349 25 2543094 25 2543039 50 2542976 75 2542849 50 2542787 50 2542725.00 2542664.25 2542603.25 5344. O0 5438.00 5534.00 5629. O0 5817.00 5911.00 6009.00 6196.00 6288.00 6383.00 6476.00 6569.00 6664.00 6852.00 6947.00 7040.00 7135 ..00 7229.00 7512.00 7607.00 7702.00 7797.00 7891.00 7986.00 8127.00 8330.00 8447.00 8540.00 8634.00 8732.00 8780.00 8875.00 9093.00 9193.00 9276.00 9369.00 9461.00 9555.00 9646. O0 9740'. O0 '9831:00 9923.00 100~.7.00 10120.00 10201.00 10293.00 10387.0Q 10479'. 00' 10573.00 10633.00 10784.00 10876. O0 10968.00 11060.00 11153.00 11246.00 11338.00 11431.00 11523. 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'-'=~- 10323. 10370.6~ 10415.78 10445.40 10459.16 10492.12 10494.72 10498.46 10506.07 10514.18 10521.12 10524.15 10532.09 10538.01 10544.19 10550.14 10556.95 10562.53 10569.16 10575.16 10580.01 10586.03 10591.03 10595.72 10599.98 10611.32 10644.09 10663.66 10685.06 10692.11 10707.11 10713.79 10722.14 10726.89 10732.71 10735.44 10739.41 10741.21 10745.17 10748.65 10751.78 10761.24 10764.35 10770.93 10780.65 10791.19 10798.45 10802.44 10813.57 10824.95 10836.40 1084-9.18 10862.53 10876.99 108-93.92 10911.86 10930.25 10949.42 10968.68 10987.49 11006.67 11012.65 11024.89 11042.71 11053.90 11069.12 11075.46 -550.12 -572.03 -582.69 -592.97 -599.66 -602.87 -611.25 -612.00 -613.06 -615.06 -616.69 -617.81 -618.44 -620.44 -621.94 -623.53 -625.00 -626.47 -627.81 -629.56 -631.37 -633.44 -636.56 -639.47 -642.75 -646.09 -656.53 · -684.09 -696.53 -707.28 -710.19 -715.19 -717.28 -720.87 -723.44 -726.87 -728.62 -731.34 -732.69 -735.75 -738.87 -742.00 -751.91 -754.84 -760.47 -765.34 -766.31 -766.62 -766.87 -767.69 -768.59 -770.78 -774.50 -780.06 -786.00 -791.00 -796.91 -804.56 -813.16 -820.31 -826.62 -833.53 -835.66 -840.72 -848.47 -853.25 -859.34 -861.56 -6950.27 -7104.77 -7184.52 -7265.02 -7320.27 -7346.77 -7412.52 -7417.77 -7426.02 -7444.27 -7468.02 -7492.02 -7503.52 -7536.52 -7563.77 -7594.27 -7623.52 -7656.77 -7684.27 -7717.52 -7748.77 -7775.27 -7809.77 -7839.02 -7866.52 -7891.02 -7957.27 -8131.02 -8221.02 -8310.77 -8339.77 -8399.77 -8427.02 -8465.77 -8490.27 -8522.52 -8539.27 -8566.77 -8580.77 -8612.27 -8643.02 -8672.52 -8763.52 -8793.27 -8856.77 -8949.02 -9039.27 -9099.02 -9131.77 -9223.02 -9316.27 -9407.52 -9499.52 -9591.52 -9683.02 -9773.52 -9863.52 -9954.27 -10044.77 -10135.52 ' -10225.52 -10316.02 -10345.52 -10407.02 -10498.02 -10556.7,7 -10633.02 -10663.27 · ~62783.66 2761.75 _02751.09 262740.81 262734.12 262730.91 262722.53 262721.78 262720.72 262718.72 262717.09 262715.97 262715.34 262713.34 262711.84 262710.25 262708.78 262707.31 262705.97 262704.22 262702.41 262700.34 262697.22 262694.31 262691.03 262687.69 262677.25 262649.69 262637.25 262626.50 262623.59 262618.59 262616.50 262612.91 262610.34 262606.91 262605.16 262602.44 262601.09 262598.03 262594.91 262591.78 262581.87 262578.94 262573.31 262568.44 262567.47 262567.16 262566.91 262566.09 262565.19 262563.00 262559.28 262553.72 262547.78 262542.78 262536.87 262529.22 262520.62 262513.47 262507.16 262500.25 262498.12 262493.06 262485.31 262480.53 262474.44 262472.22 2537555.50 2537401.00 2537321.25 2537240.75 2537185.50 2537159.00 2537093.25 2537088.00 2537079.75 2537061.50 2537037.75 2537013.75 2537002.25 2536969.25 2536942.00 2536911.50 2536882.25 2536849.00 2536821.50 2536788.25 2536757.00 2536730.50 2536696.00 2536666.75 2536639.25 2536614.75 2536548.50 2536374.75 2536284.75 2536195.00 2536166.00 2536106.00 2536078.75 2536040.00 2536015.50 2535983.25 2535966.50 2535939.00 2535925.00 2535893.50 2535862.75 2535833.25 2535742.25 2535712.50 2535649.00 2535556.75 2535466.50 2535406.75 2535374.00 2535282.75 2535189.50 2535098.25 2535006.25 2534914.25 2534822.75 2534732.25 2534642.25 2534551.50 2534461.00 2534370.25 2534280.25 2534189.75 2534160.25 2534098.75 2534007.75 2533949.00 2533872.75 2533842.50 UNOCAL Granite Point Platform Cook Inlet, Alaska Slot #4-4 Well #GP53 HUC, HF-~ Directional & Navigation Drilling Completion Report DDS: TOM DUNN Job Number' 450-85473 Start Date' 31-May-97 ~~ ~.,~,~nvl- ~ ~,~..~L~.~,~.~'..~ ~ ~.,~ ~,.~, ~ ~z--i.~..~ VV~,.~n~,.~ ~L--L_ ~ JobNo. 0450-85473 Sidetrack No. Page I of 6 ·: II,ri_' I :~--1 Company UNOCAL Rig Contractor & No. Nabors AK Drilling - #156 Field GRANITE POINT FIELD Well Name & No. GRANITE POINT PLATFORM/GP53 Survey Section Name Definitive Survey BHI Rep. DUNN. HAMBURG WELL DATA , , , Target TVD (~-r) Target Coord. N/S Slot Coord. N/S -2425.42 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 1301.49 Magn. Declination 22.130 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ff[~ 30m~ 10m[~ reft. Sec. Azim, 182.98 Magn. to Map Corr. 22,130 Map North to: OTHER ............. ........................ SURVEY D ....... ., 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'r) (OD) (OD) (Fr) (FT) (FT) (Fl') (Per lO0 FT) Drop (-) Left (-) ....... 0.00 0.00 0.00 0.00 0.00 0,00 0.00 TIE IN POINT 01-JUN-97 GSS 83.00 0.00 0,00 83.00 83.00 0,00 0.00 0.00 0.00 0.00 FIRST GYRO INSIDE CONDUCTOR 01-JUN-97 GSS 176.00 0.00 0.00 93.00 176.00 0.00 0.00 0.00 0.00 0.00 SECOND GYRO INSIDE CONDUC'I'O,-~ ,, 01-JUN-97 GSS 296.00 1.00 206,00 120.00 295.99 0.96 -0.94 -0.46 0.83 0.83 BTM OF 30' CONDUCTOR 01 -J UN-97 GSS 358.00 0.75 200.00 62.00 357.99 1.85 -1,81 -0.83 0.43 -0.40 01 -J UN-97 GSS 447.00 1.50 179.00 89.00 446.97 3.57 -3.52 -1.01 0.95 0.84 ,, 01 -JUN-97 GSS 539.00 1.50 195.00 92.00 538.94 5.95 -5.89 -1.30 0.45 0.00 01 -JUN-97 GSS 629,00 2.00 191.00 90.00 628.90 8.66 -8.57 -1.91 0.57 0.56 01 -JUN-97 GSS 720,00 2,25 180.00 91.00 719.83 12.01 -11.91 -2.21 0.52 0.27 01 -JUN-97 GSS 810.00 2.50 184.00 90.00 809.76 15.74 -15.64 -2.35 0.33 0.28 01 -JUN-97 GSS 900.00 2.25 170.00 90.00 899.68 19.42 -19.34 -2.18 0.70 -0.28 .,. 01 -JUN-97 GSS 990.00 2.50 164.00 90.00 989,60 23.00 -22.96 -1.33 0,39 0.28 LAST SURVEY IN 17 1/2" HOLE 03-JUN-97 MWD 1145.00 2.30 158.70 155.00 1144.47 28.99 -29.07 0.83 0.24 -0.13 -- 04-J UN-97 MWD 1226.00 1.20 173.40 81.00 1225.43 31.28 -31.40 1.57 1.48 -1.36 -- 04-JUN-97 MWD 1326.00 0.80 177.70 100.00 1325.41 33.01 -33,14 1.72 0.41 -0.40 04-J UN-97 MWD 1364.00 1.10 164.50 38.00 1363.41 33.62 -33.76 1.83 0.97 0.79 .. 04-JUN-97 MWD 1417.00 0.80 168.50 53.00 1416.40 34.46 -34.61 2.04 0.58 -0.57 04-J UN-97 MWD 1547.00 0.80 174.70 130.00 1546.39 36.23 -36.40 2.30 0.07 0.00 04-J UN-97 MWD 1639.00 2.40 167.00 92.00 1638,35 38.72 -38.92 2.79 1.75 1.74 04-JUN-97 MWD 1672.00 2.60 172.60 33.00 1671.32 40.12 -40.34 3.05 0.96 0.61 -- 04-JUN-97 MWD 1766.00 3.70 168.80 94.00 1765.17 45.16 -45.43 3.91 1.19 1.17 04-JUN-97 MWD 1792.00 4.00 170.30 26.00 1791.12 46.86 -47.14 4.23 1.22 1.15 04-JUN-97 MWD 1887.00 5.90 169.80 95.00 1885.76 54.85 -55.21 5.65 2.00 2,00 -0.53 04-J UN-97 MWD 1981.00 7.80 165.20 94.00 1979.08 65.63 -66.14 8.13 2.10 2.02 -4.89 ~ F_:L Job No. 0450-85473 Sidetrack No. Page 2 of 6 · =_ [1~ =-I ::(--"~ Company UNOCAL Rig Contractor & No. Nabors AK Drilling - #156 Field GRANITE POINT FIELD Well Name & No. GRANITE POINT PLATFORM/GP53 Survey Section Name Definitive Survey BHI Rep. DUNN, HAMBURG WELL DATA ,, Target TVD (FT) Target Coord. N/S Slot Coord. N/S -2425.42 Grid Correction 0.000 Depths Measured From: RKB ~] MSL~I SS[- Target Description Target Coord. E/W Slot Coord. E/W 1301.49 Magn. Declination 22.130 Calculation Method MINIMUM CURVATURE ~Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m[~ lomE~ Vert. Sec. Azim. 182.98 Magn. to Map Corr. 22.130 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 (FT) (DD) (DD) (F'r) (FT) (FT) (F'r) (Per lO0 FT) Drop (-). Left (-) 04-JUN-97 MWD 1999.00 8.20 165.30 18.00 1996.91 68.01 -68.56 8.77 2.22 2.22 0.56 04-JUN-97 MWD 2107.00 10.40 168.40 108.00 2103.48 84.79 -85.56 12.69 2.09 2.04 2.87 ,. 04-J UN-97 MWD 2201.00 12.20 169.30 94.00 2195.66 102.65 -103.63 16.24 1.92 1.91 0.96 04-J UN-97 MWD 2265.00 13.20 171.60 64.00 2258.09 116.38 -117.51 18.56 1.75 1.56 3.59 _1 04-JUN-97 MWD 2358.00 16.30 173.60 93.00 2348.01 139.68 -140.99 21.57 3.38 3.33 2.15 .--, -- 04-JUN-97 MWD 2452.00 18.70 176.20 94.00 2437.66 167.66 -169.14 24.04 2.68 2.55 2.77 04-JUN-97 MWD 2547.00 20.60 179.10 95.00 2527.12 199.46 -201.05 25.31 2.25 2.00 3.05 05-JU N-97 MWD 2637.00 23.80 180.00 90.00 2610.44 233.40 -235.05 25.56 3.58 3.56 1.00 05-J U N-97 MWD 2682.00 24.40 179.40 45.00 2651.52 251.74 -253.42 25.66 1.44 1.33 -1.33 05-JUN-97 MWD 2731.00 26.10 180.10 49.00 2695.84 272.61 -274.32 25.74 3.52 3.47 1.43 05-JU N-97 MWD 2824.00 30.30 181.00 93.00 2777.78 316.51 -318.25 25.30 4.54 4.52 0.97 , 05-JU N-97 MWD 2917.00 32.10 180.20 93.00 2857.33 364.64 -366.43 24.80 1.99 1.94 -0.86 05-JUN-97 MWD 3014.00 35.30 180.20 97.00 2938.01 418.39 -420.24 24.61 3.30 3.30 0.00 05-J U N-97 MWD 3107.00 37.40 181.20 93.00 3012.91 473.47 -475.35 23.93 2.35 2.26 1.08 05-J U N-97 MWD 3198.00 40.40 181.1 0 91.00 3083.73 530.57 -532.48 22.78 3.30 3.30 -0.11 05-JUN-97 MWD 3292.00 40.60 180.90 94.00 3155.20 591.59 -593.52 21.72 0.25 0.21 -0.21 _. 05-J UN-97 MWD 3385.00 40.20 181.00 93.00 3226.03 651.82 -653.78 20.72 0.44 -0.43 0.11 -- 05-J U N-97 MWD 3478.00 42.30 182.70 93.00 3295.95 713.12 -715.06 18.72 2.56 2.26 1.83 06-J UN-97 MWD 3569.00 43.10 182.10 91.00 3362.82 774.83 -776.72 16.14 0.99 0.88 -0.66 06-JUN-97 MWD 3662.00 43.20 182.20 93.00 3430.67 838.43 -840.28 13.75 0.13 0.11 0.11 -- 06-JUN-97 MWD 3756.00 42.90 182.20 94.00 3499.36 902.59 -904.40 11.29 0.32 -0.32 0.00 _ -- 06-J UN-97 MWD 3851.00 42.50 182.80 95.00 3569.18 967.01 -968.76 8.48 0.60 -0.42 0.63 -O-~-'J-~--~-7--'--i~V~D- ~'i'~c~':~-t~ ...... ~i2::~0 .... 1'82-.80 ~):o1~-- --~.-~ ..... i';'~5-.-'1 :~' .......... :~-1'56:6-~' ............. -:~'.-~--" 0.07 -o.o7 o.oo 06-JUN-97, MWD' 4513.00--41.40 ~-~-~-.~ '~.00 4060.50 --1410.67 ~1~4~-~-~ -13.19 0.20 -0.20 0.00 i ' ' 'l~tl¢._~ll." U U IO N L O H Job 0450-85473 Sidetrack No. 3 of 6 llr~ :~1 :=,[--..-~11__ Company UNOCAL Rig Contractor & No. Nabors AK Drilling - #156 Field GRANITE POINT FIELD : I' Well Name & No. GRANITE POINT PLATFORM/GP53 Survey Section Name Definitive Survey BHI Rep. DUNN, HAMBURG WELL DATA Target TVD (F-r) Target Coord. N/S Slot Coord. N/S __-2425.42 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W 1301.49 Magn. Declination 22.130 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lO0ft~ 30m~ 10ml-I Vert. Sec. Azim. 182.98 Magn. to Map Corr. 22.130 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 (F'r) (OD) {DD) (F'r) (FT) (F'r) (FT) (Per lO0 FT) Drop (-) Left (-) 10-JUN-97 MWD 4596.00 41.70 183.30 83.00 4122.62 1465.72 -1466.86 -16.12 0.54 0.36 0.60 10-JUN-97 MWD 4690.00 42,30 184.00 94.00 4192.47 1528.61 -1529.63 -20.13 0.81 0,64 0.74 )" - 10-JUN-97 MWD 4878.00 43,40 183.50 188.00 4330.30 1656.45 -1657.21 -28.48 0.61 0.59 -0.27 r)'--' 10--J UN'97 MWD 4969.00 42.80 182.60 91 .00 4396.75 1718.63 '1719.30 '31 .80 0.94 '0.66 '0.99 10--JU N'97 MWD 5062,00 41 .50 181 .10 93.00 4465,70 1781 .02 '1781 ,67 '33.82 I ,77 '1 .40 '1 .61 10--JU N'97 MWD 5155.00 40.20 180.00 93.00 4536.04 1841 .79 '1842.50 '34.41 1 .60 '1 .40 '1,18 I 0--JUN'97 MWD 5249.00 40.70 179.80 94.00 4607.57 1902.69 '1903.48 '34.30 0.55 0.53 '0.21 10--JUN'97 MWD 5344.00 40.90 180.00 95.00 4679.49 1964.68 '1965.56 '34.20 0.25 0.21 0.21 10--JUN'97 MWD 5438.00 41 .30 178.90 94.00 4750.32 2026.35 '2027.34 '33.60 0.88 0,43 '1.17 lO'J U N'97 MWD 5534.00 41 .80 178.60 96.00 4822.17 2089.85 '2091 .00 '32.21 0.56 0.52 '0.31 11 'J UN'97 MWD 5629.00 41 .20 179.50 95.00 4893.32 2152.65 '2153.94 '31.16 0.89 '0.63 0.95 . 11 -J UN-97 MWD 5817.00 41.70 179.20 188,00 5034.23 2276.85 -2278.38 -29.75 0.29 0.27 -0.16 11-JUN-97 MWD 5911.00 42.10 180.30 94.00 5104.20 2339.52 -2341.16 -29.48 0.89 0.43 1.17 -- 11 -JUN-97 MWD 6009,00 41.50 179.90 98.00 5177.25 2404.76 -2406.48 -29.59 0.67 -0.61 -0.41 11 -JU N-97 MWD 6196.00 42,60 180.20 187.00 5316.11 2529.84 -2531.72 -29.71 0.60 0.59 0.16 11-JUN-97 MWD 6288.00 42.50 180.20 92.00 5383.89 2591.98 -2593.94 -29.92 0.11 -0,11 0.00 11 -JUN-97 MWD 6383.00 43.10 179.80 95.00 5453.59 2656.44 -2658,48 -29.92 0.69 0.63 -0.42 11 -J UN-97 MWD 6476.00 42.10 178.80 93.00 5522.05 2719,26 -2721.42 -29.16 1.30 -1,08 -1.08 -- 11-JUN-97 MWD 6569.00 42.50 178.90 93.00 5590.83 2781.69 -2784.00 -27.90 0.44 0.43 0.11 11-JUN-97 MWD 6664.00 42.40 178.40 95.00 5660.93 2845.62 -2848.10 -26.39 0.37 -0.11 -0.53 -I 11 -JUN-97 MWD 6852.00 43.70 178.50 188.00 5798.31 2973.56 -2976.39 -22.92 0.69 0.69 0.05 11 -JUN-97 MWD 6947.00 43.50 178.00 95.00 5867.11 3038.85 -3041.87 -20.92 0.42 -0.21 -0.53 -- 11 -J UN-97 MWD 7040.00 43.60 177.80 93.00 5934.51 3102.67 -3105.90 -18.57 O. 18 O. 11 -0.22 11-JUN-97 MWD 7135.O0 41.50 178.20 95.00 6004.49 3166.67 -3170.10 -16.33 2.23 -2.21 0.42 S1JR~/E~f C U IO N L H I I i I i. Job No. 0450-85473 Sidetrack No. Page 4 ' of 6 · ~ |ll~; I :(--1 Company UNOCAL Rig Contractor & No. Nabors AK Drilling - #156 Field GRANITE POINT FIELD Well Name & No. GRANITE POINT PLATFORM/GP53 Survey Section Name Definitive Survey BHI Rep. DUNN, HAMBURG WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -2425.42 __ Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W 1301.49 Magn. Declination 22.130 Calculation Method MINIMUM CURVATURE Target Direction {DD) Build\Walk\DL per: 100ft~ 30mE] 10m0 Vert. Sec. Azim. 182.98 Magn. to Map Corr. 22.130 Map North to: OTHER I i SURVEY DATA Su~ey 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-r) '(DD) (DD) (FT) (F'I') (FT) (FT) (Per 100 FT)'Drop (-) Left (-) 11 -JUN-97 MWD 7229.00 40.80 178.40 94.00 6075.27 3228.31 -3231.93 -14.49 0.76 -0.74 0.21 12-J U N-97 MWD 7512.00 40.50 177.70 283.00 6289.99 3411.99 -3416.18 -8.22. 0.19 -0.11 -0.25 '~_. 12-JU N-97 MWD 7607.00 40.40 180.30 95.00 6362.28 3473.46 -3477.79 -7.15 1.78 -0.11 2.74 j -- 12-J U N-97 MWD 7702.00 40.70 180.00 95.00 6434.47 3535.15 -3539.55 -7.31 0.38 0.32 -0.32 12-JU N-97 MWD 7797.00 40.50 180.80 95.00 6506.60 3596.91 -3601.37 -7.74 0.59 -0.21 0.84 12-J U N-97 MWD 7891.00 39.90 181.00 94.00 6578.40 3657.54 -3662.04 -8.69 0.65 -0.64 0.21 12-J U N-97 MWD 7986.00 40.10 181.60 95.00 6651.1 7 3718.58 -3723.09 -10.08 0.46 0.21 0.63 12-JU N-97 MWD 8127.00 41.00 181.70 141.00 6758.31 3810.22 -3814.71 -12.72 0.64 0.64 0.07 12-JUN-97 MWD 8330.00 39.80 180.40 203.00 6912.90 3941.70 -3946.25 -15.15 0.72 -0.59 -0.64 12-J U N-97 MWD 8447.00 39.00 180.80 117.00 7003.31 4015.90 -4020.51 -15.92 0.72 -0.68 0.34 12-JUN-97 MWD 8540.00 39.00 181.90 93.00 7075.58 4074.40 -4079.02 -17.30 0.74 0.00 1.18 · 12-JUN-97 MWD 8634.00 39.20 182.00 94.00 7148.53 4133.68 -4138.27 -19.32 0.22 0.21 0.11 12-J U N-97 MWD 8732.00 39.70 184.60 98.00 7224.21 4195.93 -4200.42 -22.91 1.76 0.51 2.65 12-JU N-97 MWD 8780.00 40.00 184.80 48.00 7261.06 4226.68 -4231.08 -25.43 0.68 0.62 0.42 -- 12-JUN-97 MWD 8875.00 39.80 184.90 95.00 7333.94 4287.58 -4291.79 -30.58 0.22 -0.21 0.11 I) ' 14-J U N-97 MWD 9093.00 40.40 184.70 218.00 7500.69 4427.93 -4431.72 -42.33 0.28 0.28 -0.09 14-JU N-97 MWD 9193.00 41.70 185.80 100.00 7576.11 4493.54 -4497.11 -48.35 1.49 1.30 1.10 14-J UN-97 MWD 9276.00 42.70 186.60 83.00 7637.59 4549.21 -4552.54 -54.37 1.37 1.20 0.96 -- 14-J UN-97 MWD 9369.00 43.30 186.50 93.00 7705.61 4612.51 -4615.55 -61.61 0.65 0.65 -0.11 14-J UN-97 MWD 9461.00 43.00 186.60 92.00 7772.73 4675.31 -4678.06 -68.78 0.33 -0.33 0.11 14-J UN-97 MWD 9555.00 43.50 187.20 94.00 7841.20 4739.56 -4742.00 -76.52 0.69 0.53 0.64 -- 14-J U N-97 MWD 9646.00 43.50 187.40 91.00 7907.21 4802.03 -4804.13 -84.48 O. 15 0.00 0.22 14-JU N-97 MWD 9740.00 43.50 188.00 94.00 7975.39 4866.51 -4868.25 -93.15 0.44 0.00 0.64 14-JUN-97 MWD 9831.00 44.00 189.00 91.00 8041.13 4929.14 -4930.49 -102.45 0.94 0.55 1.10 I ;,' ~'-'"~'"-=---~ S'UH'VE¥ (JAL[,;uLA1 I(J'N ,AND FI'ELD 'V~(JRKSHE..ET Job No. ;450-;5473' ;idetr~,c~No. Page B:tlr~:l:~l Company UNOCAL Rig Contractor & No. Nabors AK Drilling - #156 Field GRANITE POINT FIELD Well Name & No. GRANITE POINT PLATFORM/GP53 Survey Section Name Definitive Survey BHI Rep. DUNN, HAMBURG WELL DATA Target TVD __(FO Target Coord. N/S Slot Coord. N/S -2425.42 Grid Correction 0.000 Depths Measured From: RKB ~.-J MSL~ SS[ Target Description Target Coord. E/W Slot Coord. E/W 1301.49 Magn. Declination 22.130 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 182.98 Magn. to Map Corr. 22.130 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 (ET) (DD) (DD) (ET) (F'r) (ET) (FT) (Per 100 FO Drop (-) Left (-) 14-JUN-97 MWD 9923.00 42.30 188.00 92.00 8108.24 4991.77 -4992.71 -111.76 1.99 -1.85 -1.09 14-JUN-97 MWD 10017.00 42.50 188.60 94.00 8177.66 5054.88 -5055.43 -120.91 0.48 0.21 0.64 15-JUN-97 MWD 10120.00 42.50 188.90 103.00 8253.60 5124.11 -5124.20 -131.50 0.20 0.00 0.29 15-JUN-97 MWD 10201.00 42.70 189.00 81.00 8313.22 5178.64 -5178.36 -i 40.03 0.26 0.25 0.12 15-JUN-97 MWD 10293.00 42.60 188.70 92.00 8380.89 5240.65 -5239.95 -149.62 0.25 -0.11 -0.33 15-JUN-97 MWD 10387.00 42.70 189.10 94.00 8450.03 5303.99 -5302.87 -159.47 0.31 0.11 0.43 15-JUN-97 MWD 10479.00 42.60 189.30 92.00 8517.70 5365.96 -5364.40 -169.44 O. 18 -0.11 0.22 15-JUN-97 MWD 10573.00 42.30 190.00 94.00 8587.05 5428.97 -5426.95 -180.07 0.60 -0.32 0.74 15-JUN-97 MWD 10633.00 41.70 190.60 60.00 8631.64 5468.79 -5466.45 -187.25 1.20 -1.00 1.00 16-JU N-97 MWD 10784.00 42.40 192.40 151.00 8743.77 5568.80 -5565.54 -207.42 0.92 0.46 1.1 9 16-JU N-97 MWD 10876.00 42.70 192.70 92.00 8811.55 5630.15 -5626.27 -220.94 0.39 0.33 0.33 17-J U N-97 MWD 10968.00 42.40 192.00 92.00 8879.32 5691.53 -5687.04 -234.24 0.61 -0.33 -0.76 17-JUN-97 MWD 11060.00 42.90 191.00 92.00 8946.99 5753.17 -5748.12 -246.67 0.92 0.54 -1.09 17-JUN-97 MWD 11153.00 42.80 190.60 93.00 9015.17 5815.83 -5810.25 -258.52 0.31 -0.11 -0.43 ..-._- 17-JU N-97 MWD 11246.00 42,50 190.30 93.00 9083.58 5878,31 -5872.21 -269.95 0.39 -0,32 -0.32 17-JUN-97 MWD 11338.00 42.20 190.00 92.00 9151.57 5939.80 -5933,22 -280.87 0.39 -0.33 -0.33 17-JU N-97 MWD 11431.00 42.80 187.40 93.00 9220.14 6002.30 -5995.32 -290.37 2.00 0.65 -2.80 ..... 17-JUN-97 MWD 11523.00 42.80 187.40 92.00 9287.64 6064,63 -6057.30 -298.42 0.00 0.00 0.00 -.' 17-J U N-97 MWD 11616.00 41.50 187.50 93,00 9356.59 6126.85 -6119.19 -306.51 1.40 -1.40 0.11 17-J U N-97 MWD 11710.00 41.40 187.60 94.00 9427.05 6188.87 -6180.87 -314.68 0,13 -0.11 0,11 17-J U N-97 MWD 11804.00 40.60 187.00 94.00 9497.99 6250.37 -6242.04 -322.52 0.95 -0.85 -0.64 17-J U N-97 MWD 11899.00 40.90 187.40 95.00 9569.96 6312.21 -6303.56 -330.29 0.42 0.32 0.42 18-JUN-97 MWD 11990.00 40.70 187.00 91.00 9638.84 6371.51 -6362.56 -337.75 0.36 -0.22 -0.44 18-JUN-97 MWD' 12084.00 41.40 186.80 94.00 9709.73 6433.10 -6423.84 -345.16 0.76 0.74 -0.21 lIB_, r~ ::~.__-~ UNOCAL Contractor & No. Nabors AK #156 Field GRANITE POINT FIELD Company Rig Drilling- I ;I Well Name & No. GRANITE POINT PLATFORM/GP53 Survey Section Name Definitive Survey BHI Rep. DUNN, HAMBURG WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -2425.42 Grid Correction 0.000 Depths Measured From: RKB ~} MSLE] SS['. Target Description Target Coord. E/W Slot Coord. E/VV 1301.49 Magn. Declination 22.130 Calculation Method MINIMUM CURVATURE Target Direction (OD) Build\Walk\D/per: lOOff~ 30m0 10m~ Vert. Sec. Azim. 182.98 Magn. to Map Corr. 22.130 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 (FT) (DD) (DD) (ET) (FT) (FT) (F'r) (Per tOO F'r)Drop (-) Left (-) __ 19-JUN-97 MWD 12208.00 42.30 186.40 124.00 9802.10 6515.66 -6506.02 -354.67 0.76 0.73 -0.32 19-JUN-97 MWD 12271.00 43.70 186.90 63.00 9848.17 6558.54 -6548.70 -359.65 2.29 2.22 0.79 'il 19-JUN-97 MWD 12364.00 44.90 186.90 93.00 9914.73 6623.34 -6613.18 -367.45 1.29 1.29 0.00 19-JUN-97 MWD 12457.00 45.90 187.80 93.00 9980.03 6689.36 -6678.85 -375.93 1.28 1.08 0.97 20-JUN-97 MWD 12550.00 47.60 186.10 93.00 10043.75 6756.93 -6746.08 -384.11 2.26 1.83 -1.83 20-JUN-97 MWD 12644.00 49.60 186.30 94.00 10105.91 6827.33 -6816.18 -391.72 2.13 2.13 0.21 -- 20-JUN-97 MWD 12736.00 52.40 186.70 92.00 10163.81 6898.68 -6887.21 -399.82 3.06 3.04 0.43 20-JUN-97 MWD 12828.00 53.20 187.30 92.00 10219.43 6971.78 -6959.94 -408.75 1.01 0.87 0.65 21 -JUN-97 MWD 13016.00 59.20 186.50 188.00 10323.97 7127.57 -7114.97 -427.48 3.21 3.19 -0.43 21-JUN-97 MWD 13108.00 60.40 186.40 92.00 10370.24 7206.93 -7193.98 -436.41 1.31 1.30 -0.11 -- 21 -JUN-97 MWD 13202.00 61.60 185.80 94.00 10415.81 7289.03 -7275.72 -445.14 1.39 1.28 -0.64 22-JUN-97 MWD 13265.00 62.30 185.70 63.00 10445.44 7344.56 -7331.04 -450.71 1.12 1.11 -0.16 -- 22-JUN-97 MWD 13295.00 63.10 185.80 30.00 10459.20 7371.19 -7357.57 -453.38 2.68 2.67 0.33 .,, 26-JUN-97 MWD 13401.00 62.40 185.70 106.00 10507.73 7465.31 -7451.33 -462.82 0.67 -0.66 -0.09 26-JUN-97 MWD 13432.00 62.00 186.50 31.00 10522.19 7492.69 -7478.59 -465.74 2.62 -1.29 2.58 26-JUN-97 MWD 13471.00 62.10 186.90 39.00 10540.47 7527.07 -7512.81 -469.76 0.94 0.26 1.03 .. 26-JUN-97 MWD 13493.00 62.10 187.40 22.00 10550.77 7546.46 -7532.10 -472.18 2.01 0.00 2.27 26-JUN-97 MWD 13537.00 61.10 186.10 44.00 10571.69 7585.08 -7570.54 -476.73 3.45 -2.27 -2.95 26-JUN-97 MWD 13585.00 61.00 186.80 48.00 10594.93 7627.01 -7612.27 -481.45 1.29 -0.21 1.46 27-J U N-97 MWD 13607.00 60.80 186.30 22.00 10605.63 7646.19 -7631.37 -483.64 2.18 -0.91 -2.27 28-J U N-97 MWD 13681.00 59.80 187.40 74.00 10642.29 7710.32 -7695.19 -491.30 1.87 -1.35 1.49 28-JU N-97 MWD 13774.00 56.10 187.60 93.00 10691.63 7788.89 -7773.32 -501.59 3.98 -3.98 0.22 28-JU N-97 MWD 13866.00 50.00 191.10 92.00 10746.92 7861.91 -7845.83 -513.43 7.29 -6.63 3.80 ~-~-JuN-97 MWD 13950.00 45.00 191.10 84.00 10803.65 7923.20 -7906.58 -525.35 5.95 -5.95 0.00 Projected Data - NO SURVEY r--'-,..,SURVEYCALC LATONA DFI DWORK$ r--m r--m ' ~,r~ Job No. 0450-85473 Sidetrack No..1. ......... Page · = [1[~-= I ::(---1! Company UNOCAL Rig Contractor & No. Nabors AK Drilling - #156 Field GRANITE POINT FIELD Well Name & No. GRANITE POINT PLATFORM/GP53 Survey Section Name Definitive Survey BHI Rep. DUNN, MAPES WELL DATA Target TVD (FO Target Coord. N/S Slot Coord. N/S -2425.42 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. ENV Slot Coord. E/W 1301.49 Magn. Declination 22.130 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m~ lOmr-] Vert. Sec. Azim. 182.98 Magn. to Map Corr. 22.130 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 (Fl') (DD) (DD) (Fl'} (Fl') (Fl") (F'F) (Per ~00 FO Drop (-) Left (-) MWD 13866.00 50.00 191.10 10746.90 7862.65 -7845.81 -513.44 TIE IN POINT 02-JUL-97 MWD 13881.00 47.60 189.10 15.00 10756.78 7873.09 -7856.92 -515.42 18.88 -16.00 -13.33 I, 03-JUL-97 MWD 13929.00 43.70 187.90 48.00 10790.33 7907.25 -7890.86 -520.51 8.32 -8.13 -2.50 03-JUL-97 MWD 14022.00 40.40 186.90 93.00 10859.38 7969.34 -7952.61 -528.54 3.62 -3.55 -1.08 .... 03-JUL-97 MWD 14115.00 39.40 187.00 93.00 10930.72 8028.85 -8011.83 -535.76 1.08 -1.08 0.11 04-JUL-97 MWD 14208.00 39.00 188.20 93.00 11002.79 8087.43 -8070.09 -543.53 0.92 -0.43 1.29 04-JUL-97 MWD 14300.00 37.20 187.90 92.00 11075.19 8143.98 -8126.30 -551.49 1.97 -1.96 -0.33 .... 04-JUL-97 MWD 14393.00 36.50 187.90 93.00 11149.61 8199.54 -8181.54 -559.15 0.75 -0.75 0.00 04-JUL-97 MWD 14463.00 33.80 190.50 70.00 11206.84 8239.60 -8221.32 -565.56 4.41 -3.86 3.71 04-JUL-97 MWD 14503.00 33.10 190.60 40.00 11240.22 8261.46 -8242.99 -569.60 1.76 -1.75 0.25 ., 08-JUL-97 MWD 14556.00 32.50 190.60 53.00 11284.77 8289.91 -8271.21 -574.88 1.13 -1.13 0.00 Projected Data - NO SURVEY __ .--._ _ ,, ,--. · , __ ~- SUHVEY ~JALC-ULATI'ON/~ FIELD W'O~KSHEET' -Job No. 0450-85473 No. 2 ~ Sidetrack Page 1 of 3 ~,~ ll,r~ = I Company UNOCAL Rig Contractor & No. Nabors AK Drilling - #156 Field GRANITE POINT FIELD Well Name & No. GRANITE POINT PLATFORM/GP53 Survey Section Name Definitive Survey BHI Rep. DUNN, HAMBURG i J~N~rL/=~ ..... WELL DATA ~ Target TVD (F~) Target Coord. N/S Slot Coord. N/S __ -2425.42 Grid Correction 0.000 Depths Measured From: RKB ~ MSLE} SS[--] Target Description Target Coord. E/W Slot Coord. E/W 1301.49 Magn. Declination 22.130 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mE~ lomE] Vert. Sec. Azim. 182.98 Magn. to Map Corr. 22.130 Map North to: OTHER i i 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 (FT) (DD) (DD) (FO (FI') (FI') (FI') (Per ~00 F'r)Drop (-) Left (-) MWD 13295.00 63.10 185.80 10459.21 7371.99 -7357.45 -453.93 TIE IN POINT 07-JUL-97 MWD 13369.00 64.00 186.40 74.00 10492.17 7437.25 -7423.33 -460.97 1.42 1.22 0.81 13375.00 64.80 186.90 6.00 10494.76 7442.65 -7428.70 -461.60 15.31 13.33 8.33 07-JUL-97 MWD 15-JUL-97 MWD 13384.00 66.00 185.90 9.00 10498.51 7450.82 -7436.83 -462.51 16.73 13.33 -11.11 16-JUL-97 MWD 13404.00 69.30 184.10 20.00 10506.11 7469.30 -7455.26 -464.12 18.48 16.50 -9.00 17-JUL-97 MWD 13429.00 72.80 181.50 25.00 10514.23 7492.94 -7478.87 -465.27 17.11 14.00 -10.40 17-JUL-97 MWD 13454.00 75.00 181.60 25.00 10521.17 7516.95 -7502.88 -465.92 8.81 8.80 0.40 17-JUL-97 MWD 13466.00 75.70 182.20 12.00 10524.20 7528.56 -7514.48 -466.30 7.58 5.83 5.00 17-JUL-97 MWD 13500.00 77.30 182.40 34.00 10532.14 7561.62 -7547.51 -467.63 4.74 4.71 0.59 17-JUL-97 MWD 13528.00 78.30 181.60 28.00 10538.05 7588.98 -7574.86 -468.58 4.53 3.57 -2.86 17-JUL-97 MWD 13559.00 78.70 182.10 31.00 10544.23 7619.35 -7605.23 -469.56 2.04 1.29 1.61 17-JUL-97 MWD 13589.00 78.40 181.20 30.00 10550.19 7648.75 -7634.62 ~470.41 ' 3.11 -1.00 -3.00 17-JUL-97 MWD 13623.00 78.50 181.60 34.00 10557.00 7682.05 -7667.92 -471.23 1.19 0.29 1.18 -- 18-JUL-97 MWD 13651.00 78,50 181.70 28.00 10562.58 7709.48 -7695.34 -472.02 0.35 0.00 0.36 18-JUL-97 MWD 13685.00 79.00 181.90 34.00 10569.21 7742.82 -7728.67 -473.06 1.58 1.47 0.59 18-JUL-97 MWD 13717.00 79.40 182.40 32,00 10575.21 7774.25 -7760.09 -474.24 1.98 1.25 1.56 18~JUL-97 MWD 13744.00 79.90 184.20 27.00 10580.06 7800.81 -7786.60 -475.77 6.81 1.85 6.67 18-JUL-97 MWD 13779.00 80.30 183.90 35.00 10586.08 7835.28 -7820.99 -478.21 1.42 1.14 -0.86 18-JUL-97 MWD 13809.00 80.50 185.00 30.00 10591.08 7864.85 -7850.48 -480.50 3.68 0.67 3.67 18-JUL-97 MWD 13837.00 80.20 186.30 28.00 10595.77 7892.42 -7877.95 -483.22 4.70 -1.07 4.64 18-JUL-97 MWD 13862.00 80.20 187.00 25.00 10600.03 7917.01 -7902.42 -486.07 2.76 0.00 2.80 19-JUL-97 MWD 13930.00 80.60 188.60 68.00 10611.37 7983.81 -7968,85 -495.17 2.39 0.59 2.35 19-JUL-97 MWD 14109.00 78.30 187.10 179.00 10644.14 8159.13 -8143.15 -519.21 1.53 -1.28 -0.84 19-JUL-97 MWD 14202.00 77.40 186.30 93.00 10663.72 8249.86 -8233.45 -529.82 1.28 -0.97 -0.86 ~J,,~rr,,~J ,~,~nYr_,! g~-~L~,~,~ I lUI~I ~'~I~iU rlr, LU ¥¥un~.,..~ ir-r, ~ JobNo. 0450-85473 Sidetrack No. 2 Page 2 of 3 ~- ~ ~---.~~[1[~,"1 Company UNOCAL Rig Contractor & No. Nabors AK Drilling - #156 Field GRANITE POINT FIELD Well Name & No. GRANITE POINT PLATFORM/GP53 Survey Section Name Definitive Survey BHI Rep. DUNN, HAMBURG I~ ...... WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -2425.42 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SSE Target Description Target Coord. LAN Slot Coord. E/W 1301.49 Magn. Declination 22.130 Calculation Method MINIMUM CURVATURE Target Direction (on) Build\Walk\DL per: 100ft[~ 30m[~ lOmr-] Vert. Sec. Azim.. 182.98 Magn. to Map Corr. 22.130 Map North to: OTHER ........... suR'VEY D/~TA ............ Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool "N'(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type Depth Angle Direction Length TVD Section (FT) . (DD) .. (913) (F-r) (F-r) (F-T) (F-T) (Per 100 F-r)Drop (-) Left (-) I 20-JUL-97 MWD 14295.00 76.00 185.00 93.00 10685.11 8340.26 -8323.51 -538.73 2.03 -1.51 -1.40 20-JUL-97 MWD 14325.00 76.80 184.20 30.00 10692.17 8369.41 -8352.57 -541.07 3.72 2.67 -2.67 21-JUL-97 MWD 14387.00 75.20 183.00 62.00 10707.17 8429.56 -8412.61 -544.85 3.19 -2.58 -1.94 21 -JUL-97 MWD 14415.00 77.20 183.50 28.00 10713.84 8456.75 -8439.76 -546.39 7.35 7.14 1.79 21-JUL-97 MWD 14455.00 78.70 184.70 40.00 10722.19 8495.86 -8478.77 -549.19 4.76 3.75 3.00 21-JUL-97 MWD 14480.00 79.40 185.00 25.00 10726.94 8520.39 -8503.23 -551.27 3.04 2.80 1.20 ....., 21-JUL-97 MWD 14513.00 80.30 184.80 33.00 10732.76 8552.85 -8535.59 -554.04 2.79 2.73 -0.61 21-JUL-97 MWD 14530.00 81.20 184.70 17.00 10735.49 8569.63 -8552.31 -555.43 5.33 5.29 -0.59 21-JUL-97 MWD 14558.00 82.50 184.30 28.00 10739.46 8597.33 -8579.95 -557.60 4.85 4.64 -1.43 21 -JUL-97 MWD 14572.00 82.70 184.40 14.00 10741.26 8611.21 -8593.79 -558.66 1.59 1.43 0.71 ,, . 22-JUL-97 MWD '14604.00 83.10 184.40 32.00 10745.22 8642.96 -8625.45 -561.09 1.25 1.25 0.00 -, __ · 22-JUL-97 MWD 14635.00 84.00 184.90 31.00 10748.70 8673.75 -8656.15 -563.59 3.32 2.90 1.61 ., 22-JUL-97 MWD 14665.00 84.00 184.80 30.00 10751.84 8703.57 -8685.88 -566.11 0.33 0.00 -0.33 · 23-JUL-97 MWD 14757.00 84.20 185.30 92.00 10761.29 8795.02 -8777.04 -574.17 0.58 0.22 0.54 '.'_-.~' 23-JUL-97 MWD 14787.00 83.90 183.70 30.00 10764.40 8824.85 -8806.78 -576.51 5.40 -1.00 -5.33 23-JUL-97 MWD 14851.00 84.30 '184.10 64.00 10770.98 8888.50 -8870.30 -580.84 0.88 0.63 0.63 ......... 23-JUL-97 MWD 14944.00 83.70 179.60 93.00 10780.71 8980.95 -8962.71 -583.83 4.86 -0.65 -4.84 ~. ~-_.. ~'-"-~ 24-JUL-97 MWD 15035.00 83.00 179.30 91.00 10791.25 9071.16 -9053.10 -582.96 0.84 -0.77 -0.33 ::,_-, ' 24-JUL-97 MWD 15095.00 83.10 179.00 60,00 10798.51 9130.59 -9112.65 -582.08 0.52 0.17 -0,50 24-JUL-97 MWD 15128.00 83.00 179.50 33.00 10802.50 9163.28 -9145.41 -581.65 1.53 -0.30 1.52 ~ ' ' -r', 24-JUL-97 MWD 15220.00 83.10 179.20 92.00 10813.63 9254.42 -9236.72 -580.61 0.34 0.11 -0.33 24-JUL-97 MWD 15314.00 83.00 179.60 · 94.00 10825.01 9347.54 -9330.03 -579.63 0.44 -0.11 0.43 -- 24-JUL-97 MWD 15406.00 82.70 180.80 92.00 10836.46 9438.72 -9421.31 -579.95 1.33 -0.33 1.30 25-JUL-97 MWD 15499.00 81.50 181.50 93.00 10849.24 9530.79 -9513.41 -581.80 1.49 -1.29 0.75 i i ii Company UNOCAL Rig Contractor & No. Nabors AK Drilling - #156 Field GRANITE POINT FIELD WeJl Name & No. GRANITE POINT PLATFORM/GP53 Survey Section Name Definitive Survey BHI Rep. DUNN, HAMBURG #J TL=k WELL DATA Target TVD (FO Target Coord. N/S Slot Coord. N/S -2425.42 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ SS~ :Target Description Target Coord, E/W Slot Coord. E/W 1301,49 Magn. Declination 22.130 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build\Walk\DL per: 100ft~ 30m[~ 10m0 Vert. Sec. Azim. 182.98 Magn. to Map Corr, 22,130 Map North to: OTHER i ii i iii i i i 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 (FO (DD) (DD) (FO (FO (FT) (ET) (Per ~oo FO Drop (-) Left (-) 25-JUL-97 MWD 15592.00 82.00 183.10 93.00 10862.59 9622.82 -9605.37 -585.49 1.79 0.54 1.72 2~-JUL-97 MWD 15685.00 80.10 182.00 93.00 10877.05 9714.67 -9697.14 -589.58 2.35 -2.04 -1.18 I/- 26-JUL-97 MWD 15777.00 78.70 182.00 92.00 10893.98 9805.09 -9787.51 -592.74 1,52 -1.52 0.00 26-JUL-97 MWD 15869.00 78.80 183.20 92.00 10911.93 9895.32 -9877.65 -596.83 1.28 0.11 1.30 -- 27-JUL-97 MWD 15962.00 78.40 184.10 93.00 10930.31 9986.48 -9968.63 -602.6'4 1.04 -0.43 0.97 27-JUL-97 MWD 16055.00 77.80 184.40 93.00 10949.49 10077.46 -10059.38 -609.38 0.72 -0.65 0.32 28-JUL-97 MWD 16148.00 78.30 182.30 93.00 10968.74 10168.43 -10150.20 -61'4.69 2.27 0.54 -2.26 ,, 28-JUL-97 MWD 16240.00 78.10 183.40 92.00 10987.56 10258.49 -10240.14 -619.17 1.19 -0.22 1.20 28-JUL-97 MWD 16333.00 78.10 183.00 93.00 11006.74 10349.49 -10331.00 -624.25 0.42 0.00 -0.43 28-JUL-97 MWD 16363.00 78.90 182.90 30.00 11012.72 10378.88 -10360.36 -625.76 2.69 2.67 -0.33 28-JUL-97 MWD 16426.00 78.70 184.20 63.00 11024.95 10440.68 -10422.04 -629.59 2.05 -0.32 2.06 , 28-JUL-97 MWD 16519.00 79.20 183.20 93.00 11042.78 10531.95 -10513.13 -635.48 1.18 0.54 -1.08 29-JUL-97 MWD 16579,00 79.30 183.80 60.00 11053.97 10590,89 -10571.96 -639.08 1.00 0.17 1,00 29-JUL-97 MWD 16657.00 78.20 183.00 78.00 11069.19 10667.39 -10648.33 -643.62 1.73 -1.41 -1.03 Projected Data - NO SURVEY -- i II UNOCAL G~ANITE FO~NT Grantte Point FieLd Cook InteL, ALaska PROPOSAL LI~TING B,ker Hu~hem INTEQ Y~u~ ret i 0P$3 Version #13 Our r~f ~ prop2OSB Llcenee = Dace prtnt~cl ; 2~-Feb.97 Da%e created: II-Feb-9? Laat rev{sad t 25-Feb-g7 FieLd Structure ta centred on r~Q 57 $2.7&5,,151 20 Z0.066 SLot Location IQ r~O 57 28.8~1,w151 19 53.708 SLot Grid coord?nates are N 254G505.769, E 263333.783 SLot Local cmordtnites are Z4ZS.~2 S 1301,49 E Projection typ~: alaska - Zone 4, Spaorotd: CLarke - 1~6 Reference North I$ Tru~ North IU:~Uf-ZOf-OOZI ,.LO UNOCAL PROPOSAL LISTING Page I Your ref : 0P53 Version #13 Lest revlsed : 25-Feb-97 Measured lfl¢ltn, Azi~th TrUe Vert R E ¢ T A N G U L A R Dogleg Vert Oepth Degrees Degrees ~epth ¢ 0 0 R D ! N A T E S Oeg/lOOft Sect 0.00 0.00 0.00 O.O0 0,00 H 0,00 E 0.00 O.O0 100,00 0.00 177,00 100.00 0.00 N 0,00 E 0.00 0.00 ~00,00 0,00 17T.00 200.00 0,00 N 0.00 E 0.00 O.O0 $00.00 0.00 177,00 300.00 0.00 N O,OOl 0.00 0,00 400.00 0,00 177.1)0 400.00 0.00 N 0,00 E 0.00 0,00 500,00 0,00 17T.00 500.00 0.00 H 0,00 E 0,00 0.00 600.00 1,00 177,00 S99.99 0.8? $ 0.05 E 1.00 0.8? 700.00 2,00 177.00 699.96 3,~9 $ 0,18 E 1.00 3,~7 1000.00 2.00 17T,00 999,78 13,94 g 0,73 E 0,00 13.88 1100,00 1.00 177,00 10W.74 16.56 S 0.8r E 1,00 16.49 1200.00 0.00 177.00 1199.7& 17,&3 s 0,91 E 1,00 17.36 1625,00 0.00 17T. 00 1424,74 ~7,43 $ 0.91 I O.O0 17.36 KOP 1525.00 Z,50 177.00 1524,70 19,60 $ 1,03 I ~,50 19.52 16Z5.00 5.00 177.00 1624.48 26,1& $ 1,3r; 2,50 ~6.03 17~5,00 ?.50 177,00 1723.68 37,01 S 1,9~ E 2.50 36,86 1825.00 10,00 177.00 18~2.T1 5Z.20 $ ~,7~ I 2.50 5t.98 1925.00 12.50 177,00 1920.78 71.68 S 3,76 E 2,50 71.38 2025.00 15.00 177.00 2017.91 95.&1 S 5,00 E ~,50 95,02 21~5,00 17,50 177,00 2113,90 123.35 S 6.~6 E 2.$0 122.85 2225,00 20.00 177.00 2208.59 155.45 S 8.15 E 2,50 156,8t 2325,00 22.50 1]'7.00 2301.78 191.60 8 IO,OG E 2.50 190,8& 2&L~.0a 25.00 177,00 ~393.3~ 231,86 $ 12.15 E 2,50 2~0.91 2525.00 27,50 ~77.00 2&B2.99 276,02 S l&,&7 E 2.50 27~,89 2625.00 30.00 177.00 2570.65 32~.05 S 16,98 E 2.50 322.73 2725.00 ~2.50 177.00 2656,1~ 375.886 $ 19,TO E 2,50 37~.32 2825,00 35,00 177,00 2739.28 431.33 S 22,61 E Z,SO 629,57 2925.00 37.50 17T,00 2819,91 690.38 g ~5.70 E 2,50 4~8.$7 3025.00 40.00 177.00 289?,90 S~2.88 $ 28.9B E 2.50 550.61 3105,00 &2.00 17r,00 2958,27 605.29 S 31.7~ E 2.50 60Z.81 EOC 3500.00 ~2,00 q77.00 3251,81 &69.23 $ ~5.55 E 0.00 &65.67 4000,00 &Z,O0 177.00 3623,39 12~.3~ S 6~.06 E 0,00 1198,41 ~500.00 42,00 177,00 399&.96 t537,~5 $ 80.57 E 0,00 1531.15 &60C).O0 &1.96 17B,49 ' 4069.30 160~.28 S 83,20 E 1.00 1597.75 4700.00 41,94 179.99 4143.67 1671.12 $ 8~,09E 1.00 1~6~.45 4800.00 41,94 181.~9 6218.06 1737,9~ S 83.Z3 E 1,00 ~731.23 4900,00 &I.96 182.98 G292,&~ 1806.73 $ 80,6Z E 1,00 1798.07 5000,00 41.99 18~,48 6366.78 1871,66 S 76.27 E 1,00 t86/+.94 5019.93 4Z.O0 1~.?? 6~81.59 18~.76 S 75.20 I 1,00 1878.27 5500.00 62.00 t~.77 4738,34 2Z0~.89 $ &B,6r E 0,00 2199.37 6000,00 &Z.O0 1~4.r7 5109.89 2538.32 $ 20.62 E 0.00 ~33.79 6500.00 42.0~ 18~,77 5481.6~ Z871.75 $ 7,22 U 0.00 2868.22 ?000,00 &Z.O0 18a.77 5852.99 3205.1B S 35,06 ~ 0.00 3202.65 7500.00 4~.00 18/,.r7 62~,5G 3538.61 ~ 62.90 ~ 0,00 3537.07 800O,O0 42.00 18~,27 6596.09 367Z,0~ S 90,74 N 0,00 3871.50 8500.00 42.00 le~,?r 6967.6~ 4205.47 s 118.59 # 0,00 A205.93 900O,O0 &2.00 18~.77 7339,19 4538.90 $ 146.63 g 0,400 4540,36 9500.00 62,00 18~,77 7710.7~ 4872,33 S 17&,27 Y 0.00 4874,78 10000,00 &2.00 18A,77 8082.29 5205,75 $ 202,1t ~ 0,00 52C~.21 10~00.00 42°00 18~.77 8~53,~ 5539.18 S 2~.95 ~ 0.00 5543.6~ 11000.00 ~,00 1~,77 ~5.40 5872,61 S 257.80 N 0,00 587~,06 Att data le In feet untess otharN{ee ate?ed, Coordfnatea frc~ slot g4-4 and TVO ~rem RKa (Rig: #156) (115.00 Ft above mean sea level), Bottom hole distance ts lO60&.&8 on nzi~h I~.~ degrees fr~ HeLthead. ~ Tote[ O~[eg for ~etL~th ts 89.~ ~grees. Vert~ca~ section la fr~ ~eL[he~ ~ ez~th qB~,~ degrees, Catcu~atl~ us~ the mlnJ~ curvature ~th~. Pres~t~ ~ Baker Hugh~ INTEO -$ ~NIb~ .%. UNOCAL ORA~ITE POINT PtatfO~,GPS$ Granite Po{hr FieLd,Cook InteL, ALaska PROPOSAL LISTING Page Z Your reft GP53 Version #1~ Last revised ~ 2S-Feb-9? Heaaured lncLln, Azleuth True Vert R E C T A N ~ U L A R DosLeg Vert D~pth Degrees Degrees Depth C 0 0 R D I N A ! E S Deg/lOOft Sect 11500.00 62.00 18~,77 9196.95 6206,0~ $ Z85,64 W 0.00 6212,49 12000.00 4Z,O0 186,77 9568.50 6539.~? S 313.68 ~ 0,00 6~46.92 12500.00 42.00 184,77 99~0.05 6872.90 S 341,~2 ~ 0.00 68al.35 13000.00 &2.00 186,77 10311,60 T206.33 ~ :569.16 # 0,00 7215,77 1303~.0~ A2.00 186.77 10336,88 7Z~9,0~ $ 371,06 g 0,00 7~38.53 13133,~ ~.00 184,7T 1040g,88 ~.85 $ ~76.7'~ g 2.00 T506.5? 13233.8~ ~,O0 1~,~ 10680.58 ~67.31 S ~2,61 g ~.OO ~.2~ 132~.~ 47.~ 1~.~ 10515,00 7~.46 S 3~5,~ ~ ~.00 r413,49 GP53 C5 Rvad lO-Feb-ST 1~.00 ~8.61 1~.65 10525.85 7415.39 S 3~,61 ~ 10.~ 7~25.46 1~.00 58.~ 1~,~ 105~,11 ?~.56 ~ 39Z,~ 10.~ ~05.83 13500,00 68.59 18,%66 10629,53 7~84.82 ~ 398.42 V 10,1)0 ?595,28 1360D.00 78,58 182.99 10657.76 7680.&? 8 &03.SO g 10,00 T691.08 13618.6~ 80.~,~ t82.91 10661,15 7698.78 $ &0/,.76 ~ 10,00 Tr09.41 Ftna( EOC 14000.00 80.4~ 182.91 10724.48 8074,36 $ 4~.85 V 0.00 8085,47 1&500,00 80.4~ 18Z.91 10807.51 8566,78 $ 468.89 Y O.OO 8576.53 15000,00 80,4.A 18Z.91 10890,5& 9059.20 S 4'r'5,9~ ~ 0,00 9071.59 15500.00 80,~ 182,91 I09T3.57 9551.62 ~ ~98.98 ~ 0,00 956~,6~ 16000.00 80,4~ 18~,91 11056.60 lOO&&.O6 S 5Z~.02 ~ 0,00 1005?,70 16351.66 ~0.~ 18~o91 111t5.00 10390.37 $ 5&1.6~ g 0,00 10&OG,68 FPS3 B/C~ Rvsd 18-Feb-9? Att date lB tn feet unless other#fas elated, Coordinates frcx~ s(ot ¢4.-4 end TVO from RK8 (Rig: #156) (115.00 Ft above mean sea LeveL) Bottom hale distance Is 10&OG,/,8 on a2lm, rth 18Z.98 degrees fr~ ~[Ihead. Total O~Leg for ~eLL~th ts 89.~ degrees. Vertical ,ectt~ la fr~ ~e[[he~ ~ Bzt~th 182,~ degrees, Catcutatt~ uses the m~n~ cu~ature ~th~, Pr~t~ Baker H~hea INTEO _ lt~ :90f-Zb f-bbZ1 UNOCAL GRR#ITE POI#! Ptatform,GP~3 Gran~e Point Fie~d,¢ook Inter, Ataska PROPOSAL LISTING Page 3 Your ret : §P53 Version Lest revised : 25-Feb-97 Constants fn~ettpath 140 TVD Rectmr~pJLar Coorc~. 1&25.00 14Z4.74 17.~3 $ 0.91E KOP ~105,00 2958.27 605,Z9 s 31.7Z t328~.86 10515.00 7403.46 $ 385.62 u GP53 C~ Rvsd tO-Feb-97 13618,64 t0661,15 7698.78 S ~O/,.Z& U Fine[ EOC 1&S51.66 11115.00 10390.37 $ 5&1,6~ U FPS] ~/C~ Rvsd tO-Feb-97 Cmstns positions tn string ~A~ mmmmmmm~mlmmmmmummmmm~r~c~-.~ Tope Top TVT) RectanguLar Coords. Bot NO got TVI) Rectengutar Coord;, Casing 0.00 0.00 0.00# O.DOE 29&.00 Z94,00 O,OON O,OOE 25" Casing 0.00 0.00 O.OON O,OOE 1~00.26 iZO0,O0 I?,&3S O.91E 13 3/8" Casing 0,00 0,00 O,OON O.OOE $700,00 3~00.4~ 100Z.585 52.$6E 9 5/8" Casing 0,00 0,00 O.OON O,OOE 15283.~ I0515.00 7403,~65 385.6~ 7' Casing Targets assoc{mted with this ueLLpath ~=~=~emlllmmmmmmlmmm~l~lmlmmm Target name Geographic Location T.V.D. RectanguLar Coordinates Revised 0P53 C5 Rv~d lO-~eb- 262797,000,2537112,000,0,0000 10515,00 7~03,46S 365.6L~d 7-;eb-gr FPS$ B/C5 Rv~d 18-Fe 862580.000,253A129,000~0.0000 II11~,00 10390,$7S 5~1.6GW li-Feb-97 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairman August 11, 1997 THRU: Blair Wondzell, P. I. Supervisor e/~ FROM: Lou Grimaldi, ~,~ SUBJECT: Petroleum Inspector FILE NO: AOJJHKEE.DOC BOP Test UNOCAL well #GP-53 Granite Point Platform Granite Point Field PTD #96-14 Monday, August 11, 1997: I witnessed the initial BOP test/Ion UNOCAL's Granite Point platform in the Granite Point Field. Nabors Alaska is utilizing the platforms rig to workover well #GP-53. 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 the following results observed. A targeted flange on the Kill line leaked and was found to be loose, once tightened the flange held "OK". The ram type preventers, HCR's and manual stack valves were tested with good results. The annular preventer, however, failed to hold its high test of 5000 psi. After cycling the bag two times, results did not improve. The stack was drained to below the element and a visual inspection was made and the element was found to be missing some rubber. The element was replaced with the spare kept onboard. Tuesday, August 12, 1997: The new element was tested this morning and although seemed to be holding better it still would allow the test pressure to bleed past it. I was scheduled to be at the Kenai Gasfield this morning for meter calibration and decided to allow for the rig crew to trouble shoot and retest this component without my presence. Later this evening I spoke with Shane Houck (UNOCAL Drilling Foreman) who told me that they exercised the new element a few more times and retested it. The retest was good and they proceeded with the workover program. I have seen this behavior in new elements before and feel confident that the redressed Annular preventer will provide satisfactory protection. As is usually the case for this rig, I found all equipment to be in good shape and with signs of regular maintenance. The problem with the annular preventer is a result of usage and hopefully now repaired will not give them more problems in the near future. During the change out of the element I made a cursory tour of the platform and found it to be clean and neat. The SVS systems all seemed to be in service. I spoke with the platform foreman, Jim Isham, about ongoing work on the platform which evident throughout. SUMMARY: I witnessed the initial BOP test on UNOCAL's Granite Point platform, well #GP-53. Two failures observed. Test Time; Six hours. Attachments:. AOJJHKEE.XLS cc: Dan Williamson (UNOCAL Drilling, Anchorage) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X Nabors Rig No. G.P PTD # 96~0014 UNOCAL Rep.: GP-53 Rig Rep.: Set @ Location: Sec. Weekly Other DATE: Rig Ph.# Shane Hauck 8/11/9 7 283-6657 Marvin Rodgers 13 T. 10N R. '/2W 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 Drl. Rig P Hazard Sec. P Quan. Test Press. P/F 1 250/3500 F I 250/5, 000 P I 250/5, 000 P 1 250/5, 000 P 1 250/5, 000 P 2 25O/5,0O0 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, O00 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 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 1800 average psi 3,000 I P 1,700 P minutes 41 sec. minutes 58 sec. P Remote: P Psig. TEST RESULTS Number of Failures: '/ ,Test Time: 6.0 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: Targeted flange on kill line leaked, found loose nuts and tightened, retested "OK". Annular preventer failed, change out element and retested, Still leaked. Notify inspector when repaired. 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) AOJJHKEE.XLS STATE OF ALASKA '- ALASKA OiL AND GAS CONSERVATION CuMMISSlON 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: x Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil 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 3980~N and 2854'N from SE corner Sec. 13, T10N, R12W, SM 53 At top of productive interval 9. Permit number 930'E and 720'N from SW corner Sec. 24, T10N, R12E, SM 96-0014 At effective depth 10. APl number 50- 733-20471-00 At total depth 11. Field/Pool 725'E and 2300'S from NW corner Sec. 25, T10N, R12E, SM Granite Point Field/Middle Kenai "C"Sands 12. Present well condition summary Total depth: measured 16,657 feet Plugs (measured) true vertical 11,071 feet Effective depth: measured 16,350 feet Junk (measured) true vertical 11,010 feet Casing Length Size Cemented Measured depth True vertical depth Structural Existing 182' 33" 229' 229' Conductor " 247' 26" 294' 294' Surface 984' 13 3/8" 383 Bbls CL "G" 1031' 1030' Intermediate 4520' 9 5/6" 460 Bbls CL "G" 4566' 4100' Production 13,278' 7" 14 Bbls CL "G" 13,323' 10,471' Liner 5038' 5" 10.6 Bbls CL "G" 11,596'-16,634' 9341'-11,067' Perforation depth: measured ,rue vertica,0 ! :""" "' ' L Tubing (size, grade, and measured depth) ,~;~U 0 .... (; ~99 Packers and SSSV (type and measured depth) '~:~,iask~ 0il & Gas Cons. ~nf-,~ r~ rC~ 13. Attachments × Description summary of proposal: Detailed operations program: BOP sketch."~' ..... 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: x Gas: Suspended: Doug Amos 8/1/97 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 A. Haines / c. t.~ litle: Drilling Manager Date: 8/4197 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. Plug integrity BOP Test Location clearance .,~¢'~"'""/c~' ~ Mechanical Integrity Test Subsequent form required 10- /'(~-~ ' David W. J0hnst0n ~ .~ ? ~,~ Approved by order of the Commissioner Commissioner Date '_ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICAT~ Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNO .AL Dale Haines Drilling Manager Tuesday, August 05, 1997 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Blair: I am sending you two completion diagrams. One completion diagram shows our original approved proposal which consisted of perforating the entire 5" liner and then running a completion packer. We then planned on running in with our 3-1/2" gas lift completion and stabbing into the production packer. We have changed our plans; and we do not want to perforate the entire interval. The plan is to perforate from 15,250' to 16,400'. Seal assembly will be stabbed into the liner hanger's tie-back receptacle to complete the well. GP 53 will be produced for approximately 2 months. We will then workover the well over and perforate the rest of the 5" line. GP 53 will then be completed as originally planned with a completion packer. If you have any questions or concerns with our proposal, please contact our Drilling Engineer Mitch Damm @ 263-7679. Thank you for your time and cooperation. Very truly, Dale A. Haines Drilling Manager GRA~ . E POINT PLATFORM WELL # 53 _ IJNOC L( ) New Completion Proposal RKB = 114.75"; 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 1,100 9-5/8 47 L-80 BTC 46 73 9-5/8 53.5 P-110 BTC 73 3,700 7" 29 P-110 KC-BTC 45 5,575 7" 29 L-80 KC-BTC 5,575 13,323 5" 15 L-80 SC-KC-BTC 12,905 16630 Baker 5" HMC liner hanger ~ 12,911 3-1/2" 9.2 L-80 BTC 44 12,911 JEWELRY DETAIL NO. ITEM DEPTH Kvaemer Tubing Hanger (AB TC-4S Up X STD VAM DWN) 2 3.6' STD VAM x Buttress Pup JT 3 HES XXO Safety Valve Landing 300 Nipple (ID = 2.813") 13 McMurry-MACCO SMO-1 Gas Lif~ Mandrels with 1" Valves: 5 HES "X" Nipple ID = 2.813" 6 Baker Oil Tools 6' Seal Assembly 12,9'11 TOL ~ 12,905 C-5 SAND PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 15,250 16,400 C-5 6 TCP PDTD = ?????? MAX HOLE ANGLE + 79 o O:kDRJLLING\SCHEMATIC\GP\GPP\Gp53 final diagram2.doc REVISED: 8/1/97 DRAWN BY: MWD GRAi. E POINT PLATFORM WELL # 53 TOL ~ 12,905 RKB -- 114.75"; 43' Rig Floor to Wellhead Kvaerner SMS Wellhead C-5 SAND 8 PDTD = ?????? 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 1,100 9-5/8 47 L-80 BTC 46 73 9-5/8 53.5 P-110 BTC 73 3,700 7" 29 P-110 KC-BTC 45 5,575 7" 29 L-80 KC-BTC 5,575 13,323 5" 15 L-80 SC-KC-BTC 12,905 16630 Baker 5" HMC liner hanger ~ 12,911 3-1/2" 9.2 L-80 BTC 44 12,911 JEWELRY DETAIL NO. ITEM DEPTH Kvaemer Tubing Hanger (AB TC-4S Up X STD VAM DWN) 3.6' STD VAM x Buttress Pup JT HES XXO Safety Valve Landing Nipple (ID: 2.813") 13 McMurry-MACCO SMO- 1 Gas Lift Mandrels with 1" Valves: HES Seal Assembly with Nitrile/Flourel molded seals HES Packer 8' Seal Bore Extension 4.4' Millout Extension HES "X" Nipple ID = 2.813" Wireline Muleshoe Re-entry Guide PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS ?????? C-5 6 TCP MAX HOLE ANGLE _+ 79 o O:XDRILLING\SCHE~TIC\GP\GPP\Gp53 f'mal diagram.doc REVISED: 8/1/97 DRAWN BY: MWD UNOCAL ) --1111 fill .._ II Ill Illl -. I Il t Granite Point #53 Drilling Program Date: 08/01/97 . Ill IlllJ [ To: AOGCC Doug Amos Fax Number: 659-2717 ...... ii ~_ iiii .__ iiii From: Fax Number: Phone: UNOCAL Alaska Drilling Mitchell Damm (907) 263-7884 (907) 263-7679 If you do not receive_3 pages including cover sheet, please call 263-7679. --- Illl Ii . lllll . _. I'l II I .. iiiiiii ilUll ._ I I ii Subject: Granite Point 53 Completion Change · lull I .... IIi Iii I .. II II Doug: Ill II ..... IIIIII I _. IIiiiiii Thank you for retttrmng my call. I am faxing you two completion diagrams. One compeltion diagram shows our original approved proposal which consisted of perforating the entire 5" liner and then running a completion packer. We then planned on running in with our 3-1/2" gas lift completion and stabbing into the production packer. We have changed ottr Plans; and we do not want to perforate the entire interval. The plan is to perforate from I5,250' to 16,400'. A seal assembly will be stabbed into the liner hanger's tie- back receptacle to complete the well. GP 53 will be produced for approximately 2 months. We will then workover the well over and perforate the rest of the 5" liaer. GP 53 will then be completed as originally planned---with a completion packer. If you have any questions or concerns with our proposal, please contact our Drilling Foreman Evan Harness ~ 776-6658. Evan can answer your questions or he can get a hold o fmc and I will call you. Currently (8/1/97 17:4Ibrd), we are drilling cement inside the 7" casing 6~ 12,100'. Thank you for your time and cooperation. FAX 39 .doc £o/to'd lid 0~:90 I~t.q L6-[0-911~ MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 8, 1997 THRU: Blair Wondzell, -~~ FILE NO: P. I. Supervisor ~¢~ FROM: Doug Amos~.,¢ SUBJECT: Petroleum Inspdctor aojhfgee.doc Confidential: Yes _, NoX, Attachment Only,~ BOPE Test, Nabors 156 GP-53 Granite Pt. Field, Granite Point Platform PTD # 96-0014 Saturday, June 8, 1997' I traveled to Union's Granite Point Platform to witness the BOPE test at well GP-53 on Nabors Rig 156. As the attached AOGCC BOPE Test Report indicates, there were no failures. I found the drilling rig in good condition and all equipment in compliance. The drilling crew was very experienced and knowledgeable about their equipment. SUMMARY: I witnessed the BOPE test at Union's Granite Point Platform GP- 53 well in. I found the rig and all equipment in compliance. Nabors Rig 156, 4 test hours, 22 valves, no failures, Attachment: AOJHFGEE.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X Workover: NABORS Rig No. 156 PTD # 96-0014 UNOCAL Rep.: GP.53 Rig Rep.: Set @ 4,551 Location: Sec. Weekly Other DATE: 6/7/97 Rig Ph.# 776-6658 Mike Williams Evan Harness 13 T. 10 N R. 12 W Meridian SM TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig OK Hazard Sec. Yes Quan. Test Press. P/F I 250/3,500 P I 250/5, OOO P 1 250/5,000 P 1 250/5,000 P 1 25O/5, O0O P 2 250/5,000 P 2 250/5,000 P N/A N/A N/A FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/5,000 P I 250/5, 000 P 2 250/5, 000 P 2 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 13 Test Pressure P/F 250/5, 000 P 34 250/5, O00 P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 3,000 I P Pressure After Closure 1,600 I P ~UD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 21 Trip Tank OK OK System Pressure Attained 3 minutes 45 Level Indicators OK OK Blind Switch Covers: Master: Yes Remote: Flow Indicator OK OK Nitgn. Btl's: 4 @ 1,900 (Avg.) Meth Gas Detector OK OK Psig. H2S Gas Detector OK OK sec. sec. Yes TEST RESULTS Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 22 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-t433 REMARKS: Rig is in good condition with a very experienced crew. Good test. Distribution: orig-Well File c o 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: Doug Amos FI-021L (Rev.12/94) AOJHFGEE.XLS Unocal Corporation Agrieukural Products 909 West 9th Avenue. P.O. Box 196247 Anchorage, Alaska 995 t 9-6247 Telephone (907) 276-7600 ?, U]/Uid UNOCAL. . Fax # March 2I, 1997 AOGCC Arm: Mr. Blair Wondzell 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzelh Currently, UNOCAL has set Granite Point 53's spud date for May 15, 1997. UNOCAL is submitting an Application for Sundry Approvals requesting a survey frequency variance (see our previous Application for Sundry Approvals concerning Granite Point 54's survey frequency). We have also changed GP 53's bottom-hole location. UNOCAL is requesting a variance from AOGCC Regulation Article 1 20 AAC25.050. Article 1 20 AAC25.050 requires surveys at least 100 ft apart while drilling Granite Point #53 (Permit # 96-0014). Since the well will be vertical down to 600 ft (MD), we would like to begin surveying at the conductor shoe, 294 tl (MD), and then survey 200 ft apart from 294 fl (hiD) to 600 .ft (MD). We would then survey every I00 ft during the build section--600 fr (MD) to 3,I05 fl (MD). We are then requesting a variance; so that we can survey at least 500 fl apart during the Sst tangent section. The first tin, gent section will start at 3,105 fl (M_D) and will end at 4,500 ft (MD). In the next tangent section from 5,019 ft (MD) to 13,283 ft (MD), we would like to survey every 500 ft. In the next tangent section from 5,019 ft (MD) to 13,283 ft (MD), we would like to survey every 500 ft. The final tangent section, from I3,618' (MD) to 16,351' (MD), we would also like to survey every 500 ft. In addition, We have changed Granite Point 53's directional program and completion design--see the attached directional' program, plat, and wellbore diagram. The new plan is to mn and cement a 5" 15 lb/fl I~80 liner rather than the 4-1/2" slotted liner. 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, Dale Haines Drilling Manager mwd Attachments CC: Mitch Datum, Dale Ha/nes, File STATE OF ALASKA - ALASKA OIL GAS CONSERVATION CL vlMISSION 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 Pulltubing: Variance: x Perforate: Other: x 2. Name of O~rator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil 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 w~ll at surface Leg 4, Slot #3 8. Well number 3980' W and 2854' N from SE corner Sec. 13, T10N, R12W, SM 53 ADL 1786/374045 At top of pro0uctive interval 9. Permit number 930' E and 720' N form SW Corner Sec. 24, T10N, R12E 96-0014 At effective depth 10. APl number 50- 733-20471 At total depth 11. Field/Pool 725' E and 2300' S from NW Corner Sec. 25, T10N, R12E Granite Point Field/Middle Kenai "C" Sands 12. Present wait condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective ciepth: measured feet Junk (measured). true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true verticalORIGINAL 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: Directional Program 14. Estimated date for commencing operation 15. Status of well classification as: March 15, 1997 16. If proposal well verbally approved: Oil: x Gas: Suspended: Name of a~13rover Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Dale Haines /,,,,)~4,~ c., ~ 1 ~,,,,, Title: Ddlling Manager Date: 2/26/97 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witneSSplug integrity.~ BOP Test Loca'don clearance IAppr°val N°'k.~ ")- ~6 Mechanical integrity Test Subsequent form required 10- ¢i/~) ~ . 0rigina! Signed By David W. Johnston ,. ,. Approved by order of the Commissioner ~F[eturrtecl commissioner Date o) ~,,~., Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICA I'E dNOCAL RKB = 114.75"; 43' Rig Floor to Wellhead TOL @ 13,200' GRANh._ POINT PLATFORM WELL # 53 PROPOSED COMPLETION 1 CASING AND TUBING DETAIL SIZE WTGRADE CONN TOP BOTTOM 33" Outside conductor 47 229 26" Inside Conductor 47 294 13-3/8 68 K-55 BTC 47 1,100 9-5/8 47 L-80 BTC 46 73 9-5/8 53.5 P-110 BTC 73 3,700 7" 29 P-110 KC-BTC 45 7,000 7" 29 L-80 TKC-BTC 7,000 13,500 5" 15 L-80 SC-KC-BTC 13,200 16,500 Baker 5" HMC liner hanger @ 13,200' 3-1/2" 9.2 L-80 SC BTC 44 13,000 JEWELRY DETAIL NO. ITEM DEPTH Kvaemer Tubing Hanger (AB TC-4S Up X STD VAM DWN) 3.6' STD VAM x Buttress Pup JT HES XXO Safety Valve Landing Nipple (ID = 2.813") 10 McMurry-MACCO SMO-2 SC Gas Lift Mandrels with 1-1/2" Valves: 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 C-5 SAND PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 13,500 16,500 C-5 6 TCP PDTD = 16,420' MAX HOLE ANGLE + 82 o O:kDRII.t.ING\SCHEMATICSGP~GPP~GP53-PR2.DOC REVISED: 2/25/97 DRAWN BY: MWD 42-2S1~ I I I I I I 1 I I I I 548T Old Lo6. ,- .. O .. 26 I I I Scale i #53e New Prop. LOC. 0 1000 2000 Feet UNOCAL GRANITE2 ., GRANITE POINT PLATF01: · , , ~' J ~ ~ ', '; /' , ., ~"'-"i" 1'2000I FEET .' --: DJI : 27-February-l' Proposed #53 Well I 300' ~2-2~R0 / / 26 12-24 " 0 .L e ~g I / I ! I ! . I i J .. ! ! ! J J I -- -- -t- I I I / ..................... #53~New Prop. Loc. Scale 0 1000 ~X)O 3000 Feel UNOCAL GRANITE2 GRANITE POINT PLATFOlgl~ 1' 12000 FEET DJI 2?-February- 1 D9r Proposed #53 Well 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 medications in the directional plans have changed the total depths slightly in each wells. We are also changing the 13-3/8" and 9-518" 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. Sincerely ..... * G. Russell Schmidt Drilling Manager MWD/leg ,,: :- :2, ii -~_.~ - _ ! .: AI $KA OIL AND GAS CONSERYATION COMMISSION TONY. KNOWLE$, GOVEF~NOF~ · , 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 · FAX: (907) 27~7642 February 22, 1996 G. Russell Schmidt, Drilling Manager Union Oil Company of Califomia (Unocal) P O Box 196247 Anchorage, AK 99519-6247 Re: Granite Point Field 53 ADL 374045 Union Oil Company of California (Unocal) Permit No 96-014 Surf Loc 2855'FSL, 3991'FEL, Sec. 13, T10N, R12W, SM Btmhole Loc 1177'FNL, 408'FWL, Sec. 25, T10N, R12W, SM Dear Mr. Schmidt: Enclosed is the approved application for permit to ddli the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by lawfrom other govemmentai agencies, and does not authorize conducting drilling 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 stdngs 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 ddiling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. Chairman ~ BY ORDER OF THE COMMISSION lencl c: Dept of Fish & Game, Habitat Section - w/o end Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Re-Entry E] Deepen r-1 Service BI Development Gas BI single Zone r-~ Multiple Zone E] 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 & 374045 4. Location of well at surface 7. Unit or property name 11.Type Bond (SEE 20 ACC 25.025) 2,855' FSL, 3,991' FEL, Sec 13, T10N, R12W, SM Granite Point Field AK Statewide Oil & Gas Bond At top of productive interval 12,500' 8. Well number Number 1,906' FSL, 685; FWL, Sec 24, TION, R12W 53 ADL 374045 U62 - 9269 At total depth 15,700' 9. Approximate spud date Amount 1,177' FNL, 408; FWL, Sec 25, T10N, R12W 2/14/95 $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 0 feet See Clearance Report feet 5089 15,700/11,477 feet 16. To be completed for deviated wells 17. Anticipated Pressure (see 20 AAC 25.035 (e)(2)) ~ ~-, 3 Kickoff depth 2,700 feet Maximum hole angle 82.8 Maximum surface ~'~ ¢-. psig At total depth (TVD) ~ 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 30561~3 12-1/4" 9-5/8" 47 L80 BTC 3500 47 47 3500 3484 4384 ft3 8-1/2" 7" 29 L-80 BTC 12,800' 47 47 12800 10241 500 ft3 6" 4-1/2" 12.6 L-80 SC-BTC 3100' 12600' 10127' 15700 11477 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 . .. ~,,.~ -, ~... ~ ~ Surface .,..~ Intermediate ~"~4,. ~¢- Production Liner .~.]~,!'i '~ 5 Perforation depth: measured See attached .. ..-: .... :-..:i~::.-:-.i O,~ ~ true vertical See attached ..... .... (.?,. ~ '-'-'~-O'S '; ;~;)i~:~;, "-/'-;~:" 20. Attachments Filing fee ['~ Property plat [~] BOP Sketch ~] Diverter Sketch U Drilling program Drilling fluid prograr~ FJ Time vs depth plot ['~ Refraction analysis E] Seabed report E] 20 AAC 25.050 requirements 21. I hereby cef~if~tha/t'~le foregoi.-6i¢~ruei~' '~'~ _~/¢.~~~~ nd~rrec.~e~b~ t of my knowledge Signed _.,~.~.~ Title Drilling Manager Date 01/15/96 Commission Use Only ~ I API number Appr_ov~l date/..~ I See cover letter Permit Number _/y 50-7,~,_~ '-" .2_ 0~z 7// I ....'~_ ,~"7--/~'~'(,,~ forother requirements Conditions of approval Samples required E] Yes [~ No Mud logrequired ' F~ Yes J~] No Hydrogen sulfidemeasures [-'l Yes ~ No Directional surveyrequired ~ Yes BI No Required working pressure for DOPEF-~ 2M; BI 3M; ~ SM; r-J 1OM; BI 15M Other: 0rigina! Signed By by theorderof /~...~ Approved by B~vid W. Jahnstorl Commissioner the commission Date ~.~ Form 10-401 Rev. 12-1-85 Unocal Corporation P. O. Box 196247 Anchorage, AK 99519 (907) 263-7679 Mitchell W. Damm Drilling Engineer UNOr. C IvED FEB 21 Alaska Oil & Gas Cons. Commission February 16, 1996 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: This letter pertains to our conversation on February 16, 1996 concerning maximum surface pressures and pressures @ TD. Could you please reflect the following changes to the Permit to Drills for Granite Point #52, #53 and #54. Block 17 should read as follows: GP #52 Maximum Surface 4605 psig At Total Depth (TVD) 5701 psig GP #53 Maximum Surface 4542 psig At Total Depth (TVD) 5623 psig GP #54 Maximum Surface 4289 psig At Total Depth (TVD) 5310 psig Thank you for your time and cooperation. Sincerely,-,/ ....... Mitchell W. Damm Drilling Engineer MWD/leg STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive ~mchorage Alaska 99501-3192 TH-E APPLICATION OF UNION OIL COMP~ OF CALII~ORNIA 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. 53 development oil well. ) Conservation Order No. 370 ) ) Union Oil Company of Califomia ) ) Gramte Point No. 53 ) ) February 16, 1996 IT APPEARING THAT: . Union Oil Company of Califomia (Unocal) submitted an application dated January 12, 1996 requesting exception to 20 AAC 25.055(a)(3) to allow drilling the Granite Point State No. 53 development oil well to a producing location that is closer than 500 feet to a drilling unit boundary. 2. Notice of opportunity for public heating was published in the Anchorage Daily News on January 19, 1996 pursuant to 20 AAC 25.540. 3. No protests to the application were received. The Unocal Granite Point State No. 53 well as proposed will be a deviated hole drilled from a surface location 2855' from the south line and 3991' from the east line of Section 13, T10N, R12W, Seward Meridian (SM) to a bottom-hole location 1177' from the north line and 408' from the west line of Section 25, 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 ofthis well. CONCLUSION: Granting a spacing exception to allow drilling of the Unocal Granite Point No. 53 well as proposed will not result in waste nor jeopardize correlative fights. Memorandum State of Alaska Oil and Gas Conservation Commission To: Commission · Fm' Staff~'~ ~ January 31, 1996 Subj: Request for Diverter Variance-- /~ Unocal Granite Pt. Platform Wells 52,53 & 54 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 5o, 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. Notice of Public Hearing STATE OF AIJASKA ~Maska Oil and Gas Conservation Commission The application of Union Off Company of California (Unocal) for exception to 20 AAC 25.055 to allow chqlling the Granite Point No. 53 development oil well. Unocal by letter dated January 12. 1996, has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling ora development oil well to the Middle Kenai oil pool in the Granite Point Field located in the Cook Inlet Basin, Southcentral Alaska. The exception would allow Unocal to directionally drill the Granite Point No. 53 development oil well to a producing location that is closer than 500 feet from a section line. The proposed surface location is 2855' 'from the south line and 3991' from the east line of Section 13, T10N, K12W, Seward Meridian (SM) and the proposed bottom-hole location is 1177' from the north line and 408' from the west line of Section 25, 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 2, 1996 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a heating 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 1:30 pm on February 20, 1996 in conformance with 20 AAC 25.540. If a heating is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433 after February 2, 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 February 12, 1996. Commissioner Alaska Oil and Gas Conservation Commission Published January 19, 1996 AO02614027 Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, RO. ~ox 196247 Anchorage, Alaska 99519-6247 UNOCAL Kevin A. Tablet Land Manager Alaska Business Unit Dear Chairman Johnson: January 12, 1995 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 GRANITE POINT #53 & #54 REOUEST FOR SPA CING EXCEPTION ADL 18761 and ADL 374045 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. 011141 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 't 6 1996 Alaska Gt & '-, G~s Cons. Ccmrnissioa 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 600' FNL 49O' 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, Enclosures Alaska oil a Gas C;on~,. uuiarn~ssion ~chor~e 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 tree. 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. Land Manager STATE OF ALASKA ) )ss THIRD JUDICIAL DISTRICT ) .~.~,~,-,..-. SUBSCRIBED TO AND SWORN before me this 12th day of January, 1996. Ill .... 6mcaE,m ' State of Alaska NOTARY PUBLIC Roxanne M. Sinz My Commleeion Exi31ree August 1, lg~7 NOTAI~Y PUBLIC IN AND THE STATE OF ALASKA_ My Commission expires: D~''/' ~ 7 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. Kov~ 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 ^]~ska Roxanne M. Sinz My Commission Expires August 1,1997 THE STATE OF ALASKA My Commission expires: ~'//- ~ ~ .JCAL GRANFI_. POINT PLATFORM WELL # 53 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 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 0 229 0 294 0 1,100 0 3,500 0 12,800 12,600 15,700 0 12,635 JEWELRY DETAIL NO. ITEM 1 SSSV 2 Camco Gas Lffi Mandrels 3 Sliding Sleeve 4 7" Packer 5 "X" Profile Nipple 6 Wireline Re-entry Guide DEPTH 300 As Required 12,525 12,555 12,605 12,635 TOL ~ 12,600' PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS SLOTYED LINER TYONEK C-5 SAND TI} = 15,700' MAX HOLE ANGLE = 82° O 5DRILLING\SCHEMATIC\GP\GPP\GP53-PRO.DOC REVISED: 11/27/95 DRAWN BY: MWD Well, South East T~ .,ek C-5) AFE 761101 Cum Time 0.5 0.5 1 1.5 1 2.5 0.5 3 2.5 5.5 1.5 7 0.5 7.5 15 22.5 0 22.5 2 24.5 12 36.5 2 38.5 I 39.5 2 41.5 2 43.5 0 43.5 0 43.5 0 43.5 2 45.5 0.5 46 0.5 46.5 Preliminary Procedure: 1 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 Ddll 12-1/4" hole to 9-5/8" csg point of approx. 3500' (ROP 1100~. 6 Run and cement 9-5/8" casing. 7 Batch drill, skid rig to next well. 8 Directionally ddll 8-112" hole from approx 3500'-13000' (Top C-5). ROP=640 fpd (all 8-1/2' hole) KOP DLS Angle Range 3500 2.5 0-45 9 No intermediate E-line logs required 10 Run & cement 7" casing. 11 Directionaily drill 6" hole from 12800'-15700'. ROP=240 fpd (all 6" hole) KOP DLS Angle Range 12800 6 45-83 12 Run drillpipe conveyed logs; DIL-GR-SP-Sonic. 13 RIH, CCH for 4-1/2" slotted liner 14 Run & install slotted liner from 12600'-15700'. 15 PU 2-7/8" tubing, RIH. Displ well to diesel & wash slotted liner. 16 17 18 19 20 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 dg. Revised 12/19/95 GRWEST.XLS Page 1 GPP 53 Grass Roots Depth VS Days 2,000 4,000 6,000 8,000 10,000 12,000 14,000 16,oOo 0 GP53DV'I'.XLS ~Drill 17-112" OH (ROP = 900') ~~- Run 13-3/8" CSGWellhead .~ Drill 12-1/4" Run 9-5/8' 10 OH (ROP = 1100') CSG Drill 8-112" '---'Estimated Depth (FT) Actual Depth (FT) OH (ROP = 640.)i Run 7' CSG Run k~s; Cl~ano~ oH; ~un ~1/2" SIo~ Line~ Run TBG 40 50 60 Days 12/19/95 ---~47' RT 114.?$' RKB ~5.75' 6~' ' 33' (~ 229' RKB (40' 294' RKB ,~ (105' BML) WELLHEAD STARTS HERE PROD DECK Top 26" @ 17'7' RKB (only on 3 Inner c, ondu~tora) TOP OF LEG (75' WATER DEPTH) SEA LEVEL (MLLW) MUD LINE Note.- Outer 9 conductom have 26" back to surface Inner 3 e/ors are different. 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 Req'd Cum Days Date Date Description of work 71 71 7/12/95 9/21/95 7 78 9/21/95 9/28/95 13 91 9/28195 10111/95 11 102 10/11/95 10122/95 2 104 10/22/95 10/24/95 65 169 10/24195 12/28/95 39 208 12/28/95 2/5/96 2 210 2/5/96 2/7/96 4 214 2/7196 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 2/27/96 311/96 2 235.5 3/1/96 3/3/96 38 273.5 3/3/96 4110/96 39.5 313 4/10196 5/20/96 38 351 5/20/96 6/27~96 18 369 6~27~96 7115~96 Mobilize I Install Rig 156 and Gdnding 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 Redrill 22-13 and complete Reddll 42-23 and complete Remove OBM and clean active/resv system Skid dg from leg #3 to #4 Batch drill well #52 to 13-3/8" csg. pt. Batch drill well #53 to 13-3/8" csg. pt. (includes rig skid) Batch drill well #54 to both 13-3/8" & 9-5/8" csg. pt. (includes rig skid) Batch drill well #53 to 9-5~8" csg. pt. (includes rig skid) Drill well #52 to 9-5~8" csg. 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 I 14 Il-la 18 T10N ~12W 11#53 + .52 + T10N R11W 19 2400 feet 600 _ - 0 _ .. o 600 _ 1200 _ 1800 _ 2400 3000 3600 4200 4800 5400 6000 6600 7200 _ 7800 _ 8400 - 9000 _ 9600 10200_ 10800_ 11400_ UNOCAL Structure : GRANITE POINT Platform Well : BP55 Field : Granlfe Point Field Lo~tion : Cook Inlet, Alaska WELL PROFILE DATA Point MD Inc Oir WD North East Deg/lO0 rte on 0 0.00 200.00 0 0 0 0.00 End of Hold 1000 0.00 200.00 1000 0 0 0.00 End of Build 1500 3.00 200.00 1300 -7 -3 1.00 End of Hold 1500 3.00 200.00 1500 -17 -6 O.OC ~. End of Drop 1800 0.00 200.00 1799 -24 -9 1.0C KOP 2700 0.00 200.00 2699 -24 -9 O.OC End of Build 4474 44.34 200.00 4501 -638 -232 2.5C End of Turn 4938 44,34 183.34 4635 --954 --297 2.5C Tie ontarget 12775 44.34 183.34 10240 -6421 -616 O.OC Begin Turn to Target End of Build 13417 82,82 185.42 10520 -6984 -661 6.0~ Jorget 15775 82.82 185.42 10815 -9312 -882 O.OC Created by: jones For:M D~ I Dote plo~ed : 2-Jan-g6 IP~ot Reference is GP53 Va~ion ~4. ~URFA~ ~OCATIO~ Begin Nudge 1.00 Ilcoordinot~ ore in feet reference slot ~8. 2424' FNL, 1290' ~L 2'00 End ~gle Build I ,T~e Ve~col Depths ore refer~pce RKB (Rig: ~156), 2.50 ~.~ S 5.~8 DEG W _~'~'~° 9354 (TO TD) ~17.50 ***P~NE OF PROPOSAL*** ~ 27.50 ~ 32.50 ~37.~ Begin Turn to Torge~ ~ ~ ~z~ '~" - nol EOC _ Top 4 1~ Uner T~G~ ~2 - Bose C-5 A ' ~nol EOC TARGET ANGLE gg.g~ DEG <-- West ...... 1800 1200 600 0 600 600 (/) o _ 0 .o _ (.~ _ 600 0 0 - 0 _1200 _1800 _2400 _3000 _3600 0 -- _4200 - ZY _4800 - I _5400 ~6000 V _6600 _7200 _7800 _ _8400 _ _9000 _ _9600 TARGET )J3 - O/W Contact - lI) I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 600 0 800 1200 1800 2400 3000 5600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 Scole 1 ' .500.00 Vertical Section on 185.48 azimuth wHh reference 0.00 N, 0.00 E from slot #4-8 UNOCAL GRANITE POINT Platform GP53 slot ~-8 Granite Point Field Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : GP53 Version Our ref : prop1456 License : Date printed : 2-Jan-96 Date created : 15-Nov-95 Last revised : 2-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 28.871,w151 19 53.937 Slot Grid coordinates are N 2544507.004, E 263322.524 Slot local coordinates are 2424.41S 1290.20 E Reference North is True North UNOCAL GRANITE POINT Platform, GP53 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : GP53 Version #4 Last revised : 2-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 0.00 0.00 200.00 0.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 200.00 500.00 0.00 N 0.00 E 0.00 0.00 1000.00 0.00 200.00 1000.00 0.00 N 0.00 E 0.00 0.00 1100.00 1,00 200.00 1099,99 0.82 S 0.30 W 1.00 0.84 1200.00 2.00 200,00 1199.96 3.28 S 1.19 W 1.00 3.38 1300.00 3.00 200.00 1299.86 7.38 S 2.68 W 1.00 7.60 1500.00 3.00 200.00 1499.59 17.21 S 6.26 W 0.00 17.73 1600.00 2.00 200.00 1599.49 21.31 S 7.76 W 1.00 21.96 1700.00 1.00 200.00 1699.46 23.77 S 8.65 ~ 1.00 24.49 1800.00 0.00 200.00 1799.45 24.59 S 8.95 ~ 1.00 25.34 2000.00 0.00 200.00 1999.45 24.59 S 8.95 ~ 0.00 25.34 2500.00 0.00 200.00 2499.45 24.59 S 8.95 W 0.00 25.34 2700.00 0.00 200.00 2699.45 24.59 S 8.95 g 0.00 25.34 2800.00 2.50 200.00 2799.42 26.64 S 9.70 ~ 2.50 27.45 2900.00 5.00 200.00 2899.20 32.79 S 11.93 ~ 2.50 33.78 3000.00 7.50 200.00 2998.60 43.02 S 15.66 ~ 2.50 44.32 3100.00 10.00 200.00 3097.42 57.31 S 20.86 W 2.50 59.04 3200.00 12.50 200.00 3195.49 75.64 S 27.53 ~ 2.50 77.93 3300.00 15.00 200.00 3292.62 97.98 S 35.66 ~ 2.50 100.94 3400.00 17.50 200.00 3388.62 124.27 S 45.~'~ ~ 2.50 128.02 3500.00 20.00 200.00 3483.30 154.47 S 56.22 ~ 2.50 159.14 3600.00 22.50 200.00 3576.50 188.53 S 68.62 W 2.50 194.22 3700.00 25.00 200.00 3668.02 226.37 S 82.39 ~ 2.50 233.21 3800.00 27.50 200.00 3757.70 267.93 S 97.52 ~ 2.50 276.02 3900.00 30.00 200.00 3845.37 313.12 S 113.97 ~ 2.50 322.58 4000.00 32.50 200.00 3930.85 361.87 S 131.71 ~ 2.50 372.80 4100.00 35.00 200.00 4013.9<2 414.07 S 150.71 W 2.50 426.58 4200.00 37.50 200.00 4094.63 469.63 S 170.93 ~ 2.50 483.82 4300.00 40.00 200.00 4172.61 528.44 S 192.34 W 2.50 544.41 4400.00 42.50 200.00 4247.79 590.40 $ 214.89 ~ 2.50 608.23 4473.60 44.34 200.00 4301.25 637.93 S 232.19 ~ 2.50 657.20 4500.00 44.27 199.06 4320.14 655.31 S 238.35 ~ 2.50 675.09 4600.00 44.10 195.48 4391.86 721.85 $ 259.04 W 2.50 743.30 4700.00 44.03 191.89 4463.72 789.40 S 275.49 W 2.50 812.11 4800.00 44.08 188.29 4535.60 857.84 S 287.67 ~ 2.50 881.40 4900.00 44.24 184.71 4607.34 927.04 S 295.55 W 2.50 951.04 49~.50 44.34 18~.34 4634.90 953.86 S 297.44 ~ 2.50 977.92 5000.00 44.34 18~.34 4678.89 996.76 S 299.94 W 0.00 1020.87 5500.00 44.34 18~.34 5036.52 1345.60 S 320.30 ~ 0.00 1370.05 6000.00 44.34 18~.~4 5394.15 1694.44 S 340.66 W 0.00 1719.24 6500.00 44.34 183.34 5751.78 2043.27 S 361.02 ~ 0.00 2068.42 7000.00 44.34 183.34 6109.40 2392.11 S 381.37 ~ 0.00 2417.61 7500.00 44.34 185.34 6467.03 2740.95 S 401.73 W 0.00 2766.80 8000.00 44.34 18~.34 6824.66 3089.79 $ 422.08 W 0.00 3115.98 8500.00 44.34 18~.34 7182.29 3438.62 $ 442.44 W 0.00 3465.17 gO00.O0 44.34 18.~.34 7539.92 3787.46 S 462.80 W 0.00 3814.35 9500.00 44.34 183.34 7897.55 41~6.30 $ 485.15 ~ 0.00 4163.54 10000.00 44.34 18.~.34 8255.18 4/+85.14 $ 503.51 W 0.00 4512.73 10500.00 44.34 18~.34 8612.80 48~3.97 $ 523.87 ~ 0.00 4861.91 11000.00 44.34 18.~.34 8970.43 5182.81 $ 544.22 ~ 0.00 5211.10 Begin SW Nudge End Angle Build Begin Angle Drop End Directional Nc~ge KOP Begin Turn to Targets EOC Att data is in feet unless otherwise stated Coordinates from slot #4-8 and TVO from RKB (Rig: #156) (115.00 Ft above mean sea level). Vertical section is from wet[head on azimuth 185.48 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimun curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT P[atform,GP53 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : GP53 Version #4 Last revised : 2-Jan-96 Measured lnclin. 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 ! N A T E S Deg/lOOFt Sect 11500.00 44.34 18~.34 9328.06 5531.65 S 564.58 W 0.00 5560.28 12000.00 44.34 18~.34 9685.69 5880.48 S 584,94 W 0.00 5909.47 12500.00 44.34 18~.34 10043.32 6229.32 S 605.29 ~ 0.00 6258.66 12600.00 44.34 18~.34 10114.84 6299.09 S 609.36 ~ 0.00 6328.49 1277'4.98 44.34 18~.34 10240.00 6421.17 $ 616.49 W 0.00 6450.69 12800.00 45.83 18~.46 10257.66 6438.85 S 617.54 ~ 6.00 6468.40 12900.00 51.82 !8~.89 10323.46 6513.94 S 622.38 W 6.00 6543.60 13000.00 57.82 184.26 10381.05 6595.43 S 628.19 W 6.00 6625.28 13100.00 63.81 184.57 10429.79 6682.44 S 634.91 W 6.00 6712.53 13148.29 66.71 184.72 10450.00 6726.15 S 638.47 ~ 6.00 6756.38 13200.00 69.81 184.86 10469.15 6774.00 S 642.48 W 6.00 6804.40 13300.00 75.80 185.13 10498.70 6869.13 S 650.80 W 6.00 6899.88 13400.00 81.80 185.38 10518.12 6966.76 S 659.78 W 6.00 6997.93 13417.12 82,82 185,42 10520.41 6983.66 S 661.38 ~ 6.00 7014.90 13500.00 82.82 185.42 10530.7-/ 7065.52 S 669.15 ~ 0.00 7097.13 14000.00 82.82 185,42 10593.24 7559.38 S 716.04 W 0.00 7593.21 14500.00 82,82 185.42 10655.72 8053.24 S 762.94 W 0.00 8089.29 15000.00 82,82 185,42 10718.20 8547.10 S 809.8~ W 0.00 8585.37 15500.00 82,82 185,42 10780.67 9040.96 S 856.72 ~ 0.00 9081.45 15774.72 82,82 185,42 10815.00 9312.31 S 882.49 W 0.00 9354.02 Top 4 1/2" Liner TARGET #1 - T/C-5 - Begin Final Build TARGET #2 - Base C-5 Final EOC TARGET #3 - 0/~ Contact - TD At[ data is in feet unless otherwise stated Coordinates from slot #4-8 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 185.48 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimun curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Ptatform,GP53 Granite Point Field,Cook InteL, ALaska PROPOSAL LISTING Page 3 Your ref : GP53 Version #4 Last revised : 2-Jan-96 Cce~nents in wellpath !~) TVD Rectangular Coords. Con~nent 1000.00 1000.00 0.00 N 0.00 E Begin SW Nudge 1300.00 129<2.86 7.38 S 2.68 W End Angle Build 1500.00 1499.59 17.21S 6.26 W Begin AngLe Drop 1800.00 1799.45 24.59 S 8.95 ~ End Directional Nudge 2700.00 2699.45 24.59 $ 8.95 W KOP 447'5.60 4301.25 637.93 $ 232.19 W Begin Turn to Targets 4938.50 4634.90 953.86 S 297.44 W EOC 12600.00 10114.84 6299.09 S 609.36 W Top 4 1/2" Liner 12774.98 10240.00 6421.17 S 616.49 W TARGET #1 - T/C-5 - Begin Final Build 13148.29 10450.00 6726.15 S 638.47 W TARGET #2 - Base C-5 13417.12 10520.41 698~.66 S 661.38 W Final EOC 15774.?2 10815.00 9312.31S 882.49 W TARGET ~r5 - O/W Contact - TD Targets associated with this we[Lpath Target name Position T.V.D. Local rectangular coords. Date revised GP53 O/W 15-Nov-95 262250.000,2535215.000,0.000010815.00 9312.31S 882.49g 15-Nov-95 GP53 B/C-5 15-Nov-95 262550.000,2537835.000,0.000010450.00 6686.63S 636.0714 15-Nov-95 GP53 T/C-5 15-Nov-95 262575.000,2538100.000,0.000010240.00 6421.17S 616.49g 15-Nov-95 All data is in feet unless otherwise stated Coordinates from slot #4-8 and TVD from RKB (Rig: #156) (115.00 Ft above mean sea leveL). Bottom hole distance is 9354.03 on azimuth 185.41 degrees from wet[heed. Total Dogleg for wel[path is 100.49 degrees. Vertical section is from wellhead on azimuth 185.48 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, GP53 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : GP53 Version ~4 Last revised : 2-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 0.00 0.00 200.00 0.00 2424.41 S 1290.20 E 0.00 500.00 0.00 200.00 500.00 2424.41 S 1290.20 E 0.00 1000.00 0.00 200.00 1000.00 2424.41 S 1290.20 E 0.00 1100.00 1.00 200.00 1099.99 2425.23 S 1289.90 E 1.00 1200.00 2.00 200.00 1199.96 2427.69 S 1289.01 E 1.00 1300.00 3.00 200.00 1299.86 2431.79 S 1287.52 E 1.00 1500.00 3.00 200.00 1499.59 2441.63 S 1283.94 E 0.00 1600.00 2.00 200.00 1599.49 2445.73 S 1282.45 E 1.00 1700.00 1.00 200.00 1699.46 2448.19 S 1281.55 E 1.00 1800.00 0.00 200.00 1799.45 2449.01 S 1281.25 E 1.00 2000.00 0.00 200.00 1999.45 2449.01 S 1281.25 E 0.00 2500.00 0.00 200.00 2499.45 2449.01 S 1281.25 E 0.00 2700.00 0.00 200.00 2699.45 2449,01 S 1281.25 E 0.00 2800.00 2.50 200.00 2799.42 2451.06 S 1280.51 E 2.50 2900.00 5.00 200.00 2899.20 2457.20 S 1278.27 E 2.50 0.00 0.00 0.00 Begin SW Nudge 3.38 7.60 End Angle Build 17,73 Begin Angle Drop 21,96 24.49 25,34 End Directional Nudge 25,34 25.34 25.34 KOP 27,45 33,78 3000.00 7.50 200.00 2998.60 2467.43 S 1274.55 E 2.50 3100.00 10.00 200.00 3097.42 2481,72 S 1269.34 E 2.50 3200.00 12.50 200.00 3195.49 2500.06 S 1262.67 E 2.50 3300.00 15.00 200.00 3292.62 2522.39 S 1254.54 E 2.50 3400.00 17.50 200.00 3388.62 2548.68 S 1244.97 E 2.50 44.32 59.04 77,93 100.94 128.02 3500.00 20.00 200.00 3483.30 2578.88 S 1233.98 E 2.50 3600.00 22.50 200.00 3576.50 2612.94 S 1221.58 E 2.50 3700.00 25.00 200.00 3668.02 2650.78 S 1207.81 E 2.50 3800.00 27.50 200.00 3757.70 2692.34 S 1192.68 E 2.50 3900.00 30.00 200.00 3845.37 2737,54 S 1176.24 E 2.50 4000.00 32.50 200.00 3930.85 2786.28 S 1158.49 E 2.50 4100.00 35.00 200.00 4013.99 2838.48 S 1139.49 E 2.50 4200.00 37.50 200.00 4094.63 2894,04 S 1119.27 E 2.50 4300.00 40.00 200.00 4172.61 2952,86 S 1097.87 E 2.50 4400.00 42.50 200.00 4247.79 3014,81 S 1075.32 E 2.50 4473.60 44.34 200.00 4301.25 3062,34 S 1058.02 E 2.50 4500.00 44.27 199.06 4320.14 3079.72 S 1051.85 E 2.50 4600.00 44.10 195.48 4391.86 3146,26 S 1031.16 E 2.50 4700.00 44.03 191.89 4463.72 3213,81 S 1014.71 E 2.50 4800.00 44.08 188.29 4535.60 3282,25 S 1002.53 E 2.50 159,14 194,22 233.21 276,02 322,58 372,80 426.58 483,82 544,41 608.23 657.20 Begin Turn to Targets 675.09 743.30 812,11 881.40 4900.00 44.24 184.71 4607.34 3351.45 S 994.65 E 2.50 4938.50 44.34 183.34 4634.90 3378,27 $ 992.76 E 2.50 5000.00 44.34 183.34 4678.89 3421.18 S 990.26 E 0.00 5500.00 44.34 183.34 5036.52 3770.01 S 969.90 E 0.00 6000.00 44.34 183.34 5394.15 4118,85 S 949.54 E 0.00 951.04 977.92 EOC 1020.87 1370,05 1719.24 6500.00 44.34 183.34 5751.78 4467.69 S 929.19 E 7000.00 44.34 183.34 6109.40 4816,52 S 908.83 E 7500.00 44.34 183.34 6467.03 5165.36 S 888.48 E 8000.00 44.34 183.34 6824.66 5514,20 S 868.12 E 8500.00 44.34 183.34 7182.29 5863,04 S 847.76 E 9000.00 44.34 183.34 7539.92 6211.87 S 827.40 E 9500.00 44.34 183.34 7897.55 6560,71 S 807.05 E 10000.00 44.34 183.34 8255.18 6909,55 S 786.69 E 10500.00 44.34 183.34 8612.80 7258.38 S 766.34 E 11000.00 44.34 183.34 8970.43 7607,22 S 745.98 E 0.00 2068.42 ...... 0.00 2417.61 0.00 2766.80 0.00 3115.98 0.00 3465.17 0.00 3814.35 0.00 4512,73 .~' 0.00 4861.91 0.00 5211.10 Att 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). Vertical section is from wellhead on azimuth 185.48 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,GP53 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : GP53 Version #4 Last revised : 2-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 ! N A T E S Deg/lOOFt Sect 11500.00 44.34 183.34 9328.06 7956.06 S 725.62 E 0.00 5560,28 12000.00 44.34 183.34 9685.69 8304.90 S 705.27 E 0.00 5909,47 12500.00 44.34 183.34 10043.32 8653.73 S 684.91E 0.00 6258,66 12600.00 44.34 183.34 10114.84 8723.50 S 680.84 E 0.00 6328,49 Top 4 1/2" Liner 12774.98 44.34 183.34 10240.00 8845.58 S 673.7'2 E 0.00 6450.69 TARGET #1 - T/C-5 - Begin Final Build 12800.00 45.8~ 183.46 10257.66 8863,27 S 672.66 E 6.00 6468.40 12900.00 51.82 183.89 10323.46 8938,35 S 667.83 E 6.00 6543.60 13000.00 57.82 184.26 10381.05 9019.84 $ 662.01E 6.00 6625.28 13100.00 63.81 184.57 10429.79 9106.85 S 655.29 E 6.00 6712.53 13148.29 66.71 184.72 10450.00 9150.56 S 651.74 E 6.00 6756.38 TARGET #2 - Base C-5 13200.00 69.81 184.86 10469.15 9198.42 S 647.73 E 6.00 6804.40 13300.00 75.80 185.13 10498.70 9293.54 S 639.41 E 6.00 6899.8~ 13400.00 81.80 185.38 10518.12 9391.18 S 630.42 E 6.00 6997.93 13417.12 82.82 185.42 10520.41 9408.07 S 628.83 E 6.00 7014.90 Final EOC 13500.00 82.82. 185.42 10530.77 9489.93 S 621.05 E 0.00 7097.13 14000.00 82.82 185.42 10593.24 9983.79 S 574.16 E 0.00 7593.21 14500.00 82.82 185.42 10655.72 1047-/.65 S 527.27 E 0.00 8089.29 15000.00 82.82 185.42 10718.20 10971.51S 480.37 E 0.00 8585.37 15500.00 82.82 185.42 10780.67 11465.37 S 433.48 E 0.00 9081.45 15774.72 82.82 185.42 10815.00 11736.72 S 407.72 E 0.00 9354.02 TARGET fl5 - O/W Contact - TD All data is in feet cmaless otherwise stated Coordinates from NW Corner of Sec. 13, TION, R12W SM and TVO from RKB (Rig: #156) (115.00 Ft above mean sea [eve[). Vertical section is from wellhead on azimuth 185.48 degrees. Declination is 0.00 degrees, Convergence is -1.17 degrees. Calculation uses the minimua curvature method. Presented by Baker Hughes INTEQ UNOCAL GRANITE POINT Platform,GP53 Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 3 Your ref : GP53 Version #4 Last revised : 2-Jan-96 Coe~rents in wellpath ~) TVD Rectangular Coords. Coherent 1000.00 1000.00 2424.41 s 1290.20 E Begin SW Nudge 1300.00 1299.86 2431.79 S 1287.52 E End Angle Build 1500.00 1499.59 2441.63 S 1283.94 E Begin Angle Drop 1800.00 1799.45 2449.01S 1281.25 E End Directional Nudge 2700.00 2699.45 2449.01 S 1281.25 E KOP 4473.60 4301.25 3062.~4 S 1058.02 E Begin Turn to Targets 4938.50 4634.90 3378.27 S 992.76 E EOC 12600.00 10114.84 8723.50 S 680.84 E Top4 1/2" Liner 12774.98 10240.00 8845.58 S 673.72 E TARGET #1 - T/C-5 - Begin Final Build 13148.29 10450.00 9150.56 S 651.74 E TARGET #2 - Base C-5 1~417.12 10520.41 9408.07 S 628.83 E Final EOC 15774.72 10815.00 11736.72 S 407.72 E. TARGET ~ - O/W Contact - TD Targets associated with this wet[path Target name Position T.V.D. Local rectangular coords. Date revised GP53 O/W 15-Nov-95 262250.000,2535215.000,0.000010815.00 11736.72S 407.72E 15-Nov-95 GP53 B/C-5 15-Nov-95 262550.000,2537835.000,0.000010450.00 9111.04S 654.13E 15-Nov-95 GP53 T/C-5 15-Nov-95 262575.000,2538100.000,0.000010240.00 8845.58S 673.72E 15-Nov-95 All data is in feet unless otherwise stated Coordinates from N~ Corner of Sec. 13, TION, R121~ SM and TVD from RKB (Rig: #156) (115.00 Ft above mean sea level). Bottom hole distance is 9354.03 on azimuth 185.41 degrees from wellhead. Total Dogleg for we[[path is 100.49 degrees. Vertical section is from wellhead on azimuth 185.48 degrees. Declination is 0.00 degrees, Convergence is -1.17degrees. Calculation uses the minim~n curvature method. Presented by Baker Hughes INTEQ UNOCAL GIb~NITE POINT PLatform GP53 slot ~Y+-8 Granite Point Field Cook Inlet, ALaska CLEARANCE REPORT by Baker Hughes INTEQ Your ref : GPS$ Version ~4 Our ref : prop1456 License : Date printed : 29-Dec-95 Date created : 15-Nov-95 Last revised : 29-0ec-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 ~ 57 28.871,w151 19 53.937 SLot Grid coordinates are N 2544507.004, E 263322.524 Slot Local coordinates are 2424.41 S 1290.20 E Refererw:e North is True North Main calculation performm<t with 3-D Minimun Distance method Object welLpath' GMS <O-1057"2'>,,13-13,GRANITE POINT Platform PGMS <O-11560'>,,11-13Rd,GRANiTE POINT Platfor GMS <4025-11653'>,,11-13,GRANITE POINT PLatfor PMSS (9437 - lOZ70'>,,32-13Rd,GILANITE POINT P[ PMSS <8478 - 12563">,,32-'13Rd~2,GRANITE POINT PGMS <O-10200~>,,32-13,GRANITE POINT PLatform GMS <2700 - 11450~>,,33-13,GILANITE POINT Platf MSS <8630-11376"> ,,33-23,GRANITE POINT Platfo GMS <O-12000'>,,32-P_i,GPdm, NITE POINT PLatform GMS <8900-119~5'>,,32-23Rd,GRANITE POINT P[atf m/MSS <0-11150-15715'>,,MUC I-1,GRANITE POIN GMS <0-11839'> ,,GP-51,GRANITE POINT Platfom PGMS <O-1216:~'>,,GP-50,GlaJ~NITE POINT Platform GMS <O-10(LtO~>,,MUC i-2,GR~ANITE POINT PLatform GMS <O-12200'>,,12-24,GILANITE POINT PLatform GMS <O-10560'>,,24-13,GRANITE POINT PLatform GMS <9ZO0-10640'>,,24-13Rd,GRANITE POINT Platf GMS <O-11473'>,,33-14,GIL~NITE POINT PLatform CaMS <9200-11410~>,,33-14Rd,GILANITE POINT Ptatf GMS <O-11200'>,,31-23,GILANITE POINT PLatform GMS/MSS/GMS <O-12471'>,,44-11,GRANITE POINT P[ ~ <O-10850'>,,44-14,GILANITE POINT PLatform GMS <O-11800'>,,11-24,GRANITE POINT Platform GMS <O-10191'>,,31-14Rd#2,GILANITE POINT P[atfo GMS/MSS <O-84)76'>,,31-14,GiLANITE POINT Platfor GMS <O'11011'>,,31-14RcI~1,GRANITE POINT Ptatfo GMS <O-10874'>,,31-13,GILANITE POINT PLatform GMS/MSS/GMS (O-14544'>,,42-23,GRANITE POINT Pt PMSS <11453 - 13821'>,,22-13Rd2,GRANITE POINT Closest approach with 5-D minimun distance method Last revised Distance M.D. Diverging from M.D. Il-Aug-95 23.7 2733.3 27"53.3 11-Aug-95 71.6 880.0 880.0 11-Aug-95 71.6 8843.0 84)0.0 13-Aug-95 94.9 400.0 104843.0 13-Aug-95 94.9 400.0 10480.0 13-Aug-95 94.9 400.0 400.0 13-Aug-95 94.9 400.0 400.0 11-Aug-95 51.4 1050.0 7020.0 11-Aug-95 51.4 1050.0 7020.0 22-May-91 51.4 1050.0 9540.0 22-May-91 92.7 460.0 12440.0 11-Aug-95 90.1 1050.0 2700.0 2-0ct-92 75.1 1100.0 11880.2 22-May-91 96.4 780.0 12160.0 2Z-May-91 18.3. 800.0 10240.0 22-Ma¥-91 82.9 780.0 780.0 22-May-91 82.9 780.0 780.0 22;May-91 61.4 400.0 400.0 22-May-91 61.4 400.0 11640.0 22-May-91 66.1 200.0 11600.6 22-May-91 70,2 280.0 11880.2 ~2-May-91 58.7 460.0 12160.0 22-May-91 31.8 1050.0 6460.0 ?.2-May-91 69.6 60.0 620.0 ~2-May-91 69.6 60.0 12160.0 22-May-91 69.6 60.0 12240.0 ?.2-Nay-91 91.7 100.0 520.0 22-May-91 59.2 1460.0 1460.0 2D-Dec-95 94.7 320.0 320.0 PM$S (6738 - 12036'>,,22-1'~'GRANITE POINT Pt GeT Gyro <0-?002'>,,22-13R ANITE POINT Prat GP52 Version #4,,GP52,GRAN~fE POINT Platform GP54 Version #4,,GP54,GRANITE POINT Ptatform 20-Dec-95 4-Dec-95 29-Dec-95 29-Dec-95 94.? 94.7 8.4 4.4 ~00.0 320.0 320.0 11640.0 2700.0 Created by : jones Fo:r: Dote plotted : 2-Jan-g6 Pint Reference is GP53 Version /~14. Soordinates ore in feet reference slot True Vertical Dep[hs ere reference RKB (Rig: ~ 24O 220 20O 180 I I I 2O 4O I I V UNOCAL Structure : GRANITE POINT Platform Well: GP53 Field : Granite Poinf Field Location : Cook Inlet, Alaska < 160 140 120 100 80 200 West 60 40 20O / O0 O0 o 4200 1600 36O0 3400 6OOO lo00 3200 ~ooo 5600 0 2O 1400 1600 20O0 2400 360( 3800 1200 ~600 Scale 1 · 10.00 40 60 80 lO00 400 4O00 4200 6O 8O _100 _2OO I I V 4800 Z200 3800 1600 240 220 200 180 160 140 120 100 80 60 40 West 20 0 20 :;: .4d~ ~',, 60 80 ~'%~C(,"."?.? ':' ...... ' Scale 1 ' 10.00 iDete ~otted : 2-Jan-96 IPIot Reference is GP53 Version ICoordinotes ore in feet reference s~ot i~4-8. ITrue Vertical Depths are reference RK~ (Rig: 60O 560 52O UNOCAL Strucfure : GRANITE POINT Pl?fcrm Well: GP53 Field : Gronife Point F:eid Location : Cook Inlet, Alaska 480 440 400 360 W e s f ~co,~: · ~o.oo .320 280 240 200 160 80 40 0 40 J , 320 / -. 360 / 400 4000 --1 480 i '/ 520 _ 560 _ 2600 600_ / 640_ 8200 680 _ -- /4.000 / 2200 72O 4200 24O0 76ot 8OO 840 880 920 96O 1000 I I 5--60 I I 600 520 5400 I I I I I 480 440 320o/ 4OO 360 2800 250O 4400, i2' hI, ~ C: q .; ~ *~ ~ ', ~ .p 'i-' ', - 200 ~.~/ 4600 320 _ 320 _- _ 360 _ 400 -- _ 440 _ 480 _ 520 -- _ 560 -- 600 _ 640 680 720 760 280 240 2O0 Wesf 800 k 840 _ 880 _ 920 -- _ 960 -- 1000 40 o 40 Scale ~ : 20.00 0 I I V Created by : jones For:. M DAMM D~te plotted : 2-don-96 Plot Reference is GP§3 Version Coordinates are in feet reference s~ot ~4-8. True Vertical Depths are refere~ RKB (Rig: ~156). UNOCAL i Struc~ture : GRANITE POINT Platform Field : Granite Point Field 1200 '!00 1000 900 800 700 Well: CPS3 Location : Co~k Inlet, Alaska 6OO 500 Wes{ 400 ZL-v'O 200 I I V 28OO 3000 64-OO 11000 60aa 5OOO 1200 'I00 1000 900 800 700 $8OO ~200 ~6OO 66OO 600 500 520O ~'" 58oo 6OO0 6OOO 6400 660O 6800 62O0 7000 7200 , 6400 / / / 7400 0 ~ 200 West 100 440O 4600 4800 5200 5000 5200 54OO Scale 1 ' 50.00 100 200 300 400 5600 1400 500 16OO 1700 800 1900 2OO0 5OO0 1 O0 0 1 O0 200 500 400 Scale 1 · 50.00 0 I I V Creoted by : jones For: M DAMM Date plotted : 2-Jan-96 Plot Reference is GP53 Version ~4. ICoordinates are in feet reference slot ~4-8. lime Vertical Depths are reference RKB (Rig: #156). 0 0 cC 3600_ -- .. 3700_ - 3800_ 3900_ 4100_ 4200_ .,~,, ,--I---- ~ 4300_ 0 - f) 4400_ 4500_ _ 4600_ - 4700_ 4900_ 5000_ 5100_ 5200_ 53O0 UNOCAL Structure : GRANITE POINT Platform Well: GP53 Field : Granite Point Field Location : Cook Inlet, Alaska < W e s f Scale 1 · 50.00 1200 11 O0 1000 900 800 700 600 500 400 300 200 1 O0 0 1 O0 200 300 400 7400 7600 I8 7800 000 8200 B400 % 8600 _3600 o _3700 " 0 _ 0 _3800 0 _3900 _4000 _4100 420O 4300 - _4400 _4500 I - I _4600 _ _4700 4800 ~o° 4900 ~ ~Oo - _5000 8800 _5100 9000 _5200 _ I I I I' I I I I I 'I I [ I / I I I I I I I I I I I I I I I I I I 5300 1200 11 O0 1000 900 800 700 600 500 400 300 200 1 O0 0 1 O0 200 300 400 < Wesf Scale 1 · 50.00 UNOCAL GRANITE POINT PLATFORM WELLS 452, #53 AND ~54 DEPTH INTERVAL 0 - , 900' t52 0 - ~ 1100' #53 AND 454 17-1/2" HOLE 13-3/8" CASING MUD TYPE GENERIC MUD #2 MUD ADDITIVES M-I GEL/M-I BAR/SODA/ ASH/CAUSTIC/LIME POTENTIAL PROBLEMS HOLE CLEANING/CRAVEL/ GAS KICK/LOST CIRCULATION TREATMENTS/' PROCEDUI~S Build spud mud system with prehydrated bentonit~ in fresh water and filtered inlet water. Treat drill water with Soda Ash as required to reduce calcium content to 40 ± ppm. Pre-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 if 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 %54. 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 (12/95) ANTICIPATED SPUD MUD PROPERTIES Mud D~nsity Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss (API) pH 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. of 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 DEPTH INTERVAL MUD TYPE MUD ADDITIVES POTENTIAL PROBLEMS UNO~AL GRANITE POINT PLATFORM ~n~LLS ~52, #53 aao #54 :1:1100' - :!:3500' (153) ±llO0' t3500' (154) :!:900' - :1:2700' 12-1/4" HOLE 9-5/8" CASING GENERIC ]MUD M-Z GEL/M-I BAR/SODA ASH/ POLYPAC/SPERSENE/XP-20/ SODZUMBICARBONATE/ CAUSTIC HOLE CLEANING/TIGHT HOLE/BIT BJ~T.T. INO/ GUMBO CLAYS/HOLE ENLARGEMENT/GAS KICKS/ COAL SLOUGHING l) 2) 3) 4) 5) 6) ?) TREATMENT PROCEDURES Use the surface mud from well #53 to drill the 13-3/8" collar, cement and shoe. Treat this fluid aa 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) Drill to T.D. If hole conditions warrant, spot a viscous pill on bottom. Run 9-5/8" casing. 10) Evaluate quality of mud and save for reuse on 9-5/8" casing interval on wells #53 and #54. ANTICIPATED 9-5/8'~ 14110 PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels API Fluid Loss pH MBT Drilled Solids 9.0-9.6 ppg 40-70 sec/qt 10-15 cps 10-20 #/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 the discharge permit. See letter requesting authorization of list of approved products and M.A.C. DM- 184 .WP (12/95) DEPTH INTERVAL MUD TYPE MUD ADDITIVES VERSAWET/ POTENTIAL PROBLEMS CIRCULATION/WATER KICKS/HIGH GELS UNOCAL GRANITE POINT PLATFORM WE~-~-S #52, ,53 AND #54 #52 2700' - 11395' 8-1/2" 11395' - 14357' 6" ~53 3500' - 12800' 6" 12800' - 15700' 6" #54 3500' - 12684' - 15517' 6" MINEKAL OIL BASE VG-69/M-I Bar/CONOCO LVT2-/LOWATE VERSACOAT! VERSAHRP/VERSAMOD/ALCO~R 274/LINE/CaCl~ HOLE CLEANING/LOST TREATMENTS/PROCEDURES 1. Mix mineral oil mud system utilizing the following recommendations: Notes Initial volume from G.P. 22-13 will be approximately 800 bbls. Additional volume should be mixed as follows: a. Premix and store 10.8 ppg calcium chloride brine. 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. f. Add calcium chloride brine.g. Blend for a minimum of 30 minutes. Add Versawet/check theology/add Versamod. Add Barite to required mud weight. Anticipated mud weight in the 8-1/2" hole should be approximately 9.5 ppg. DM-184.WP (12/95) h. 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. a, Conduct a rig team meeting discussing all aspects of displacement. Note~ Rig operations should dictate optimum displacement time. bt Dilute and lower mud weight ofwater base mud. Pump a 75 bbl br£neXCD polymer viscous sweep. Pump a 25 bbl mineral oil viscous sweep pill. Pump mineral oil mud system. c. Displace in turbulent flow 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 method 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 o£ "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 iow as possible, centrifuge 8-1/2" hole mud and add Conoco LVT 200 to reduce mud weight. Conduct cost estimate prior to reducing mud weight. DM-184 .WP (~2/95) · Maintain low shear rate values with VG-69, Versamod, Alcomer 274 and Versa HKP. Run and cement 5" liner. ~ Displace well to diesel after running tubing. displacement procedure.) (See separate 10. Store mineral oil mud for use on next well in sequence. ANTICIPATED MUD PROPER~ISB Mud Weight ppg 8.5 9.5 PV 12-20 25-35 YP 15-20 15-20 Gels 10/25 10/40 O/W 80/20 80/20 E.S. 800+ 800+ HTHP @ 225° F 6 cc 6 cc BASS FORI~t,~TION LVT 200 bbl VG-69 ppb Lime ppb Versacoat ppb Versawet ppb Versamod ppb/Versa HRP/Alcomer 274 CaC1, Barite/Lowate ppb Varies w/MW & OW ratio 5-8 2 4-6 1-2 0-1 34 As Required DM-iS4 .WP (12/95) FILL-UP KILL LINE FLOW- ANN~ BOP 13~/~3000 psi PIPE RAMS 135/s" 5000 psi BLIND RAMS 135/s"5000 psi SPOOL ~ ~,~ooo ~ ..~>5IL~ ~o~. 4" 5000 psi 11 II 4" 5000 psi [ PIPE RAMS 135/~5000 psi LINE~ RISER 13 ~'~" 5000 psi COOK INL T PLATFORMS BOPE STACK 13 %" 5000 psi 6" - ~.50 tB Old RIG HEADER SECTION FRONT VIEW 5O00' 56" TOP BUFFER TANK FRONT VIEW GAUGE & REMOTE PANEL TRANSMITTER GAUGE FLANGE BEHIND HEADER 3 ! 3A A 1 5 2 7 1 8 I A<Xm3;:eN, 4 1/16" - 5000# Flg X 4" Nl~S Lg'. Flg. 5000# ~tVel Adap:mr. 4 1/16" - 5000~ Flg. X 3" NPS NXpple 90 cleg. Adapcmr, 3 1/16" - 10000# ~Xg. X 3" NPS Nlt:a;).l.s Ada~r, 3 1/16" - ~0000# Plg. X 3' NI:'S NtIpIPle Adai~ex. 2 1/16" - 50001 Flg. X 2" 1TPS NtDDZe 5000# W/ 2 - 2" ~ 9 1 wiLLis c~e wi NPS ends 10 2 swaco c:ao~ 2 9/16" - I0,000# z-smm:m opera-,.ed ~ wlC. l~ paael 11 3 5 - way N'PS f.3..ow blocA, 4X4X3X3X2 12 3 15 2 19 21 I N~S 2" ~Lln~ Flange NPS 3" S/.tn~ Flange NTS 4" X 8' S~car ~S 4" Lg. FI~ X Nipple ~S 2' X 8" Spear ~e ~S ~1~ V~ ~" ~S B~ V~ve 3" Casing Design Summat3, Well: GP 53 Field: Granite Point Date: Casing Mud WT M.S.P. Size (PPG) (psi) 1/8/95 Design by: Mitchell Datum Max. Kick Tolerance (gaLS) 26" 8.8 61 13-3/8" 9 301 9-5/8" 9 1,046 7" 9 2,218 4-1/2" 9 NA 130 95 72 326 NA *** Slotted Liner*** Casing Bottom Top Length Wt Grade Size (FEET) (FEET) (FEET) (LB/FT) Thread Connection 26" 329 47 282 TVD 329 47 282 13-3/8" 1,100 47 1,053 68 K-55 TVD 1,099 47 1,052 9-5/8" 3,500 47 3,453 47 L-80 TVD 3,483 47 3,436 7" 12,800 47 12,753 29 L-80 TVD 10,257 47 10,210 4-1/2" 15,700 12,600 3,100 12.6 L-80 TVD 10,815 10,114 Buttress Buttress Buttress SC-Buttress Casing Weight Tension Minimum * Collapse * Collapse Size W/O BF Top of Strength TDF Pressure #1 Pressure #2 Section Tension ~ Bottom ~ Bottom (LAS) (LBS) (1,000/LBS) (psi) (psi) '"13-3/8" 71,604 71,604 1,069 14.9 314 NA 9-5/8" 162,291 162,291 1,086 6.7 996 NA 7" 369,837 369,837 597 1.6 2,934 4,533 4-1/2" 39,060 39,060 289 7.4 NA NA Collapse **Burst Minimum Resist. CDF#1 CDF#2 Pressure Yield Tesnsion Strength (psi) (psi) (psi) BDF 1,950 6.2 NA 1,742 3,450 2.0 4,760 4.8 NA 5,334 6,870 1.3 7,020 2.4 1.5 5,624 8,160 1.5 NA NA NA NA NA NA * Collapse pressures are calculated using two methods (chec 'ks). 1) Difference between two cement slurries (i.e. AVG of a 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) Difference between Mud Weight on the outside and gas lift gas (0.0 psi/FT) on the inside. (i.e. Multiply (.052 X MW - 0.0 psi/FT) X the TVD of the Top of Cement. ** Burst pressure is calculated. (BHP ~ the depth of the next casing X TVD next casing) X (0.5 = half of wellbore evacuated). KTGP53.XLS 1/15/96 Maximum Surface Pressure Calculations Well: 53 Casing Size: 26" Depth Interval: 0'-1,100' Hole Size: 17.50 General Information: Anticipated Mud Weight (MW): 8.8 PPG Shoe Depth (D~ho~): 294 MD Estimated Fracture Gradient (at the Shoe): Total Depth (Dm): 1,100 MD Bottom Hole Pressure Gradient (BHPG): Gas Gradient (GG); (assumes worse case): Maximin Gas Column Height in wellbore when top of gas is at the shoe (Ht): 0.4576 psi/FT 294 TVD 0.90 psi/FT 1099 TVD 0.35 psi/FT 0.10 psi/Fr 500 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 (I-It), found in the Maximum Kick Tolerance Calculations, is used. Maximum Surface Pressure - Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume) MSP = P~n~- 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. 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). P~ho~ = MSP + .052*MW*D~o~ Pshoe = 195 psi FP~hoe = 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~ho~ DP shoe = 92 psi The DPshoe is less that the internal yield of the casing. KTGP53.XLS 26" MSP 1/9/96 Maximum Kick Tolerance Calculations Well: GP 53 Casing Shoe: 26" General Information Variables 1 26" Casing Shoe (from RT) 294 Feet (rVD) 2 Fracture pressure Gradient 0.90 psi/FT FPG 3 Fracture pressure at the 26" Shoe 265 psi FP,~o~ 4 Proposed TD of the 13-3/8" Casing Shoe (TVD) 1,099 Feet (TVD) Dm 5 Pore pressure gradient 0.350 psiPFr PpG 6 Maximum anticipated pore pressure ~ TD 385 psi Pm~nv 7 Mud Weight See table PPG MW 8 Gas Gradient 0.10 psi/FT GG 9 Average open hole size 17.50 Inches ODo, 10 ;Drillpipe OD 5.00 Inches OD~P 11 iCapaeity of open hole by drillpipe 0.2731 BBL/FT CAP 10 !Height of gas column in wellbore when top of gas is at the shoe HT Feet (TVD) Ht Assumptions for Granite Point Field: AH 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 (Ht) calculation with gas bubble top at 26" shoe. FPshoe + Pgas bubble + Proud = Pmax~ TD FPeo, + GG*Ht + .052*MW*(DrM2hh~Ht) = Pm~m Gas Volume (GV) calculation at 26" shoe. GV = CAP*Hr Kick Tolerance calculation: Gas volume in wellbore at TD. P1 V1 = P2V2. Assume constant temperature. Kick Tolerance * P~ m = GV * FP MudWeight Gas BubbleHeight Gas Volume~Shoe KickTolerance (PPG) (Fee0 (BBLS) (BBLS) 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 9.8 708 193 133 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 11.0 721 197 135 KTGP53 .XLS 1/9/96 Maximum Surface Pressure Calculations Well: GP 53 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~ho~): 1100 MD Estimated Fracture Gradient (at the Shoe): Total Depth (D~): 3500 MD Bottom Hole Pressure Gradient (BHPG): Gas Gradient (GG); (assumes worse case): Maximum Gas Column Height in wellbore when top of gas is at the shoe (Ht): 0.468 psi/FT 1099 TVD 0.85 psi/FT 3483 TVD 0.45 psi/FT 0.10 psi/FT 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 = Maximmn Bottom Hole Pressure - Hydrostatic Pressure (Gas Volmne +Mud Volume) MSP = Pm,~m- GG*Ht - .052*MW*(Dn)-Ht) MSP = 301 psi Hydrostatic Pressure at the Shoe Calculations: The greatest hydrostatic pressure at the shoe (Pshoe) is when 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). P~o~ = MSP + .052*MW*D~o, Pshoe= 815 psi FPshoe= 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 * Dsho~ DP shoe= 321 psi The DPshoe is less that the internal yield of the casing. KTGP53.XLS 13-38" MSP 1/15/96 Maximum Kick Tolerance Calculations Well: GP 53 Casing Shoe: 13-3/8" General Information Variables 1 13-3/8" Casing Shoe (from RT)+B6 1,099 iFeet (TVD) Dshoe 2 Fracture pressure Gradient 0.85 psi/FT FPG 3 Fracture pressure at the 26" Shoe 934 psi FPshoe 4 Proposed TD of the 9-5/8" Casing Shoe (TVD) 3,483 Feet (TVD) Dm 5 Pore pressure gradient 0.450 psi/FT PpG 6 Maximum anticipated pore pressure ~ TD 1,567 psi Pmax~r> 7 Mud Weight See table PPG MW 8 Gas Gradient 0.10 psi/FT GG 9 Average open hole size 12.25 Inches ODo, 10 Drillpipe OD 5.00 Inches ODDp 11 Capacity of open hole by drillpipe 0.1214 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/Fr. 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 (Ht) calculation with gas bubble top at 13-3/8" shoe. FPshoe + Pgas bubble + Pmud = Pmax~ TD FPsho, + GG*Ht + .052*MW*(Dm-D~ho~-Ht) -- Pm~m Gas Volume (GV) calculation at 13-3/8" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in wellbore at TD. P1V 1 = P2V2. Assume constant temperature. Kick Tolerance * P~ m = GV * FP Mud Weight Gas Bubble Height Gas Volume~Shoe Kick Tolerance (PPG) (FeeO (BBLS) (BBLS) 7.0 889 108 64 7.2 945 115 68 7.4 998 121 72 7.6 1,047 127 76 7.8 1,092 133 79 8.0 1,135 138 82 8.2 1,174 143 85 8.4 1,212 147 88 8.6 1,247 151 90 8.8 1,280 155 93 9.0 1,311 159 95 9.2 1,341 163 97 9.4 1,369 166 99 9.6 1,395 169 101 9.8 1,420 172 103 10.0 1,444 175 105 10.2 1,467 178 106 10.4 1,488 181 108 10.6 1,509 183 109 10.8 1,529 186 111 11.0 1,.548 188 112 KTGP53.XLS 1/15/96 Maximum Surface Pressure Calculations Well: GP 53 Casing Size: 9-5/8" Depth Interval: 0'-12,800' Hole Size: 8.50 General Information: Anticipated Mud Weight (MW): 9.0 PPG Shoe Depth (D,ho~): 3500 MD Estimated Fracture Gradient (at the Shoe): Total Depth (Dm): 12,800 MD Bottom Hole Pressure Gradient (BI-~G): Gas Gradient (GG); (assumes worse case): Maximum Gas Column Height in wellbore when top of gas is at the shoe (Ht): 0.468 psi/FT 3483 TVD 0.85 psi/FT 10257 TVD 0.50 psi/FT 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 in wellbore when top of gas bubble is at the shoe- during a gas kick situation. A percentage of the gas column height (I-It), found in the Maximum Kick Tolerance Calculations, is used. Maximum Surface Pressure = Maximum Bottom Hole Pressure - Hydrostatic Pressure (Gas Volume +Mud Volume) MSP = Proem- GG*Ht - .052*MW*(Ehv-Ht) MSP = 1,046 psi Hydrostatic Pressure at the Shoe Calculations: The greatest hydrostatic pressure at the shoe (Pshoe) is when 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). P~o~ = MSP + .052*MW*D~o~ Pshoe = 2,676 psi FP,~e = 2,961 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~ho~ DP shoe = 934 psi The DPshoe is less that the internal yield of the casing. KTGP53.XLS 9-58" MSP 1/11/96 Maximum Kick Tolerance Calculations Well: GP 53 Casing Shoe: 9-5/8" General Information Variables 1 9-5/8" Casing Shoe (l~om RT) 3,483 Feet (TVD) D,ho~ 2 Fracture pressure Gradient 0.85 psi/FT FPG 3 Fracture pressure at the 9-5/8" Shoe 2,961 psi 4 Proposed TD of the 7" Casing Shoe (TVD) 10,257 Feet (TVD) Dm 5 Pore pressure gradient 0.50 psi/FT PpG 6 Maximum anticipated pore pressure ~ TD 5,129 psi Pm~4~O 7 Mud Weight See table PPG MW 8 Gas Gradient 0.10 psi/FT GG 9 Average open hole size 8.50 Inches ODoH 10 Drillpipe OD 5.00 Inches ODvP 11 Capacity of open hole by drillpipe 0.0459 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/Fl'. (GP 13-13; 1967) MI calculations assume that water based mud is used and does not take into account gas solubility in oil based mud. Gas bubble height in weilbore (Ht) calculation with gas bubble top at 9-5/8" shoe. FPshoe + Pgas bubble + Pmud = Pmax@ TD FP~o~ + GG*Ht + .052*MW*(DrD-D~I-It) = P~rD Gas Volume (GV) calculation at 9-5/8" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in wellbore at TD. P1V1 = P2V2. Assume constant temperature. Kick Tolerance * Pm~*V = GV * FP Mud Weight Gas Bubble Height Gas Volume ~ Shoe Kick Tolerance (PPG) (Feet) (BBLS) (BBLS) 7.0 1,128 52 30 7.2 1,342 62 36 7.4 1,540 71 41 7.6 1,725 79 46 7.8 1,897 87 50 8.0 2,057 94 54 8.2 2,207 101 58 8.4 2,348 108 62 8.6 2,481 114 66 8.8 2,606 120 69 9.0 2,724 125 72 9.2 2,835 130 75 9.4 2,940 135 78 9.6 3,040 139 81 9.8 3,135 144 83 10.0 3,225 148 85 10.2 3,311 152 88 10.4 3,393 156 90 10.6 3,470 159 92 10.8 3,545 163 11.0 3,616 166 96 KTGP53 .XLS 1/9/96 Maximum Surface Pressure Calculations Well: 53 Casing Size: 7" Depth Interval: 0'-15,700' Hole Size: 6.00 General Information: Anticipated Mud Weight (MW): 9.0 PPG Shoe Depth (D~ho,): 12,800 MD Estimated Fracture Gradient (at the Shoe): Total Depth (Dm): 15,700 MD Bottom Hole Pressure Gradient (BHPG): Gas Gradient (GG); (assumes worse case): Maximum Gas Column Height in wellbore when top of gas is at the shoe (I-It): 0.468 psi/FT 10257 TVD 0.85 psi/FT 10815 TVD 0.52 psi/FT 0.10 psi/FT 4,500 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 (I-It), 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*(Dq~Ht) MSP = 2,218 psi Hydrostatic Pressure at the Shoe Calculations: The greatest hydrostatic pressure at the shoe (Pshoe) is when 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). P~hoe = MSP + .052*MW*D~ho~ Pshoe-- 7,019 psi FPshoe= 8718 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 - BI-IPG * DP shoe-- 1,685 psi The DPshoe is less that the internal yield of the casing. KTGP53.XLS 7" MSP 1/9/96 Maximum Kick Tolerance Calculations Well: GP 53 Casing Shoe: 7" General Information Variables 1 7" Casing Shoe (from RT) 10,257 Feet (TVD) D,ho, 2 Fracture pressure Gradient 0.85 psi/FT FPG 3 Fracture pressure at the 7" Shoe 8,718 psi FPao, 4 Proposed TD of the 4-1/2" Casing Shoe (TVD) 10,815 Feet (TVD) Dm 5 Pore pressure gradient 0.52 psi/FT PpG 6 Maximum anticipated pore pressure ~ TD 5,624 psi 7 Mud Weight See table ?PG MW 8 Gas Gradient 0.10 psi/FT GG 9 Average open hole size 6.00 Inches ODoH 10 Drillpipe OD 3.50 Inches OD~P 11 Capacity of open hole by drillpipe 0.0231 BBL/FT CAP 12 Height of gas column in wellbore when top of gas is at the shoe lit Feet (TVD) Ht Assumptions for Granite Point Field: Fracture Pressure Gradient = .9 PSI/VF; and Maximum Pore Pressure Gradient = .52 PSI/FF. (GP 13-13; 1967) 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 (Ht) calculation with gas bubble top at 7" shoe. FPshoe + Pgas bubble + Pmud = Pmax~ TD FP,ho, + GG*Ht + .052*MW*(DT~D,~o,-Ht) = P,n~x~m Gas Volume (GV) calculation at 7" shoe. GV = CAP*Ht Kick Tolerance calculation: Gas volume in wellbore at TD. P1V1 = P2V2. Assume constant temperature. Kick Tolerance * P,~x~ m = GV * FP Mud Weight Gas BubbleHeight Gas Volume~Shoe KickTolerance (PPG) (Fee0 (BBLS) (BBLS) 7.0 12,492 288 447 7.2 12,039 278 430 7.4 11,620 268 415 7.6 11,230 259 401 7.8 10,867 251 388 8.0 10,528 243 376 8.2 10,210 235 365 8.4 9,912 229 354 8.6 9,632 222 344 8.8 9,368 216 335 9.0 9,119 210 326 9.2 8,884 205 318 9.4 8,661 200 310 9.6 8,450 195 302 9.8 8,250 190 295 10.0 8,059 186 288 10.2 7,878 182 282 10.4 7,705 178 275 10.6 7,540 174 270 10.8 7,383 170 264 11.0 7,233 167 259 KTGP53 .XLS 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 ll-13rd 2/14/92 9-5/8" 0.961 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" 0.871 1,010 16.8 GPP 51 8/25/92 9-5/8' 1.051 9,592 20.2 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" 0.93 9,877 17.9 Anna 1 ltd 10/23/94 13-3/8" 0.89 2,976 17.2 Anna llrd 11/11/94 9-5/8" 0.92 8,750 17.7 * Anna 3rd 12/10/94 9-5/8" 0.75 7,839 14.5 Anna 50 2/8/95 18-5/8" 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 16.51 Anna 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 6/3/95 9-5/8" 0.88 9,842 17 * Anna 52 2/3/95 18-5/8" 1.41 1,153 27 Anna 52 3/27/95 13-3/8" 0.84 3,940 16.151 Anna 52 4/15/95 9-5/8" 0.91 9,470 17.6 * Anna 7rd2 8/25/95 9-5/8" 0.96 4,439 18.5 Anna 7rd2 9/6/95 7" 0.82 9,589 15.8 Notes: All fracture gradients reported have been corrected for air and water gaps. * Indicates a (FIT)-Formation Integrity Test was achieved, not actual leak off. FRACDATA.XLS 1/4/96 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 Granite Point Field Fracture Gradient Data 0.2 0.4 0.6 0.8 1 Fracture Gradient (PSI/FY) 1.2 1.4 1.6 FRACDATA.XLS 1/4/96 A~T 1758~,~ 3% ADL- UNOCAl MOBIL -- __ ~-100% 256d AC 3-3 -98 UNOCA MOBIl ADL-~ :L-25% -75% 74044 MOBIIJ- 7'5% 2560 3-3 ADL- AC -98 74045 lb ':. 0 i ! 1,54_ !, J ,, ! - I -I - le #53 I - ' UNOCAJL- 25% 15o6o AC! HBP II -1874 L 'I I I '4. 14 * {... I'53+ 2000+ FEET Unocal Corporation P.O, Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOr..AL G. Russell Schmidt Drilling Manager Thursday, January 11, 1996 Dear Mr. Johnston: Mr. David Johnston Commissioner Alaska O&G Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 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 ali 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- 3/8" 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 WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION ENGINEERING GEOLOGY COMPANY J~~,/ WELL NAME ~~. -, J/~ /~D~_ . ~ PROGRAM: exp [] dev'. redrll [] serv [] wellbore '7 REMARKS 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool .............. y ~ ~~//~ ~,~ J~_~ 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 ..... Y 12- Permit can be issued without administrative approval- --~~-e6--JW'~,~. 13. Can permit be approved before 15-day wait ....... 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf cng . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... 33. Seabed 'condition survey (if off-shore) ....... /Y N 34. Contact name/phone for weekly progress reports . . ./< . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMI SS ION: JDH ~ JDN TAB /I ~ I - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS i~ Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimul~ie: Change approved program: Pull tubing: Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: 114.75 RKB (MLLW) feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: x Granite Point Field 4. Location of well at surface Leg 4, Slot #3 8. Well number 3980' W and 2854' N from SE corner Sec. 13, T10N, R12W, SM 53 ADL 1786/374045 At top of productive interval 9. Permit number 96-0014 At effective depth 10. APl number 50- 733-20471 At total depth 11. Field/Pool Granite Point Field/Middle Kenai "C" Sands 12. Present well condition summary Total depth: measured 16,657' feet Plugs (measured) true vertical 11,071' feet Effective depth: measured 16,513' feet Junk (measured) true vertical 11,042' feet Casing Length Size Cemented Measured depth True vertical depth Structural 182 33" Driven 229 229 Conductor 247 26" Driven 294 294 Surface 984 13-3/8" 1213 sx 1031 1030 Intermediate 4,506 9-5/8" 1369 sx 4551 4088 Production 13,275 7" 500 sx 13323 10471 Liner 3,725 5" 377 sx 16634 10266-11067 Perforation depth: measu red 13,339'- 14,500; 14,590'-14,595' (Squeezed); 15,250'-16,900' (Squeezed) true vertical 10,478'-10,730'; 10,743'-10,744(Squeezed); 10,817'- 11,123'(Squeezed) Tubing (size, grade, and measured depth) 3-1/2" 9.2 Ib/ft L-80 12,972' Packers and SSSV (type and measured depth) HES Versatrieve Packer @ 12,900' 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: Directional Program Temperature survey X Schematic X Op characteristics plot ' X 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: X 17. I hereby certify that.~ foregoing is true and correct to the best of my knowledge. Je clan Signed: %/~yn Cf FoRTitle:cOMMISSIoNWater flood technicianusE ONLY Date: 6/18/2002 I No Conditions of approval: Notify Commission so representative may witness _ . Plug integrity___. BOPTest_ __ Location clearance Mechanical Integrity Test_.~,' ,~-" Subsequent form required 10- t~,~.~,¥,~,,.t ~,~,~k~'~s,~1 :~ ~x ~,~\~,,-..~, .x~x.1 c3~ JUH 1 9 2002 Original S~gned By Allchorage Cammy Oe~sl~ T~ Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORi®!NAL SUBMIT IN HOOd SlX'8090~O0~ k/OSCj.f/:d9 I/~V 0~:/_. ~O0~/g i./9 III 688"8 I. uo!~.~Jeped do.L r~ 006';~ I.a~Oed . ~ __ 4 'dtue.l. ......... 00o~ O00~L O000t 0009 O009 000~ 000~ 0St 09t O~t Ogt OOt 08 09 Off O~ 0 ~eAJns eJn~eJedLue.L d dine1 ;gOO;g/g/9 ~c~ d9 Pressure 0 0 0 0 C~ 06/16/02 o o o o o o )2 )2 ~2 ! 121 o 06/07/02 05/29/02 05/20/02 05/11/02 05/02/02 04/23/02 04/14/02 04/05/02 03/27/02 03/18/02 03/09/02 02/28/02 02/19~02 02/10/02 02/01/02 01123/02 01/14/02 01/05/02 12/27/01 12/18/01 12/08/01 11/29/01 11/20/01 11/11/01 11/02/01 10/24/01 10/15/01 10/06/01 09/27/01 09/18/01 09/09/01 08/31/01 08/22/01 08/13/01 08/03/01 07/25/01 07/16/01 07/07/01 06/28/01 06/19/01 0 C) (:D C:) 0 0 0 0 0 0 C) 0 0 Rate GRANJ. E POINT PLATFORM WELL # 53--Water Injector Final Com letion: 8/29/97 RKB = 114.75"; 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 1,031 9-5/8 47 L-80 BTC 46 73 9-5/8 53.5 P-110 BTC 73 4,551 7" 29 P-110 KC-BTC 45 6,989 7" 29 L-80 KC-BTC 6,989 13,323 5" 15 L-80 SC-KC-BTC 12,909 16634 SC-Buttress 43.44 12,914 STL 12,914 12,970 Baker 5" HMC liner hanger ~ 12,921 3-1/2" 9.2 L-80 3-1/2" 9.2 L-80 JEWELRY DETAIL NO. ITEM DEPTH 1 Kvaemer Tubing Hanger 43.44 (AB TC-4S Up X STD VAM DWN) 2 STD VAM x Buttress Pup JT 47.5 3 HES "X" Nipple ID = 2.813" 12,857 TOL ~ 12,909 4 Halliburton VLT Versatrieve Packer with 12,900 seal bore extension. 5 Seal Assy. (Length = 13.12') crossed over 12900 to 3-1/2" STL tubing. 6 Mule-shoe guide 12,971 7 C-5 SAND 7 EZSV Cement Retainer 14,530 8 EZSV Cement Retainer 15,112 PDTD = 14,530 MAX HOLE ANGLE _+ 80 o ~ 13,800' PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 13,339 14,500 C-5 14,590 14,595 C-5 15,250 16,900 C-5 6 8/15/97 Exisiting Interval 6 8/14/97 Squeezed 6 8/4/97 Squeezed $CANNEE; ' IlG g lj. GP 53 final 8-29-97.doc REVISED: 9/16/97 DRAWN BY: MWD Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 RECEIVED JUH I 9 2002 UNOCAL Anch0rao~, June 18,2002 State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Attn: Tom Maunder Re: Granite Point Injection WeI1,GP-53 Dear Mr. Maunder: A temperature survey was run on 6/8/02 for the purpose of demonstrating that Granite Point 53 (Permit # 1960140, API# 50-733-20471-00) is injecting into the desired Tyonek C-5 reservoir and there is no flow into any fresh water aquifers or shallow reservoirs. I am enclosing a plot of the temperature survey, a plot of the operating characteristics over the last year, and a current well bore schematic. The temperature survey plot starts approximately 100 feet below the packer and 30 feet above the perforated interval. No significant departures from the geothermal gradient are apparent on the plot. We believe there is minor tubing / casing communication due to leaking packer seals. We have been operating this well with the tubing and casing at equal pressure, 4000 psi. to minimize further damage. The 70% burst strength of the 9 5/8 casing is 5700 psi. It is Unocal's opinion that the well can be operated safely with no risk to shallow fresh water aquifers or gas zones. Please grant us permission to continue injection into this well under the assumption that we will monitor the various annuli daily and report this data monthly, and we will run a temperature survey every two years. Also enclosed is a 10-403 for your approval. If you have any questions regarding this, please contact myself at 263-7807 or Hal Martin at 263-7675. Jeffery J tDolan Waterflood Technician Cook Inlet Waterflood Management Enclosures SCANNED AUG g .l 2002 ORIGINAL AOGCC Granite Point GP-53 Application for Variance jjd UNDERGROUND INJECTION CONTROL PROGRAM ALASKA OIL AND GAS CONSERVATION COMMISSION Authorization to Inject with an Integrity Loss Sundry application ~O~-\~\ forwell Q~,~-~q ~>'~ ~>'~ ,PTD ~63o©\~is approved to allow the well to remain in injection service. This approval is subject to the following conditions: Confirmed T x IA communication, rate not quantifiable. Water Injection ONLY 4 Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. Annual MITIA/LLRT 4 year CMIT T x IA Confirmed T x IA communication, > 10 gpm. Water Injection ONLY Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. 2~MIT T'xqxA--C&bing leh~T T'~ac.~ leak) ~_~r~ V Pr~duct~o~ Casing ~eak Water Injection ONLY Daily Pressure (tubing and all annuli) and Rate Monitoring with a monthly report of this information to the Commission. Annual MITT Annual CMIT IA x OA IA x OA Communication Water Injection ONLY Daily Pressure (tubing and all almuli) and Rate Monitoring with a 1 monthly report of this information to the Commission. Annual MITT Annual CMIT IA x OA Alarm w/injection shutdown on OA. Set point minimum 1000 psi < minimum burst strength of outside casing. This approval is specific for the identified integrity loss. Should pressure/rate monitoring indicate a change in the well conditions, the following applies: Type 4 changes to Type 3, notify Commission on next business day and secure permission to continue operations. If well already has Type 4 or 3 integrity loss and monitoring indicates Type 2 or 1 may have developed, secure well immediately and notify the Commission on the next business day. By Order of the Commission Re: Permission to continue injection in GP-53 Subject: Re: Permission to continue injection in GP-53 Date: Thu, 10 Jan 2002 16:27:23 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Ruff, Christopher ^" <ruffc@unocal.com > Chris, Your request and justification are appropriate. You correctly note that were a problem to develop that the change in the monitored parameters would be a flag. By copy of this email, you have approval to resume injection and conduct the temperature survey. Tom Maunder, PE AOGOC "Ruff, Christopher A" wrote: Tom, I don't know if you are handling GP-53's 10-403 which requests permission to continue injection and time extension. Please move this one to the front of my requests if at all possible. We currently have this well shut-in and would like to turn it back on so the injection intervals will stay cool. This will allow us to run the temperature survey to prove the integrity of the wellbore. There is no risk to any fresh water aquifers or any shallow hydrocarbon intervals (there aren't any of either present), so continued injection causes no risk. For that matter the results of the temperature survey are somewhat academic for the same reasons. Never the less we want to run the survey to be thorough, then apply for the variance. The only real risk is a shallow leak that allows pressure to be transmitted to the backside of nearby wellbores, if this were to occur I would expect a rapid increase in injection rate coincident with a drop of injection pressure which would be caught by our daily surveillance system. Attached is a copy of the letter that was submitted with the 10-403. <<Aogcc GP53 Time extension 12-31-01.doc>> Thanks Chris Name: Aogcc GP53 Time extension 12-31-01.doc Aogcc GP53 Time extension 12-31-01.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder~admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 6~20~2002 11:13 AM TONY KNOWLE$, GOVERNOB ALASKA OIL AND GAS CONSERVATION COMMISSION October 23.1997 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ADMINISTRATIVE APPROVAL AIO NO. 11.2 Re: The application of Union Oil Company of California to expand the affected area of Area Injection Order No. 11. Rick D. Cross Landman Unocal Alaska Resources UNOCAL Corporation P. O. Box 196247 Anchorage, AK 99519-6247 Dear Mr. Cross: The drilling and completion of well Granite Point No. 53 (GP No. 53) has demonstrated that the originally established affected area of Area Injection Order No. 11 did not include the southern extent of the Granite Point Middle Kenai Oil Pool. The portion of the accumulation penetrated by GP No. 53 has been depleted; however, operation of the well as an injector w'ill increase ultimate recovery from the Granite Point Middle Kenai Oil Pool. Pursuant to your v~Titten request dated August 27, 1997, and subsequent correspondence from UNOCAL dated September 23, 1997, the Alaska Oil and Gas Conservation Commission hereby authorizes the expansion of the affected area of Area Injection Order No. 11 to include the north half of Sections 25 and 26 and the northeast quarter of Section 27 in Township 10 North, Range 12 West, Seward Meridian. ! ~N~~.~hl~g~laska this day October 23, 1997. o Cammy O~chsli Commissioner TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION October 23, 1997 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re' ADMINISTRATIVE APPROVAL NO. 76.32 The application of Union Oil Company of California to expand the affected area of Conservation Order No. 76. Rick D. Cross Landman Unocal Alaska Resources UNOCAL Corporation P. O. Box 196247 Anchorage, AK 99519-6247 Dear Mr. Cross: The drilling and completion of well Granite Point No. 53 (GP No. 53) has demonstrated that the originally established affected area of Conservation Order No. 76 did not include the southern extent of the Granite Point Middle Kenai Oil Pool. The portion of the accumulation penetrated by GP No. 53 has been depleted; however, operation of the well as an injector xvill increase ultimate recovery from the Granite Point Middle Kenai Oil Pool. Pursuant to your written request dated August 27, 1997, and subsequent correspondence from UNOCAL dated September 23, 1997, the Alaska Oil and Gas Conservation Commission herebv authorizes the expansion of the affected area of Conservation Order No. 76 to include the north half of Sections 25 and 26 and the northeast quarter of Section 27 in Township 10 North, Range 12 West, Seward Meridian. Davtd, xW. Johnst(~n Robert_N._ Christenson, P.E. echsli Chairm Commissioner Commissioner :5CANNED' AUG1 2002 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re'. The application of Union Oil Company of California (Unocal) for expansion of the affected areas of Conservation Order No. 76 and Area Injection Order No. 11 in the Cook Inlet offshore Granite Point Oil Field in Southcentral Alaska. Unocal by letter dated September 22, 1997 has requested an expansion of the affected areas of Conservation Order No. 76 and Area Injection Order No. 11. Information obtained through the recent drilling of Granite Point well No. 53 indicates that recoverable reserves within the Granite Point Middle Kenai Oil Pool may be present on lease Nos. ADL 374044 and ADL 374045 which are currently outside the affected areas of the subject orders. The requested action would allow Unocal to operate Granite Point well No. 53 as an injector or as a producer within the C-5 Middle Kenai reservoir. The well-encountered oil saturations that indicate the Middle Kenai oil Pool may have originally extended through the prop(psed area of expansion. A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 pm October 9, 1997 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 October 28, 1997 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 October 9, 1997. 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 October 21, 1997. Chairman Published September 25, 1997 ADN 02814008 AlaSKA OIL AND GAS CONSERVATION COMMISSION September 5, 1997 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dale ltaines Drilling Manager Union Oil Company of California P.O. Box 196247 Anch. Ak. 99519 Mr. Haines: The attached approval to convert well Granite Point No. 53 to a Class II water injector is limited to the downhole operations described in your application. Operation of the well as an injector is not approved herein. Expansion of the affected areas of Conservation Order No. 76 and Area Injection Order No. 1 i is required prior to operating the well as an injector. We have been in contact wilh Rick Cross of your office concerning these .,.natters, he or Bob Crandall at the AOGCC can provide any additional intbrmation you may require. ~avid W. Joh'~.,~ Chairman Attachment 2002. Unocal Alaska Resou,~s Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL August 27, 1997 Mr. Bob Crandall ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, AK 99501-3192 ORIGINAL Granite Point Field PROPOSED CHANGE TO AREA INJECTION ORDER #11 & CONVERSION OF GRANITE POINT #53 ADL 374045 Dear Mr. Crandall: On September 29, 1986 the AOGCC issued Area Injection Order No. 11 establishing area wide injection covering Section 18 & 19 of T10N, R11W, S.M., and Section 2,11,13, 14, 23, &24, and E/2 SE/4 of Section 15, NE/4 NE/4, S/2 NE/4, SE/4, & SE/4 SW/4 of Section 22 ofT10N, R12W, S.M. Unocal, as operator of the Granite Point Field, requests that Area Injection Order No. 11 be amended to include the N/2 of Sections 25 & 26, and the NE/4 of Section 27 o£T10N, R12W, S.M. The additional area is needed to encompass a structural high that dips southwesterly across a portion of Sections 25 & 26 and into Section 27. Injection of produced water into this area will enhance the recovery of hydrocarbons, and may eliminate the need to drill additional wells. Enclosed in triplicate is our "Application for Sundry Approvals" (form 10-403) to covert the Granite Point #53 development well to an injection service well. Also enclosed is a "Verification of Application" by the undersigned stating that the applicant is acquainted with the facts pursuant to 20 ACC 25.280. Enclosures Sincerely, UNION OIL COMPANY OF CALIFORNIA, d.b.a. UNOCAL ! /~- :'//. '..--:'~2"/ ' ~'_/ . .~" .i~'---- / 'ffi~ D. Crosg ...... /~"~ .... '~' Landman ~ ~ ~,~ ? ~J N Ol 1 N 11 1997 GRANITE POINT DRILLING PROGRAM C-5 STRUCTURE MAP Area Injection Order 11 http://www.stato--'-.us/local/akpages/Al)MIN/ogc/oindex/aio/aio I 1 .htm STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE REQUEST OF UNION OIL COMPANY OF CALIFORNIA for an Area Injection Order for the portion of the Granite Point Field developed by the Granite Point Platform ) Area Injection Order No. 11 ) ) Southern Portion of ) Granite Point Field ) ) ) September 29, 1986 IT APPEARING THAT: 1. Union Oil Company of California (Union) requested the Alaska Oil and Gas Conservation Commission to issue an area injection order permitting the underground injection of fluids within a portion of the Granite Point Field for purposes of enhanced hydrocarbon recovery. 2. Notice was published in the Anchorage Daily News on September 12, 1986 of an opportunity for a public hearing on October 13, 1986. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly, the Commission will, in its discretion, issue an order without a public hearing. FINDINGS: 1. An order permitting the underground injection of fluids on an area basis, rather than for each injection well individually, provides for efficiencies in the administration and surveillance of underground fluid injection operations. 20 AAC 25.460 provides the Commission with the authority to issue an order governing underground injection operations on an area basis. 2. The portion of the Granite Point Field developed by Union's Granite Point Platform constitutes a compact "project area" which can readily be described by governmental subdivisions. Union is the sole operator of this Project Area. 3. The Project Area encompasses approximately the southern one-third (1/3) of the Granite Point Field, Middle Kenai Oil Pool. The Project Area includes all existing injection wells and injection well sites planned for enhanced recovery of oil from this portion of the Middle Kenai Oil Pool. 4. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Granite Point Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(A) and 20 AAC 25.440(c). 5. Less stringent requirements for well construction, operation, monitoring, and reporting of 1 of 3 6/19/2002 3:49 PM Area Injection Order 11 http ://www.state~" ,us/local/akpages/ ADMIN/ogc/oindex/aio/aio l l.htm injection operations may be more appropriate than would be required when injection occurs into, through or above portions of aquifers not exempted. 6. The vertical limits of injection strata and confining formations may be defined in the Mobil Granite Point well No. 1. 7. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. 8. Statewide regulations and conservation orders govern field operations except as modified by this order. 9. To ensure that fluids injected are confined to injection strata, the mechanical integrity of injection wells should be demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions. 10. Injection wells existing on the date of this order were constructed and completed in accordance with regulations which conform to the requirements of 20 AAC 25.412. NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the following described area referred to in this order as the affected area: SEWARD MERIDIAN TION RllW T1ON R12W Sections 18 and 19. Sections 2, 11, 13, 14, 23 & 24. Section 15:El/2 SE1/4. Section 22:NE1/4 NE1/4, S1/2 NE1/4, SE1/4 and SE1/4 SW1/4. Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non-hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in the Mobil Granite Point well No. 1 between the measured depths of 7,725 feet and 10,800 feet. Rule 2 Fluid Injection Wells The underground injection of fluids must be: 1) through a well permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through a well approved for conversion to a service well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. Rule 3 Monitoring the Tubing/Casing Annulus Pressures The tubing/casing annulus pressure of each injection well must be checked weekly to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a AUG g 1 2DD2 2 of 3 6/19/2002 3:49 PM Area Injection Order 11 http://www.state ...... us/local/akpages/ADMIN/ogc/oindex/aio/aio 11 .htm hoop stress greater than 70% of the casing's minimum yield strength. Rule 4 Reporting the Tubing/Casing Annulus Pressure Variations Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 5 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi, or, assuming a 0.465 psi/ft gee-pressure gradient, a surface pressure that imposes a differential pressure gradient across the casing of 0.25 psi/ft at the vertical depth of the packer, whichever is greater; but not to exceed a hoop stress greater than 70% of the casing's minimum yield strength. The test pressure must be held on the tubing/casing for 30 minutes with no more than a 10% decline. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Rule 6 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Note: Rule 6 has been amended by Administrative Approval No. 11.1. Rule 7 Plugging and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accordance with 20 AAC 25.105. Rule 8 Administrative Relief Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated September 29, 1986 C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission Lonnie C. Smith, Commissioner Alaska Oil d Gas Conservation Commission W. W. Barnwell, Commissioner Alaska Oil & Gas Conservation Commission Area injection Order Index 3 of 3 6/19/2002 3:49 PM Administrative Approval No. 11.1 http://www.state.s" s/local/akpages/ADMIN/ogc/oindex/aio/aal 1-l.htm October 28, 1986 ADMINISTRATIVE APPROVAL NO. 11.1 Re' Amend Rule 6 of Area Injection Order (AIO) No. 11 Mr. Gerry Graham District Operations Manager Union Oil Company of California P. O. Box 190247 Anchorage, AK 99519-02479 Dear Mr. Graham' The Commission has determined that Rule 6 of AIO No. 11 as set forth is unclear as to the Connnission's intent. Therefore, Rule 6 is amended to read' Rule 6 Well Integrity Failure Whenever operating pressure observations or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must [IMMEDIATELY CEASE INJECTION,] notify the Commission on the first working day following the observation, [AND] obtain Commission approval [FOR CORRECTIVE ACTION] of a plan for corrective action, and when an USDW is not endangered, obtain Commission approval to continue injection. Sincerely, C. V. Chatterton Chairman Return to AiO No.ll 1 of 1 6/19/2002 3:49 PM STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Re: The motion of the Alaska ) Oil and Gas Conservation Com- ) mittee to determine if waste ) is occurring, to hear testi- ) mony on the initiation of a ) pressure maintenance project, ) the beneficial use of gas and ) other relevant matters; and ) the application of Mobil Oil ) Corporation and Pan American ) Petroleum Corporation for an ) order authorizing water in- ) jection for pressure mainten- ) ance or secondary recovery ) purposes and for the consoli- ) dation and revision of Con- ) servation Orders No. 59 and ) No. 60; Granite Point Field. ) Conservation Order No. 76 Granite Point Field: Pressure Maintenance Project, Field Rules and Beneficial Use of Gas Granite Point Middle Kenai Oil Pool September 12, 1969 IT APPEARING THAT: 1. The Alaska Oil and Gas Conservation Committee moved to hold a public hearing to hear testimony by the operators of the Granite Point Field to determine if waste is occurring as a result of producing the Middle Kenai Pool and to hear testimony on the initiation of a pressure maintenance project for the Middle Kenai Pool, the beneficial use of gas produced as the result of crude oil production and any other matters relevant to the proper development and operation of this pool. 2. Notice of the hearing was published in the Anchorage Daily News on July 17, 1969. 3. Mobil Oil Corporation and Pan American Petroleum Corporation, as operators of the Granite Point Field, by application received July 22, 1969, petitioned the Committee for an order authorizing water injection for pres- sure maintenance or secondary recovery purposes in the Granite Point Field and for the consolidation and revision of Conservation Orders No. 59 and No. 60. 4. A public hearing was held in the City Council Chambers of the Z. J. Loussac Library, Anchorage, Alaska, on August 15, 1969. Testimony was pres- ented in response to the motion and in support of the petition, and affected and interested parties were heard. CONSERVATION ORDER NO. 76 Page 2 September 12, 1969 AND IT FURTHER APPEARING THAT: 1. The Middle Kenai Pool should be re-named the Granite Point Middle Kenai Oil Pool. of the Granite Point Middle Kenai Oil Pool is essentially 2. Development pool limits have been reasonably well defined. complete and the e undersaturated and maximum recovery of oil 3. The reservoir fluids ar ...... ~ -~overv method is used. will not be achieved unless some a~oztzona~ ~ : 4. Water injectivity tests indicate the feasibility of injecting fluids into the Granite Point Middle Kenai Oil Pool to supplement the natural reservoir energy and thereby achieve increased oil recovery. 5. There is a substantial variance in permeability between crestal wells and downdip or flank wells and more than one injection pattern may be advisable. 6. Lease line injection wells should confine reservoir fluids to each operator's leases and thereby protect correlative rights. 7. The value of the additional recovery from a fluid injection project will exceed the cost of such a project. 8. The operat°rs have increased their use of produced gas but some gas is being flared. 9. Negotiations with potential purchasers of produced gas indicate there is no market for the flared gas and the findings of Conservation Order No. 61 with respect to the Granite Point Field have not materially changed. 10. Conservation Orders No. 59 and No. 60 should be revised and consoli- dated herein. , C NED 1 2002 CONSERVATION ORDER NO. 76 Page 3 September 12, 1969 NOW, THEREFORE, IT IS ORDERED that the rules herein set forth apply to the following described area: Township 10 North, Range. 11 West, S. M. Sections 5, 6, 7, 8, 18 and 19: Ail Township 10 North, .Range 12 West~ S. M. Sections 1, 2, 11, 12, 13, 14, 23 and 24: Ail Section 15: E 1/2 SE 1/4 Section 22: NE 1/4 NE 1/4, S 1/2 NE 1/4, SE 1/4, SE 1/4 SW 1/4 Township 11 North, Range 1.1. ~est~ s. Sections 29, 30, 31 and 32: Ail Township...Lll' North~. Range !2 West. S. M. Section 25: E 1/2 NE 1/4, SE 1/4 Section 35: E 1/2 Section 36: Ail Rule 1. Definition of Pool. The Granite Point Middle Kenai Oil Pool is defined as the accumulation of oil common to and which correlates with the accumulation found in the Mobil-~Union Granite Point No. 1 well between the drilled depths of 7,725 feet and 10,800 feet. Rule 2... Spacing. (a) Not more than two completed wells shall be allowed in any govern- mental quarter section. (b) No pay opened to the well bore shall be nearer than 500 feet to any property line nor nearer than 1,000 feet to any well drilling to or capable of producing from the same pool. Rule 3. Casing and Cementing Requirements. Surface casing must be set and cemented to a depth of at least 1600 feet. Sufficient cement must be used to circulate to the surface. The production string must be cemented with a sufficient volume of cement to extend at least 500 feet above the shoe or a volume sufficient to cover 100 feet above the top of the uppermost producing zone encountered in the well, whichever is greater. Rule 4. Bottom Hole Pressure Surveys. A key well bottom hole pressure survey shall be made upon Committee request; provided, however, such surveys shall not be required more often than twice in any calendar year. The time and length of survey, number and location of wells, datum and other details will be determined by the Committee upon consultation with the operators. CONSERVATION ORDER NO. 76 Page 4 September 12, 1969 Rule 5. Gas-Oil Ratio Tests. A gas-oil ratio test of 24 hours duration shall be made annually on each producing well. The tests will be made during the months of June and July and the results will be reported on Committee Form P-9 prior to September of each year. The requirements' of this rule will be waived if monthly reported oil and gas production is based on a gas-oil ratio test made at least every six months in each producing well. Rule 6. Pressure Maintenance Pro~ec.t.. The injection of water for the purpose of pressure maintenance, secondary recovery or of conducting injectivity tests is hereby permitted in the Granite Point Middle Kenai Oil Pool. A semi-annual progress report detailing project operations and results shall be submitted to the Committee in January and July of each year. Rule 7. ~ Administrative. Approval. Upon request of the applicants and a showing that the affected parties have been notified of such request, the Committee may authorize the conver- sion or drilling of any well at any location, the termination or suspension of the project, or any operation reasonably designed, to further the purposes of the project. Rule 8. Other Conservation Orders. Conservation Orders No. 59 and No. 60 are hereby revoked. Ail other Conservation Orders affecting the Granite Point Middle Kenai Oil Pool shall remain in full force and effect, except as modified hereby. DONE at Anchorage, Alaska, and dated September 12, 1969. Thomas R. Marshall, Jr., ~xecutiv~ ecre~a~ Alaska Oil and Gas Conservation Committee Concurrence: Homer L. Burrell, Chairman Alaska Oil and Gas Conservation Committee 07 K. Gil~reth, J~.,- ~d~r Alaska Oil and Gas Conservation Committee RE: GP-53 minor leak first indications 3/10/99 Subject: RE: GP.53 minor leak first indications 31t0199 Date: Thu, 20 Jun 2002 12:13:59 -0700 From: "Dolan, Jeff J" <dolanjj@unocal.com> To: "'Tom Maunder"' <tom_maunder@adm in.state.ak, us> Tom, Not, bing from Blair. I have a fax receipt that shows Steve Tyler faxed Blair the 3/10/99 MIT on 3/31/99. We checked Stel,/~r~gmail records and mine but have nothing either way. I think in those days most communication was by fax or voice. L also. Ioo. ked in the basement well t~les.buLfo,unci.notJ3ing. LoOKing DaCE through the recoras Irma noJes mnalcaung ma[we first recognized GP-53 had minor leaks from an MIT conducted 3/10/99. The well passed but showed a 1 psi/min, one way leak. Diagnostics were run during the 2 weeks following the MIT from which we concluded that the packer seals were probably leaking. New guidelines je~ere issued 3/27/99 which were to operate the well @4,000 psi on the tubing and casing to minimize movement ~n the packer seals and minimize any further damage. This is my tracking spreadsheet with all the Unocal injector wells on it, dates, status etc. There are two rows of b_~l~~~t_op_. They either hide all the rows or expose a certain group, such as the Dolly wells or wells ---~_~_s. ~_~-(~~:ht~l~ HJ~nl~t~~ ~ tbJ~ll initialize some variables the macros use. The r~_. _u'n~..~]t~~l,~'~Z-~Ul~(~.~ ~r~rfie~6~Jrny printer assignment to prevent the macro from SuLb~:._~l~Pv?~Lr~r~r leak first indications 3/10/99 Regards; Th j6 rVu hav ything in thc 999 time Cram ?? Oil Asset Group Alaska Business Unit Unocal 76 Voice 907.263.7807 Fax 907.263.7884 Email dolanjj~unocal.com BG NED 11 I of I 6/20/2002 11:22 AM UIC File Review Date: Subject: PTD #: Orders.: Reviewers: Initiating Action: July 10, 2002 Unocal Granite Point (GP) Well 53 (Water Injector) 196140 CO 76 AIO 11 Tom Maunder, P.E. ~O ~- ,. ~ Jim Regg ~.~,~, Application for Variance Review Summary 1. According to the available records, Unocal reported minor (<1 psi/minute) communication in early March 1999, shortly after the well was converted to injection service. The well file (PTD #196140) does not include documents regarding the MIT failure. Per Unocal, diagnostics determined that the packer seals were leaking. Unocal continued operation in March 1999 with equal pressures in tubing and inner annulus (IA)1. On November 8, 2000, Jeff Jones (AOGCC Inspector) witnessed a MIT for a variance using annulus pressure monitoring (APM) that noted the tubing and IA pressures dropped simultaneously at 50 psi/15 minutes. 2. Unocal submitted request dated 6/18/02 (received 6/19/02) to continue injection; provided temperature survey and well performance data (injection rate, tubing and IA pressures) 3. Chronological Review of files revealed: a. CO 76 (September 12, 1969) b. AIO 11 (September 29, 1986) - Class II underground injection authorized for small "project area" as described in AIO c. AIO 11.1 (October 28, 1986) - clarification of Rule 6 ("Well Integrity Failure") d. Sundry Application (Form 10-403; August 27, 1997) - convert GP-53 from producer to water injector; request amendment ofAIO 11 since GP-53 injection zone is outside area authorized. e. AOGCC Sundry approval (September 5, 1997) - Sundry approved; well cannot be operated as an injection until CO 76 and AIO 11 expansions approved ,, f. Public Notice (September 25, 1997) - public comment solicited on Unocal application for expansion of CO 76 and AIO 11 g. Administrative Approvals CO 76.32 and AIO 11.2 (October 23, 1997) - expansion of Orders approved 4. Technical Evaluation of Request- Temperature survey indicates water injection confined to intended target; tubing and IA pressure communication evident from performance data; pressures less than 70% MIYP of adjacent and next outer casing. ~ IA - inner annulus; annulus between tubing and next outer protective casing 1~ecomrnendation File Review indicates compliance with provisions 0/'20 AAC 25, CO, and AIO (as amended). Approval of Unocal's request is recommended subject to following conditions: a. Monitor all casing annuli daily; report monthly unless there is a 10% change in pressure attributable to other than well performance (AIO Rule 3 requires weekly check of IA only) b. Run temp survey every 2 years (anniversary date is date of variance approval) and provide results to Commission. c. Perform combination MIT (tubing and and I,,A) every 2 y,e, ars (AIO Rule 5j':*~i set to isolate the tubing and annulus, an observation test may be performedby. 8,l ~e' well observing the pressure decline of the tubing and annulus. ~'~~