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196-056
Pages NOT Scanned in this Well History File xHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i~(.¢.O~.(~File Number of Well History File PAGES TO DELETE Complete RESCAN [] [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [3 Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy(~ Vincent Nathan Lowell Date: ~ ¥~.0 /s/L.~ [] TO RE-SCAN Notes: Re-Scannedby: Be~edyDiaenaVincent~.'at~ha. a~°weft Date:~.~' t~. 'slt~/ u., .. STATE OF ALASKA 1 . Z013 ALIPA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS z�.t3�; 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate 7 -- . Other 1E1 _.. , Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Co.-14 tJ i r Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeU❑ C",0 ,1.. 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: LG '- 4.4. Name: Hilcorp Alaska, LLC Development p Exploratory ❑ 196 -056 � �,,. 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99503 50- 733 - 20473 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017595 MGS ST 17595 32 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Middle Ground Shoal / Undefined Gas 11. Present Well Condition Summary: Total Depth measured 8,330 feet Plugs measured 7,226 feet true vertical 4,770 feet Junk measured 7,767' & 7,794' feet Effective Depth measured 8,250 feet Packer measured 6,624' feet true vertical 4,731 feet true vertical 3,895' feet Casing Length Size MD TVD Burst Collapse Structural 296' 32" 296' 296' Conductor Surface 792' 13 -3/8" 792' 771' 3,450 psi 1,950 psi Intermediate 3,015' 9 -5/8" 3,015' 2,052' 6,870 psi 4,760 psi Production 3,793' 7" 6,789' 3,975' 8,160 psi 7,020 psi Liner 1,661' 3 -1/2" 8,320' 4,765' 9,685 psi 7,853 psi Perforation depth Measured depth 7,268' - 8,180' feet SCANNED MAY 3 0 2O13 True Vertical depth 4,238' - 4,696' feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2# / L -80 6,685' (MD) 3,925 (TVD) Packers and SSSV (type, measured and true vertical depth) HES PHL Ret Pkr 6,624' (MD) 3,895' (TVD) SSSV: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gasp WDSPL GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -164 Contact Dan Taylor Email dtaylor @hilcorp.com Printed Name Dan Taylok- Title Operations Engineer Signature Phone (907) 777 -8420 Date 5/15/2013 RBDMS MAY 17 Ai; (�e LS—..1.....1.13 Form 10 -404 Revised 10/2012 %� Submit Original Only • Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BA -32 50- 733 - 20473 -00 196 -056 4/22/2013 4/23/2013 Daily Operations: 04/22/13 - Monday Spot equipment. Rig up lubricator and pressure test to 250 psi low and 2000 psi high. (1) RIH with 2.75' GR 5,500', work tools, and fell to 5,662' KB. POOH. (2) Add 1 -/34" wt bar and run down to 5,700'. Work tools and POOH. (3) RIH with 2 "x4' DD bailer down to 5,700'. Work tools and POOH. Bailer was filled with thick Poylmer. Had roller stem on it. Swab from surface to 1,825' approx. 31 bbls. Shut down for night. 04/23/13 - Tuesday Rig up lubricator. PT 250 psi low and 2500 psi high. 0 psi on 3 -1/2" and 9 -5/8 ". Tank had 31 bbls in it at start. RIH and swab from 750' (FL was at 500') to 1,450' with 33 runs. Going real well. Swab out 84 bbls total for both days. Run back in hole with swab cups to down to 1,600'. Tools lost weight and line went slack. POOH. RIH with 2 "x4' DD bailer to 1,567'. Bailed on obstruction and POOH. Bailer full of LCM. RIH with 2 "x4' DD bailer from 1,565' to 1,649'. Bailer full of LCM (same stuff) Sent pictures of LCM pill to town. RIH with 2 "x4' bailer and 1 -3/4" wts and bailed from 1,639' to 1,661'. Tools became stuck. Worked tools free and bailer full of same. POOH. Rig down slickline. Will have a meeting in the morning to see what options we have. TP - 0 psi and casing was 0 psi. • • • Baker Platform Ba -32 II SCHEMATIC N Middle Ground Shoal Last Completed: 06/30/1998 Gas Well Ililrorp 11a,ka. I.I.I RKB: MSL = 118' Mudline = 220' Water Depth= 102' 1 KB: MSL ADL: 17595 32 PTD: 196 -056 _1 JJJ Mean Sea Level Leg 4, Slot 8 API: 50 -733- 20473 -00 Mud Line xta. 3 32" ,._ Y Size Type Wt/ Grade/ Conn ID Top Btm Cement CMT d Sacks Top 13 -3/8" 32" Conductor Surf 296' Driven 13 -3/8" Surface 68#,K- 55,BTC 12.415" Surf 792' 795 Surf Top 24.8° Job 9 -5/8" Intermediate 47 #,L- 80,BTC 8.681" Surf 73' 2395' 53.5 #,P- 110,BTC 8.535" 73' 3015' 1136 Calc 60.4° - Caic ToC 6789' 2395 9.8 -. 7" Liner 29 #,L- 80,TKC -BTC 6.184" 2996' T 955 None PP9 ° brine 6790' 3 -1/2' Liner 9.2 #,L- 80,Butt 2.992" 6659' 8320' 372 CB zxP �Q 1rP ..................................................................................................._.................................. ........_.._.__................ -.._..._...................................................................._....................................................................................... ........... K 2696' 9-5/8" 3015 4 Tubing: 3 -1/2" Production 9.2 #, L -80 2.992" 39.00' 6685' Completion Jewelry Detail # Depth Length ID OD Item 1 39' Kvaerner Hanger (AB TC-4S DWN X STD VAM Up) 2 40' 2.992 3.500 3 -1/2" 9.2# L80 Tubing 3 301' 2.35 2.813 3.500 HES XXO Safety Valve Landing Nipple 2696' BOT HC -ZXP Liner Top Packer & HMC Liner Hanger 4 6584' 0.78 2.992 3.920 X -Over, 3 -1/2" x CS -Hyd 5 6585' 4.30 2.813 4.550 HES XU Dura sleeve Tbg Punch 6 6624' 5.19 2.885 5.980 HES 3 -1/2 x 7" PHL Retrievable Packer a ._ 6569' -6575' 7 6672' 3.000 4.125 BOT 80 -40 Seal Bore Extension (14.5') -_ 4 6659' BOT Hydroflow III 3-1/2" Liner Top Packer HES PHL 5 w - - -. - - -- Retrievable BOT High Flow 7 "x 3 -1/2" Liner Hanger w /tie -back 6624 6666' sleeve. 3- 1/2LTP �. I Liner Hanger 8 6688' 138 2.813" 3.950 HES X- Nipple 6659' w" 4 L 7 /,M:. w/ tie -back - - -- sleeve lj 8 4 r 6666' 04/23/13: 1,661' LCM obstruction (reference WellEz rpt 4/24/13) 10/22/10: Tubing punch 23 shots, 1- 11/16" x 6' perf gun, from 6569 — 6575' RKB. Well kill w/9.8 ppg KW brine. TOCCBL 10/3/10: Tag Pkr at 7226' RKB w /2.73" GR. 6769' 6796' 2005: Shallow leak in 13-3/8" casing allows communication to the 32" conductor. 2005: Tubing tested to 2170 for 35 min (good), 9 -5/8" tested to 1500 psi for 15 min (good w/ no change in 13- HES EZ Drill SV ' Squeeze Pkr@ , Ghoa hlineope r _ 3/8" pressure), then increased pressure on 9 -5/8" to 2000 psi for 40 min (good). No change on 13 - 3/8 ". .,.. 60, - -.� ' '226 ,._ a 6864'-6476 1997: Severe loss zone 6300' — 6700' MD, losses while running casing and no returns while cementing. HES ELITE ' Perfs — - - - -- Magna range BP ' ,. 7268' - 7440' @ 7376 i 4 FISH: Junk Pkrs "♦�' �� 8 pushed to 44 7767'87794 . -' Perforation Data Perfe 6070'-6160' Doglegs MD TVD Ghost hole 31/2 µ 8320' w/35" liner 9.87 538' 7268 - 7344 4238 -4277 4 HPF Isolated by Packer at 7226' KB 4.532 832' 7396 -7440 4301 -4327 4 HPF Isolated by Packer at 7226' KB PBTD =8250' TD =8330' 7.56 1067' 8070 -8180 4639 -4696 4 HPF Isolated by Packer at 7226' KB MAX HOLE ANGLE = 62.10 @ 2,226' MD / 1,657' TVD 6.06 1275' 8170 -8180 4691 -4696 HP Isolated by Packer at 7226' KB 6.60 1571' 6.45 6823' Updated by: JLL 05 /10/13 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, April 22, 2013 2:28 PM To: Juanita Lovett (jlovett@hilcorp.com) Cc: Bob Jones (robert Jones @repsol.com); Ted Kramer (tkramer @hilcorp.com); Juanita Lovett (jlovett@hilcorp.com); Bettis, Patricia K (DOA) Subject: RE: Baker - Well Ba -32 - Sundry #313 -164 (PTD 196 -056) - Additional set of perforations to original sundry Juanita , We don't have any issues with the new zone. Thanks for checking in with us first. The perfs can be added and reported with the final 10 -404. A new 10 -403 will not be required. Guy Schwartz Senior Petroleum Engineer SCANNED APR 2 3 2013 AOGCC 907 - 444 -3433 cell 907 - 793 -1226 office From: Bettis, Patricia K (DOA) Sent: Monday, April 22, 2013 2:19 PM To: Schwartz, Guy L (DOA) Cc: Roby, David S (DOA) Subject: RE: Baker - Well Ba -32 - Sundry #313 -164 (PTD 196 -053) - Additional set of perforations to original sundry Guy, I have no problem with the additional perfs from 7,087 to 7094 ft MD. The well will be open to production over 1626 ft from the property line where owner changes. Thanks, Patricia From: Schwartz, Guy L (DOA) Sent: Monday, April 22, 2013 1:45 PM To: Bettis, Patricia K (DOA) Subject: FW: Baker - Well Ba -32 - Sundry #313 -164 (PTD 196 -053) - Additional set of perforations to original sundry Can you look at these? Guy Schwartz Senior Petroleum Engineer AOGCC 907- 444 -3433 cell 907 - 793 -1226 office From: Juanita Lovett [ lai!tu;uiovFitt; ;.f iicsaf ,.com] Sent: Monday, April 22, 2013 1:41 PM 1 To: Schwartz, Guy L (DOA) • Cc: Ted Kramer; Daniel Taylor; Jacob Dunston; Reid Edwards Subject: Baker - Well Ba -32 - Sundry #313 -164 (PTD 196 -053) - Additional set of perforations to original sundry Guy, FYI. Sundry # 313 -164, approved on April 11, 2013, originally contained two planned sets of future perforations. Our geologist has identified an additional set of perforations we would like to add. These new perforations are located at _'_7 -t x,094' (MD) / ±4,138' ± (TVD). These perforations fall directly below the second set of perforations and fall within the same pool and same sands. Our intent is to proceed with the third set of perforations, which could happen as early as tomorrow. Please let us know if you require any additional information concerning this addition to the original sundry. Sincerely, Juanita Lovett Sr. Operations /Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Office: (907) 777-8332 Email: 2 • w �� '', s THE STATE Alaska Oil and Gas OF T� °fALASKA Conservation Commission 7. OF � GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Dan Taylor Operations Engineer ©5 � Hilcorp Alaska, LLC R 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Middle Ground Shoal Field, Undefined Gas Pool, MGS ST 17595 32 Sundry Number: 313 -164 Dear Mr. Taylor: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 11)41-A-7/1"---- Cathy 6V-I F oerster Chair DATED this /1 day of April, 2013. Encl. SCANNED APR 12 2013 0 _ : f v E STATE OF ALASKA ¶. IE ALASKA OIL AND GAS CONSERVATION COMMISSION AOk 1 ,..&) APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend El Plug Perforations ❑ Perforate 0 Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Install Patch G 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development GI • 196-056 - 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733-20473-00• 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 378 Will planned perforations require a spacing exception? Yes ❑ No 0 MGS ST 17595 32 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0017595 - Middle Ground Shoal / Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): - 8,330 4,770 - 8,250 • 4,731 7,226' 7,767' & 7,794' Casing Length Size MD TVD Burst Collapse Structural 296' 32" 296' 296' Conductor Surface 792' 13 -3/8" 792' 771' 3,450 psi 1,950 psi Intermediate 3,015' 9 -5/8" 3,015' 2,052' 6,870 psi 4,760 psi Production 3,793' 7" 6,789' 3,975' 8,160 psi 7,072 psi Liner 1,661' 3 -1/2" 8,320' 4,765' 9,685 psi 7,853 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,268' - 8,180' 4,238' - 4,696' 3 -1/2" 9.2# / L -80 6,685' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Packer: HES PHL Ret Pkr and SSSV: N/A Paker: 6,624' (MD) 3,895' (TVD) and SSSV: N/A 12. Attachments: Description Summary of Proposal CI 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development EI • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/15/2013 Oil ❑ Gas 0 • WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylorphilcorp.com Printed Name Dan T1iL1 / Title Operations Engineer i/' Signature ✓ Phone (907) 777 -8319 Date 4/2/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 -II (01/ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RRDMS APR 1 211S Spacing Exception Required? Yes ❑ No [ir Subsequent Form Required: ) CD - LI v q APPROVED BY Approved by .G r COMMISSIONER THE COMMISSION Date: - - // /3 Z � � L ./3 1 0 /� t Submit Form and r 1t> � Q o e�is /�1]2) Approved application is valid for 12 months from the date of approval. Attachments in �\ • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501 -3192 Re: THE APPLICATION OF UNION ) Conservation Order No. 378 OIL COMPANY OF CALIFORNIA) for an order granting an exception ) to spacing requirements of Title ) Union Oil Company of California 20 AAC 25.055 to provide for the ) Baker No. 32 drilling of the Baker No. 32 ' ) development gas welL ) March 26, 1996 • IT APPEARING THAT: 1. .Union Oil Company of California (Unocal) submitted an application dated March 6, 1996 requesting exception to 20 AAC 25.055(aX4) to allow drilling the Granite Point State No. 54 development gas well to a producing location that is closer than 1500 1110 feet to a drilling unit boundary. 2. Notice of opportunity for public hearing was published in the Anchorage Daily News on March 8, 1996 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: 1. The Unocal Baker No. 32 well as proposed will be a deviated hole drilled from a surface location 1987' from the north line and 478' from the west line of Section 31, T9N, R12W, Seward Meridian (SM) to a bottom -hole location 824' from the south line and 1775' from the west line of Section 19, T9N, R12W SM. • 2 Unocal is the owndr of all off setting spacing units. 3. An exception to 20 AAC 25.055(a)(4) is necessary to allow drilling of this welL CONCLUSION: . Granting a spacing exception to allow drilling of the Unocal Baker No. 32 well as proposed will not result in waste nor jeopardize correlative rights. • • - Conservation Oide_ r 4 7 `L • March 26, 1996 Page 2 41111 . • NOW, THEREFORE, IT IS ORDERED: Unocal's application for exception to 20 AAC 25.055 for the purpose of drilling the Baker No. 32 well is approved as proposed. DONE at Anchorage, Alaska and dated March 26, 1996. 411111 ITMlrpqllLtillk 1141111111111 David W. J, hnston, Ch A OIL 41. Alaska Oil : ' d Gas Con.- - ation Commission h R to � ��► • o = J. J. David Norton, P.E., Commissioner " Alaska Oil and Gas Conservation Commission 1 • 9 •Pp. JON CO ' Tuckerman Babcock, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed- The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission rduse_an•application by not acting on it within 10-day period.' Ari�affscted.fers4n has.30 'days. from the digit; die; Oommission refuses the application or mails (or otherwise diihributlis}' -an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (ie., 10th day after the application for rehearing was filed). • • > • 0 EERRATU.M CONSERVATION ORDER NO. 378 DATED MARCH 26,1996 First narasranh should read: • IT APPEARING THAT: 1. Union Oil Company of California (Unocal) submitted an application dated March 6, 1996 requesting exception to 20 AAC 25.055(a)(4) to allow drilling the Baker No. 32 development gas well to a producing location that is closer than 1500 feet to a drilling unit boundary. • . _ • . • ~ • • Well: BA -32 Hilcorp Alaska, LLC Date: 04/01/2013 Well Name: BA -32 API Number: 50- 733 - 20473 -00 -00 Current Status: SI Leg: 4 Estimated Start Date: April 15, 2013 Rig: WL Reg.Approval Requested? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 196 -056 First Call Engineer: Dan Taylor (907) 777 -8319 (0) (907) 947 -8051 (M) Second Call Engineer: Reid Edwards (907) 777-8421 (0) Pressures: Current BHP: - 2,055 psi @ 4030' TVD / 6900' MD .51 psi /ft., at mid -perf (9.8ppg brine to surface) Max. Exp'd BHP: - 1,733 psi @ 4030' TVD / 6900' MD .43 psi /ft., at mid -perf (SW gradient to surface) Max. Anticipated Surface Pressure: 1,318 psi @ 4030' TVD / 6900' MD 0.43psi /ft, at mid -perf (SW gradient and 0.106psi /ft gas gradient) Well Status: BA -32 is a gas producer which was SI October 2005 for platform abandonment preparation. In October 2010 23 tubing perforations were shot over 6' from 6569' to 6575'. Last tag on set packer was at 7226' (October 2010). Work Plan: Use WL to RIH and perforate new intervals in the 39A and 39B Set tubing patch over punched interval 6569' to 6575'. Procedure Summary: 1. RU E -Line. Pressure test lubricator to 1,850psi (500psi over max expected surface pressure). 2. RIH with 2.73" GR and tag packer at 7226'. 3. POOH and lay down GR. 4. Shoot fluid level to establish liquid level in wellbore. 5. RU and RIH with WL swabbing tool. Swab to 632'. 6. POOH and lay down swabbing tool. 7. RU and RIH with perforating guns (taking note of FL) and perforate 39B at 7053' to 7062' 8. POOH laying down perforating guns. 9. RU and RIH with 2 run of perforating guns and perforate 39A at 6900' t o 6930'.' 2- 10. POOH laying down perforating guns. 11. RU and RIH with tubing patch. Correlate to tubing tally and set patch over interval 6569' to 6575'. 12. POOH and lay down setting tool. 13. Pressure Test Tubing / pip / 1k . (so 14. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic C,t)a S f . • • Baker Platform Ba -32 ii SCHEMATIC N Middle Ground Shoal Last Completed: 06/30/1998 Gas Well Hilcorp Alaska, LLC RKB: MSL = 118' Mudline= 220' Water Depth= 102' i 1. 7 ' KB: MSL ADL: 17595 32 PTD: 196 -056 ' Mean Sea Level Leg 4, Slot 8 API: 50- 733 - 20473 -00 Mud Line 32" Size Type Wt/ Grade/ Conn ID Top Btm Cement CMT Al Sacks Top 13 - /8" 32" Conductor Surf 296' Driven 13 -3/8" Surface 68#,K- 55,BTC 12.415" Surf 792' 795 Surf Top 24.8° Job 9 -5/8" Intermediate 47 #,L- 80,BTC 8.681" Surf 73' 2395' 53.5 #,P- 110,BTC 8.535" 73' 4' 1136 Calc 2395' 9.8 8 7" Liner 29 #,L- 80,TKC -BTC 6.184" 2996' 6789' 955 None ppg 60.79 brine 6790' 3 -1/2' Liner 9.2 #,L- 80,Butt 2.992" 6659' 8320' 372 CBL ��° ' " —'- , 2696' 9 -5/8" ;o,s 4 , & k Tubing: 3 -1/2" Production 9.2 #, L -80 2.992" 39.00' 6685' Completion Jewelry Detail # Depth Length ID OD Item 1 39' Kvaerner Hanger (AB TC -45 DWN X STD VAM Up) 2 40' 2.992 3.500 3 -1/2" 9.2# L80Tubing 3 301' 2.35 2.813 3.500 HES XXO Safety Valve Landing Nipple 2696' BOT HC -ZXP Liner Top Packer & HMC Liner Hanger 4 6584' 0.78 2.992 3.920 X -Over, 3 -1/2" x CS -Hyd 5 6585' 4.30 2.813 4.550 HES XU Dura sleeve Tbg Punch 6 6624' 5.19 2.885 5.980 HES 3 -1/2 x 7" PHL Retrievable Packer 6569'-6575' 7 6672' 3.000 4.125 BOT 80 -40 Seal Bore Extension (14.5') 10/22/10 .__.. _. x° 4 6659' BOT Hydroflow III 3 -1/2" Liner Top Packer HES PHL 5 x" — _. _..... ..... Retrievable BOT High Flow 7" x 3 -1/2" Liner Hanger w /tie -back Pkr 6666' 6624' g sleeve. 3- 1/2LTP f 7 Liner Hanger 8 6688' 1.38 2.813" 3.950 HESX - Nipple 6659' sleeve tie-back ve - .... -.... sleeve I P 8 66� 10/22/10: Tubing punch 23 shots, 1- 11/16" x 6' perf gun, from 6569 — 6575' RKB. Well kill w /9.8 ppg KW brine. L 10/3/10: Tag Pkr at 7226' RKB w/2.73" GR. ;A/# ToC CBL 2005: Shallow leak in 13 -3/8" casing allows communication to the 32" conductor. 6789' .,*.ti 6790' _....._. r 1," 2005: Tubing tested to 2170 for 35 min (good), 9 -5/8" tested to 1500 psi for 15 min (good w/ no change in 13- 3/8" pressure), then increased pressure on 9 -5/8" to 2000 psi for 40 min (good). No change on 13 -3/8 ". HES EZ Drill SV ' Squeeze Pia @ Ghost hole 1997: Severe loss zone 6300' — 6700' MD, losses while running casing and no returns while cementing. 7226 w/3.5 "liner — 6864' -9476' HES ELITE Perfs Magna range BP ,,;....--..—.._ 7266 - 7440' FISH: @ 7375' push o Perforation oratiDn Data pushed 7767 ' & & 779 o 7784 Perfs Doglegs MD TVD 8070' -8160' 9 538' 7268 - 7344 4238 -4277 4 HPF Isolated by Packer at 7226' KB Ghost hole 3 -1 / 2 " w/3.5" liner 4.53 832' 7396 -7440 4301 -4327 4 HPF Isolated by Packer at 7226' KB 8326' d ; S . 9196' -9274' 7.56 1067' 8070 -8180 4639 -4696 4 HPF Isolated by Packer at 7226' KB PBTD =8250' TD =8330' 10 MAX HOLE ANGLE = 62.10 @ 2,226' MD 1 1,657' TVD 6.06 1275' 8170 -8180 4691 -4696 HPF Isolated by Packer at 7226' KB 6.60 1571' 6.45 6823' Updated by: J LL 03/26/13 • • 0 • Baker Platform Ba -32 PROPOSED N Middle Ground Shoal Last Completed: 06/30/1998 Gas Well Hilcorp Alaska, LLC RKB: MSL = 118' 7udline 220' Water Depth= 102' KB: MSL ADL: 17595 32 PTD 196 - 056 1 2 Mean Sea Level Leg 4, Slot 8 API: 50- 733 - 20473 -00 7 ili■ Mud Line z Size Type Wt/ Grade/ Conn ID Top Btm Cement CMT Top Sacks 32 " ...................._ Conductor......... .................... Surf 296' Driven 13 -3/8" 13 -3/8" Surface 68#,K- 55,BTC 12.415" Surf 792 795 Surf Top 792 24.8 Job 9 -5/8" Intermediate 47 #,L- 80,BTC 8.681" Surf 73' 53.5 #,P- 110,BTC 8.535" 73' 3015' 1136 2395' Calc 60.4° Liner 29 #,L- 80,TKC -BTC 6.184" 2996' 6789' 7" 955 None 60.7° Calc roc 3-1/2 .............................. Liner .................. ............... � ! 9.2# L -80 Butt ....................... 992" ........ .... 6659 ........................ 8320 ........................ 372 ...................... 6790' CBL...... ....................................... .............................._ .__................_._.._......... .........._......................................................................................................... ............................._. 2395' brine Tubing: 13K ' zxP 3 -1/2" Production 9.2 #, L -80 2.992" 39.00' 6685' ' ›.- LTP 2696' Completion Jewelry Detail 9 -5/8" 3015 4 N # Depth Length ID OD Item 1 39' Kvaerner Hanger (AB TC -45 DWN X STD VAM Up) 2 40' 2.992 3.500 3 -1/2" 9.2# L80 Tubing 3 301' 2.35 2.813 3.500 HES XXO Safety Valve Landing Nipple 2696' BOT HC -ZXP Liner Top Packer & HMC Liner Hanger 4 6584' 0.78 2.992 3.920 X -Over, 3 -1/2" x CS -Hyd 5 6585' 4.30 2.813 4.550 HES XU Dura sleeve 6 6624' 5.19 2.885 5.980 HES 3 -1/2 x 7" PHL Retrievable Packer 7 6672' 3.000 4.125 BOT 80 -40 Seal Bore Extension (14.5') 6659' BOT Hydroflow III 3 -1/2" Liner Top Packer Install tubing ✓ BOT High Flow 7" x 3 -1/2" Liner Hanger w /tie -back patch 6666' _ sleeve. 6569'-6575' _... Tbg Punch 8 6688' 1.38 2.813" 3.950 HES X -Nl le _: 6569' -6575' nr 4 10/22/10 HES PHL 5 ,_, 10/22/10: Tubing punch 23 shots, 1- 11/16" x 6' pert gun, from 6569 – 6575' RKB. Well kill w/9.8 ppg KW brine. Relievable 10/3/10: Tag Pkr at 7226' RKB w /2.73" GR. • 6624' ...Mil 2005: Shallow leak in 13 -3/8" casing allows communication to the 32" conductor. 7 2005: Tubing tested to 2170 for 35 min (good), 9 -5/8" tested to 1500 psi for 15 min (good w/ no change in 13 -3/8" LTP 3-1/2 6659' ,/ rJ 03,74 w /tie bac pressure), then increased pressure on 9 -5/8" to 2000 psi for 40 min (good). No change on 13 -3/8 ". 1111 , 6666e 1997: Severe loss zone 6300' – 6700' MD, losses while running casing and no returns while cementing. s 6 Q ooze 6. 7" 1 7,# TOCCBL FISH: 6789' + " 6790' 1. ° Perfs ±6900 -±6930 '/ Perforation Data ::-ae Pens ±7053-±7062 HES EZ Onosv T Doglegs MD TVD Squeeze Pkr ' ' Ghost hole 7226 ��rr ' 9.87°- 538' ±6900- ±6930 ±4033- ±4049 Future � " ' w/ 3.6 ° liner i ,, " 6864' -9478' 4.532 832' ±7053 - ±7062 ±4118 - ±4123 Future HES ELITE 1 i P ens Magna range BP ' 7268' - 7440' 7375 +�' ; ....-..-y. 7.569 1067' 7268 -7344 4238 -4277 HPF Isolated by Packer at 7226' KB pushed to ' 6.06 127 7396 -7440 4301 -4327 HPF Isolated by Packer at 7226' KB 7767' 8 7794 4 Perfs -....-,-, 8070' -818 6.60° 1571' 8070 -8180 4639 -4696 HPF Isolated by Packer at 7226' KB ---6—, 3 1 /2" ., Ghost hole 8320' -. - _ . . 8 1 6 . 2 7r 81886' -8274' 10 6.450 6823' 8170-8180 4691 -4696 HPF Isolated by Packer at 7226' KB PIBTD =8250' TD = 8330' MAX HOLE ANGLE = 62.10 @ 2,226' MD / 1,657' TVD , Updated by: JLL04 /01/13 IOW - IV' IP it; u i _ ____ NI e . • 1 47-c al ).)-)3 INA 1)1 11\ .., i: ,„ .1. ---) 7 OG '0006 81") - ' . 8 l .Or',, - O Jk 5 c • 7 G 0 i 9000 -- -- --; ?: 8000. 6000 . 1, IM R A Q STATE OF ALASKA ALASKIIIIIL AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U Other U Cancel Procedure Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 196 -056 • 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: • 50- 733 - 20473 -00 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017595 [Baker Platform] MGS ST 17595 32 r. 9. Field /Pool(s): Middle Groun Shoal Field/ Undefined Gas Pool 10. Present Well Condition Summary: Total Depth measured 8,330 feet Plugs measured 7,226 feet true vertical 4,769 feet Junk measured N/A feet Effective Depth measured 7,226 feet Packer measured 6,624 feet true vertical 4,215 feet true vertical 3,895 feet Casing Length Size MD TVD Burst Collapse Structural 296' 32" 296' 296' Conductor Surface 792' 13 -3/8" 792' 771' 3,450 psi 1,950 psi Intermediate 3,015' 9 -5/8" 3,015' 2,051' 5,750 psi 3,090 psi Production 3,793' 7" 6,789' 3,974' 8,160 psi 7,072 psi Liner 1,661' 3 -1/2" 8,320' 4,764' 9,685' psi 7,835 psi Perforation depth Measured depth 7,268'- 7,344', 7,396- 7,440', 8,070' - 8,180' Feet 5 V I IMED FEB * 6 2012 True Vertical depth 4,238'- 4,277', 4,301'- 4,327', 4,639'- 4,682' Feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.2 #/ L -80 _ 6.685' MD 3,965' 6,624' MD Packers and SSSV (type, measured and true vertical depth) HES PHL Ret PKR 3,895' TVD R EG P1 VE D N/A 11. Stimulation or cement squeeze summary: N/A JAN 2 7 2012 Intervals treated (measured): N/A i Treatment descriptions including volumes used and final pressure: N/A : ,A li -. ", :' & G C, ©ns. Commission Aicrinrngp 12. Representative Daily Average Production or.Injection.Data _ Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 125 psi 160 psi Subsequent to operation: 0 0 0 0 psi 0 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations Y 15. Well Status after work: Oil ❑ - Gas El WDSPL Li GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -296 Contact Hilcorp Drilling Dept. at 777 -8301 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature "� _ . - Phone 276 -7600 Date 1/25/2012 4 Form 10-404 Revised 10/2010 RSDMS JAN 2 7 2012 •„ ,,00,y Submit Original Only e Cook Inlet Basin, Alaska Offsh • Baker Platform Ba -32 Middle Ground Shoal N Middle Ground Shoal Last Completed: 06/30/1998 Gas Well RKB: MSL = 118' Mudline= 220' Water Depth= 102' ::..,. :: : KB: M ADL: 17595 32 PTD: 196 -056 - Mudn Sea Level Leg 4, Slot 8 API: 50- 733 - 20473 -00 Mud Line Current Schematic ii. --.. : 32" i::. l :: ., Size Top Btm Cement CMT Conn ID o Type Wt/ Grade/ o P Yp _ Top o Sacks P d - Driven - Surf 296' ;:::. 32" Conductor 792 13 - 3/8 " Surface 68# 55 12.415 Surf 792 795 Surf 792 i 24.8° Top Job _....:.::::.: 9 -5/8 Intermediate 47 #,L- 80,BTC 8.681" Surf 73' .............. :: 3:: : :: :::::::::::::::::::::::%::, _ ........................_.._....... ..........................._... 53.5# P 110 C 2395' BT 8.535" 73' 3015 1136 Calc 60.4° _ 6789' >f 7" Liner 29 #,L- 80,TKC -BTC 6.184" 2996' ° 955 None 60.7 95 ppg .. 3 -1/2' Liner 9.2#,L- 80,Butt 2.992 6659' 8320' 372 CBL zxP ' ><:11:i:::::::: III.- .". LIP Tubing: # 2696' 9 -518.. ti : :... .::.: :. ,'. 30,5 d 3 -1/2" Production 9.2 #, L -80 2.992" 39.00' 6685' Completion Jewelry Detail a; # Depth Length ID OD Item i 343LF 1 39.00' Kvaerner Hanger (AB TC -4S DWN X STD VAM Up)_ 2 40.00' 2.992 3.500 3 -1/2" 9.2# L80 Tubing >: -: 3 301' 2.35 2.813 3.500 HES XXO Safety Valve Landing Nipple 2696' BOT HC -ZXP Liner Top Packer & HMC Liner Hanger 4 6584' 0.78 2.992 3.920 X -Over, 3 -1/2" x CS -Hyd 5 6585' 4.30 2.813 4.550 HES XU Dura sleeve - :F'i; 6 6624' 5.19 2.885 5.980 HES 3 -1/2 x 7" PHL Retrievable Packer f ``'' 7 6672' 3.000 4.125 BOT 80 -40 Seal Bore Extension (14.5') -, F i i ii Tb - -- - 3 :0 :i 6569.6575' 6659' BOT Hydroflow III 3 -1/2" Liner Top Packer 1F F 1022/10 _ -- - — ±•: s ' 6666' BOT High Flo 7 x 3 -1/2" Liner Hanger /tie -back HES PHL -:. b: m :..i sleeve. Retrievable :.>!.:.: 6 8 6688' 1.38 2 813" 3.950 HES X- Nipple 7 Liner Hanger -_ -- - - -_ -.. .._ - -_ . 3-1/2 LTP ��_C. w,te back 1 0/22/10: Tubing punch 23 shots, 1- 11/16" x 6' perf gun, from 6569 - 6575' RKB. Well kill w/9.8 ppg KW brine. +] sleeve 8 4 I 6666' 10/3/10: Tag Pkr at 7226' RKB w/2.73" GR. _ 2005: Shallow leak in 13 -3/8" casing allows communication to the 32" conductor. L _ 2005: Tubing tested to 2170 for 35 min (good), 9 -5/8" tested to 1500 psi for 15 min (good w/ no change in 13 67 9' - •.' 6 °o 3/8" pressure), then increased pressure on 9 -5/8" to 2000 psi for 40 min (good). No change on 13 -3/8 ". _ • 1997: Severe Toss zone 6300' - 6700' MD, losses while running casing and no returns while cementing. HES EZ Drill SV ' Ghost hole Squeeze Pkr @ 7226 ` w/3.5• liner FISH: .� 6864' -9478' HES ELITE Perfs Perforation Data Magna range BP • . _A._ e'7268' -7440' @7375 Doglegs MD TVD Junk Pkrs 9.87 538 7268 - 7344 4238 -4277 4 HPF Isolated by Packer at 7226' KB 7767'8, 7794 4.53 832 7396 -7440 4301 -4327 4 HPF Isolated by Packer at 7226' KB Pef . 8070' -8180' 7.56 1067 8070 -8180 4639 -4682 4 HPF Isolated by Packer at 7226' KB Ghost hole 8-1'2" WI' .5.hner 6.06 1275 8170 -8180 10 HPF Isolated by Packer at 7226' KB 8320' 4. , - 8186' -8274• 6.60 1571 PBTD =8250' TD = 8330' 6.45 6823 MAX HOLE ANGLE = 62.10 @ 2,226' MD / 1,657' TVD WBD Ba -32 Dec2010.docx Page 1 of 1 JRN 4 -2009 & ARD 12/2010 Chevron • • 11 00 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) Ba -32 MGS ST 17595 32 ADL0017595 5073320473 BR8294 Date .. Primary Job Type Job Category Objective Actual Start Date Actual End Date Well Preparation Well 10/2/2010 10/3/2010 Services Primary Wellbore Affected Wellbore UWI Well Permit Number Ba -32 507332047300 1960560 10/2/2010 00:00 - 10/3/2010 00:00 Operations Summary R/U slickline and pressure test lubricator to 250 psi low/ 2500 psi high. RIH with 2.73" GR to 7,226' RKB. RIH with 3.5" BO shifting tool to XU sleeve at 6,585' RKB - open sleeve. R/D slickline. 10/2112010 00:00 - 10/22/2010 00:00 Operations Summary R/U on Ba -32. Unable to pump. Appears that sleeve did not open. R/D. 10/22/2010 00:00.10123/2010 00:00 Operations Summary R/U eline and pressure test lubricator to 250 psi low/ 3000 psi high. RIH with 1- 11/16" x 6' tubing punch gun and shoot 23 holes from 6569' - 6575'. POOH, all shots fired. R/D eline unit. 10/23/2010 00:00 - 10/24/2010 00:00 Operations Summary Pressure test lines to 500 psi low and 2000 psi high. Pump 9.8 bbp KWF at 2 bpm /1300 psi down tubing taking returns up 9 5/8" annulus holding BHP constant. Pumped 336 bbls total until 9.8 ppg KWF back to surface. Bleed off tubing and casing. Well Dead. 10/26/2010 00:00 - 10127/2010 00:00 Operations Summary R/U on Ba -32. Pressure test lines to 500 psi low and 2000 psi high. Pump 10.5 bbls diesel at 1 bpm down tubing and up 9 5/8" annulus. Pump 20 bbls 9.8 KWF, 25 bbls LCM pill, 32 bbls 9.8 ppg KWF, 1.5 bbls diesel, chased with 2 bbls KWF. Had good returns throughout. Bleed off all pressure and Shut in well. R/D. 2011 July's Baker/Dillon Production Well Report Page 1 of 1 • Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, August 08, 2011 3:42 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Cole, David A; Ross, Gary D; Tyler, Steve L; Quick, Mike [ASRC] Subject: 2011 July's Baker /Dillon Production Well Report Attachments: Master Well List TIO Report 2011 08 01.xls Hi Tom &Jim, ` — OS � Here is July's monthly report for the Baker and Dillon monitored production wells. The Ba -25RD continues to show some increasing pressures in one tubing string and the inner casing. The Ba -5 & 11 wells are still showing slowly climbing pressures (one tubing string on Ba -5 and one tubing and the inner casing on Ba -11). The general pattern of stable or slowly rising pressure trends continued this month. Besides the wells mentioned above, the only other pressure anomaly relates to the seasonal trend in pressures apparent in Di -6 & Ba -32 (before it was killed). Larry «Master Well List TIO Report 2011 08 01.xis» 8/9/2011 Plolessure & Rate vs Time - Well Ba -32 200 180 '''•••"9 5/8" 13 3/8" - 160 - •Tubing 140 120 3 N 100 v o. 80 60 40 20 CI) CI) rn rn 0 rn 0 0 0 0 rn rn O O O O O O O O O O O O O O O O O O O O O O o O N O O O aD 2.`', ' n O O n O O O n a M M N N O N O O M O O O M M M N N N N N N N N N N N N N N N N N N N N N N N M 8 LL� O O r O 8 O N N M '8 O O 8 8 m O N N M 8 8 O r O O O O O O O O O � O O O O O O O O O � O O O O O O O Date 13 3/8" TIO Report 07/19/11 06/22/11 0 Data Sheet 06/01/11 0 05/28/11 0 05/26/11 0 Ba -32 05/25/11 0 05/24/11 0 05/23/11 0 FLOWING 05/22/11 0 05/21/11 0 05/04/11 0 Permit # 1960560 04/01/11 0 02/03/11 0 01/20/11 0 0 0 API # 50- 733 - 20473 -00 12/17/10 0 0 0 11/09/10 0 0 0 10/31 /10 0 0 0 01/31/2009 to 08/01 /2011 10/30/10 0 0 0 10/29/10 0 0 0 10/28/10 0 0 0 10/27/10 0 0 0 10/26/10 0 0 0 10/25/10 0 0 0 10/24/10 0 0 10/23/10 0 10/22/10 0 10/20/10 100 10 10/19/10 125 10 10/18/10 125 10 10/17/10 125 10 10/16/10 125 10 10/15/10 125 10 10/14/10 125 10 10/13/10 125 20 10/12/10 125 10 0 10/10/10 100 10 0 8/9/2011 2:37 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 08 01.xIs Ba -32 RECE' , STATE OF ALASKA 'IVED ALA_OIL AND GAS CONSERVATION COM.ION OCT 1 9 2005 REPORT OF SUNDRY WELL OPERA TIONSA1 k O" fl. G C C .. as a I \X as 008. ommlSSlÖÔ 1 . Operations Abandon Repair Well Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations ../ Perforate New Pool 0 Perforate 0 4. Current Well Class: Development 0 Stratigraphic 0 Stimulate Other WaiverO Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: ExploratoryD'196-Ô56 ServiceO 6. API Number: 50-733-20473-00 9. Well Name and Number: MGS ST 17595; Baker 32 10. Field/Pool(s): Middle Ground Shoal 7. KB Elevation (ft): 118' above MSL 8. Property Designation: Baker Platform/Cook Inlet 11. Present Well Condition Summary: Total Depth measured 9,064' feet true vertical 5,121' feet Effective Depth measured 8,240' feet true vertical 4,725' feet Casing Length Size Structu ral Conductor 296' 32" Surface 792' 13-3/8" Intermediate 3015' 9-5/8" Production 4093 7" Liner 1661 3-1/2" Plugs (measured) Bridge Plug at 7,226' Junk (measured) MD TVD Burst 296' 296' n/a 792' 771' 3,450 psi 3,015' 2,052' 5,750 psi 2,696'-6,789' 1,891'-3,974' 8,160 psi 6,659'-8,320' 3,912'-4,764' 10,160 psi Collapse n/a 1 ,950 psi 3,090 psi 7,020 psi 10,530 psi Perforation depth: Measured depth: 7,268'-8,180' fjÇ/\NNED NOV (1 ~~ 2001 . True Vertical depth: 4,238'-4,696' Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 (â) 6.685' Packers and SSSV (type and measured depth) Halliburton PHL Retrievable packer @ 6,624'; HES XXO SV landing nipple @ 301' 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 ~O o 0 50 15. Well Class after proposed work: ExploratoryO Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl o o Tubing Pressure 800 75 Service 0 x GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: 305-279 Contact J Gary Eller 263-7848 Printed Name Timothy C. Brandenburg Signature Title Drilling Manager ORIGtNAL, Date I D- /7-0,") Phone 907-276-7600 RKB =56' Rig Floor to Wellhead Kvaerner SMS Wellhead PDTD = 8,240' MAX HOLE ANGLE = 60° @ 1,515' B-32 Actual Wellbore Schematic 10-14-05 32" Inside Conductor 296 13-3/8 68 K-55 BTC 792 Note: 13-3/8" has shallow breach (9/17/05) 9-5/8 47 L-80 BTC 73 9-5/8 53.5 P-IlO BTC 73 3,015 7" 29 L-80 TKC-BTC 2,696 6,789 3-1/2 9.2 L-80 Buttress 6,659 8,320 1 K vaerner Tubing Hanger (AB TC-4S DWN X STD V AM Up) 39 2 3 4 5 6 7 8 9 10 11 TOP 7268 7396 8170 8070 3-1/2' TC-42 x Buttress Crossover 40' HES XXO Safety Valve Landing Nipple (ID = 2.813") 301' Baker Oil Tools HC-ZXP Liner Top Packer & 9-5/8" X 7" HMC liner Hanger 2,696 3-1/2" Buttress X CS-Hydril Crossover 6,584 RES XU DURASLEEVE (ID = 2.813") 6,585' HES 3-1/2" X 7" PHL Retrievable Packer 6,624' BOT Hyflo ill Liner Top Packer, BOT High Flow 7" x Liner Hanger with Tie-back sleeve, BOT 80-40 Seal Bore Extension (Length = 14.5'), HES X-Nipple (ID = 2,813") Halliburton EZSV set 9/21/05 6,650' 6,666' 6,672' 6,688' 7,226' BTM 7344 7440 8180 8180 PERFORATION DATA ZONE SPF DATE COMMENTS 4 6/22/98 Plugged 4 12/10/97 Plugged 4 8/21/97 Plugged 4 11/26/97 Plugged REVISED: 10114/05 DRAWN BY: JWS e Well Ba-32 Operations Summary Baker Platform October 14, 2005 e 9/17/05 Planned Freeze Protect of 13%" by 9%" annulus. Starting Pressures: Tubing = 800 psi; 9%" = 240 psi; 13%" = 0 psi (static). RU to freeze protect 13%" by 9%". Pumped 2 bbl down 13%" by 9%" with test pump did not see any pressure build. Started getting returns on the 13%" by 32" open conductor. Shut down and secured operations. 9/18/05 Worked to skim freeze protect fluid out of conductor. Pumped fluid from 32" by 13%". Continued until we had only water back. Indications are that there is a very shallow leak in the 13%" casing. Tubing = 800 psi; 9%" = 240 psi; 13%" = 0 psi; 9/21/05 RU slickline and PT to 500 psig low and 2250 psig high (good test). Attempt to RIH and found one section of lubricator would not drift. LD one section of lubricator. PU 2.81" gauge ring. RIH and tag SSSV at 301' RKB. POOH. RIH with 3.5" GS and Prong. PuIl3%" BXE SSSV. POOH. RIH with 2.75" X 3' dummy plug to 6,680' RKB. Change over tool string, add KJ above dummy. Made it down hole to 7,280' RKB. POOH. PJSM and LD slickline. Spot and RU e-line. PJSM. Arm Halliburton 2%" shorty setting tool. Pressure test lubricator to 500 psi low and 2,500 psi high (good test). RIH with 3%" Halliburton EZ Drill SV squeeze packer. Tie in CCL on way in hole to 7,520'. Pull up hole to set packer in middle of joint at 7,226' e-line. (Note: This is 42' above Top perf). Set Packer seeing good indication of weight loss over 5 minutes, pick up above packer and set back down on packer. POOH. LD e-line. Hook up high pressure hose and blow down well pressure to atmosphere. Close in well and monitor no build up (good negative test). Load well with seawater and pressure test to 2,100 psig for one hour. Final pressure after one hour 2,050 psig (good positive test). During test 9%" production casing pressure increase 5 psi. RD. 9/23/05 SIMOPs and PTSM. Pressure tested tubing to 2,170 psig for 35 minutes and charted with final pressure of 2,160 psig (good test.) Bleed off tubing and pressure tested 9%" to 1,500 psig and held for fifteen minutes watching 13%". Everything looking good. Took pressure up to 2,000 psig and held for 40 minutes and final pressure was 1,990 psig (good test). Bleed 9%" casing off. 9/24/05 SIMOPs and PTSM. RU on BA-32 with 3Y:z" BO shifting tool. Pressure test lubricator to 250 low and 500 psig high. RIH with 3Y:z" BO shifting tool and locate XU Sleeve at 6,585' RKB. POOH and find tool sheared which is indication that sleeve not all the way open. We do have 150 psig tubing pressure indicating that sleeve is part way open. Equalize tubing and casing on surface manifold with final pressure of 40 psig on both sides. Bleed both off to atmosphere and monitor until no returns. Circulate raw water across top. Close in tubing side and pump down annulus to 1,000 psig bundle test with seawater to 1,000 psig on both sides (held good test). Bleed pressure off both sides and monitor until no returns again. Line up with diesel and pump 13 bbl diesel down 9%" while taking returns up tubing. Equalize on surface again. Isolate strings and bull head 2 bbl diesel down tubing (at which point both strings were 1,000 psig again) monitor bundle test again with pressure holding and wait. Slowly bleed small gas cap with very little diesel off gs/a" casing until both strings bleed off. RIH with BO shifting tool and locate sleeve at 6,585' RKB. Jar down on sleeve for half hour prior to passing through. POOH. LD Pollard wireline. Pressures on well BA-32 as of 9/25/05 are as follows: tubing 70 psig, 9%" casing 50 psig, and 13%" casing 0 psig. 10/1/05 Tubing 75 psig, 9%" casing 50 psig and 13%" casing 0 psig. Ba-32 morning report summary, CONFIDENTIAL: last revised 10/14/2005, Page 1. ) ) Chevron . Timothy C Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com October 10, 2005 Commissioner John Norman Alaska Oil & Gas Conservation Commission 333 W. th Avenue Anchorage, Alaska 99501 Re: Baker Platform Pilot Pre-Abandonment Work Summary ~ t) l\JQ~l:;j:,ti:CJ \C~) ~G~ ~~~'v;~ Dear Commissioner Norman, jOb-D5(p @It/ 2> 'Y This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of Unocal's pilot pre-abandonment work on the Baker Platform in Cook Inlet, Alaska. On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platform to develop a safe, cost effective, and optimal method for the abandonment of multiple well bores. As noted in the letter of October 22, 2004, Unocal has operated the Baker and Dillon Platforms under a "lighthouse" mode where all oil and gas production has been shut-in. The Dillon Platform was shut-in December 2002 and the Baker Platform was shut-in August 2003. Unocal commenced the pilot study with a diagnostic program on five water injection wells and three oil wells on the Baker Platform in July 2005. The diagnostic program consisted of pressure and temperature surveys for baseline data, mechanical integrity of the completion, injectivity tests to the formation, and pressure measurement on the outer casing annuli. The injection wells initially surveyed were Baker 7, 8rd, 12, 15rd, and 27. The oil wells surveyed were Baker 13, 28, and 30. Unocal did not anticipate that any of the oil wells on the Baker platform would have a bottom hole pressure (BlIP) gradient exceeding seawater. However, when it was discovered that Baker well 28 had a static BlIP of9.0 ppg, the diagnostic program was expanded to include all of the oil wells and water injection wells on the Baker Platform as well as six wells on the Dillon Platform. The Baker water injection wells have mostly held their residual pressure since being shut-in. Their BHP gradients range from 5.8 to 9.4 ppg. Three oil wells on the Baker platform have BHP gradients that exceed a seawater gradient. Two additional wells have pressures that exceed an oil gradient but are below a seawater gradient. Under the right conditions, these wells could be capable of unassisted flow. The Baker Platform Well BlIP Summary is attached. The Dillon well BHPs are all below a seawater gradient of 8.4 ppg. No additional diagnostic well work on the Dillon platform has been initiated. ~UP\JCATE Union Oil Company of California I A Chevron Company http://www.chevron.com ) ) Commissioner John Norman Alaska Oil & Gas Conservation Commission October 10, 2005 Page 2 No temperature anomalies were noted on the Baker platform with the exception of Baker well 28. Baker 28 exhibited a temperature anomaly at approximately 5,000 feet MD, as noted on the attached Baker Composite Temperature Chart. An assessment of Baker 28 is attached with the recommendation of no remedial activity. Chevron intends to conduct annual temperature/pressure surveys on Baker 28 to monitor the well status. There were no temperature anomalies noted on the Dillon platform wells. The pilot abandonment program commenced with plugging perforations on the water injection wells initially identified (i.e. Baker wells 7, 8rd, 12, 15rd, and 27). The plugging of the perforations received Sundry approval and the integrity testing of the cement plugs was witnessed by an AOGCC representative. In addition, perforations were plugged in the water supply well Baker 501 and in the gas well Baker 32. In light of the Chevron Corporation acquisition ofUnocal, the well plugging operations for the oil wells on the Baker platform has been omitted from the 2005 pilot program to allow time to reassess economic potential under Chevron's criteria. Furthermore, the gas potential from the Baker is also being re-assessed. To better prepare for the winter, Chevron will be applying heat on both the Baker and Dillon platforms. In addition, the wells capable of receiving a freeze protect fluid in their respective annuli will be freeze protected. If you have any questions or concerns, please contact me at 907-263-7657. Sincerely, ~ ~-éê- ,2 ~ C--~ /~ ~ ¿::;Í Timothy C. Brandenburg Drilling Manager Attachments Cc: Dale Haines Gary Eller Union Oil Company of California I A Chevron Company http://www.chevron.com Baker Platform Well BHP Summary Last Updated: October 7,2005 Pressure Survey Measured Gradient Equivalent Mud Well Well Type Date MD (ft) TVD (ft) BHP (psia) (psi/ft) Weight (ppg) Notes Ba-4 Injector 27-Jul-05 7850 7843 3141 0.400 7.7 Ba-5 Producer 30-Jul-05 6284 5566 2753 0.495 9.5 Ba-6 Producer 20-Jul-05 5712 5709 2811 0.492 9.5 Ba-7 Injector 7-Jul-05 6244 5630 2712 0.482 9.3 Ba-8rd Injector 7-Jul-05 7100 6937 3288 0.474 9.1 Ba-9rd2 Injector Perfs cemented, no survey planned -' Ba-11 Producer 21-Jul-05 8379 8113 3273 0.403 7.8 Ba-12s Inject()r 6..Jul~05 Ba-121 Injector 16-Jul-05 7121 6106 2941 0.482 9.3 Ba-13 Producer 6-Jul-05 7916 7661 3236 0.422 8.1 Ba-14 Gas No survey Ba-15rd Injector 5-Jul-05 6480 6286 3050 0.485 9.3 Ba-16 Injector No survey Ba -1 7 Injector No survey Ba-18 Gas No survey Ba-20 Producer 28-Jul-05 4134 4030 1242 0.308 5.9 Obstruction in tubing at 4139' Ba-23 Injector 23-Jul-05 8841 8499 2584 0.304 5.8 Ba-25rd Producer 22-Jul-05 9495 9033 3208 0.355 6.8 Ba-27 Injector 6-Jul-05 7779 5999 2928 0.488 9.4 Ba-28 Producer 3-Jul-05 8441 5308 2497 0.470 9.0 Ba-29 Producer 28-Jul-05 7923 7594 2165 0.285 5.5 Ba-30 Producer 4-Jul-05 10966 9109 3593 0.394 7.6 - Ba-31 Producer 29-Jul-05 11433 10636 3795 0.357 6.9 --¿Ba-32 Producer No survey (~c,)\ ~~..I""'"" , l't"';~ r.?, : \¡)' . i iß:"\ : 'I :/ ,'\ : i í II, \ ¡: i l'_J ,.;.\ '~; :: "" J 'J\ 'U". ¡ :[' I ,1 ,))\ '. '~F'I, 'I' I \,;=-} ~ J..J ;! !" t....=fJ ) ¡(r,m" UJ'l']! \1,: I,u.,· ~ , I I I : ' 'i,~''!..,' .,: : i ) /r,;'\~ :-¡ J ,'1', ; I Ii r \ : ',' ¡ w',\ : : ii:ï1 \ ; : ¡u i¡j L.:=J¡ ß/,l:~l , ~~' \\ / ~ \ \ .: ;rï " iW' WI I / ,f FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy C. Brandenburg Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 : C\'~(~ " Re: Middle Ground Shoal ST 1 7595; Baker-32 Sundry Number: 305-279 ;t~CJ¡Ü~~ß:;t) ~:~, 1 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, OJ4f~fr John K. Norman Chairman DATED this2-l~ay of September, 2005 Encl. " STATE OF ALASKA ) AlAv.,à Oil AND GAS CONSERVATION COMMlù610N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil Company of California 1. Type of Request: Suspend U Repair well 0 Pull Tubing 0 3. Address: PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 118' above MSL 8. Property Designation: Baker Platform, Cook Inlet 11. Total Depth MD (ft): 9064 Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 7268'-8180' Packers and SSSV Type: Development Stratigraphic Perforate U Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Dril~Number: Exploratory 0 1960560 \,~ o 6. API Number: 50-733-20473-00 ~/ o o Service 9. Well Name and Number: MGS ST 17595; Baker-32 10. Field/Pools(s): Middle Ground Shoal PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 5121 Effective Depth MD (ft): 8240 Effective Depth TVD (ft): 4725 Plugs (measured): Length Size 296' 32" 792' 13-3/8" 3015' 9-5/8" 4093 7" 1661 3-1/2" Perforation Depth TVD (ft): 4238'-4696' Halliburton PHL Retrievable packer HES XXO SV landing nipple 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 9/21 /2005 Date: MD 296' 792' 3015' 2696'-6789' 6659'-8320' Tubing Size: 3-1/2" TVD 296' 771' 2052' 1891'-3974' 3912'-4764' Tubing Grade: 9.2#, L-80 Packers and SSSV MD (ft): ~, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Timothy C. Brandenburg Title Drilling Manager / '''-&--:--~ C~ VPhone 907-276-7600 Date ~ /~/;/ COMMISSION USE ONLY ~ Signature Other U Junk (measured): Burst Collapse n/a n/a 3450 psi 1950 psi 5750 psi 3090 psi 8160 psi 7020 psi 10160 psi 10530 psi Tubing MD (ft): 6685' packer - 6624' SCSSV - 301' 13. Well Class after proposed work: Exploratory 0 Development 0 Service 0 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Other: ro? ~'dCJf\~~dS..)~.. Subsequent Form Required: \i C) "'-\ Approved by: ~ ¡J~ Contact Gary Eller: 263-7848 <7 ~ 20-v..s- Sundry Number: ðJfS ... ól-¡t?j Location Clearance 0 \.JI:)\,\~ "k-~~~--~'~ ~rS<::" , RBOMS BFL SfP 2. 1 2005 (~.¡ r-)Cprr'~ISS'\~rE!\" L \.. \ \ \ l..! t l '\ K APPROVED BY THE COMMISSION Form 10-403 Revised 11/2004 Date: 9 - 2/- ð:.s- Submit in Duplicate ') ) Well Ba-32, Middle Ground Shoals Unit Plugging Procedure AFE Recent Well History: In August 2005, a freeze protection treatment was attempted on the 130/8" surface casing of well Ba-32. The foreman noted returns on the 32" conductor immediately upon pumping the freeze protect fluid into the 13%" x 9%" annulus. The 9Y8" casing and the 3~" tubing both appear to have pressure integrity. There apparently exists a shallow breach in the 13%" surface casing of well Ba-32. Objectives: Isolate the perforations in well Ba-32 to minimize opportunity for hydrocarbons to escape out the breach in the 130/8" casing. Procedure: 1. MIRV electric line on Ba-32. Pressure test lubricator and conduct pre-job safety meeting. RIH with a gauge ring for 3~", 9.2 ppftubing to a depth of ±7270'. V se roller stem as needed due to hole deviation. POOH. PV a Halliburton composite bridge plug for 3~", 9.3 ppftubing. RIH, tie in with CCL, and set composite bridge plug at ±7238' MD. POOH, RDMO e-line. æ:ote: The AOGCC plugging requirement is that the bridge plug be set within 50' of the top perf which is at 7268' MD.) 2. Bleed off all trapped pressure on the tubing string to negative test the plug. Load hole with seawater (required volume = 63 bbl). Pressure test bridge plug to 2000 psi. Give AOGCC rep opportunity to witness pressure test. Monitor pressure on 9Y8" casing during pressure test. Bleed off tubing pressure when finished. 3. Pressure test 9Y8" casing to 2000 psi using seawater. Monitor pressure on tubing and watch for flow from 13%" casing during pressure test. Bleed of casing pressure when finished. Communicate results of pressure test to Drilling Superintendent. B-32.doc September 19,2005 ) ) " ~~f~.~ :} !Æ~fÆ~~fÆ ATßASHA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK', GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ' FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 tl.'....',...J".'.". /..,'Ð~ 1V(" Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: This letter confirms your conversation with Commission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform. and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval"j because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmamied and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be ubmitted forthwith. ¡:, Siucere~~ :.A>. . No an Daniel T. Seamount, Jr. Ch . Commissioner BY ORDER OF THE COMMISSION DATED this 1:Zday of November, 2004 '...' -" C\ 2DUL\ é"oC-'f\~~NEL.j NO\] 2~ ¿) ~ r-.~~ Ene!. :; ,., ...-C Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil of California aka Unocal 1 . Type of Request: 3. Address: 909 West 9th Ave. Anchorage AK 99501 7. KB Elevation (ft): 118' RKB above MSL 8. Property Designation: BAKER 11. Total Depth MD (ft): Total Depth TVD (ft): 5,121' Length 9,064' Casing Structural Conductor Surface Intermediate 739' 4,093' Production Liner ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMlbSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: RECEIVED OCT 12 2004 Suspend U Repair well 0, Pull Tubing 0 Perforate U Alaska UtW&ifå3t]on».nhdJifrUI1_ru Stimulate 0 Time ExtensArn:lngrage Other 0 Re-enter Suspended Well 0 Monitor Frequency 5. Permit to Drill Number: Exploratory 0 1960560 ,- 0 6. API Numbey 50-733-2gø3-00 9. Well Name and Number: /. Ba-32 10. Field/Pools(s): Development Stratigraphic 0 0 Service Middle Ground Shoal PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 8,240' 4,725' Size I MD I / TVD Burst / 296' / 792' / 3,015' Junk (measured): Collapse 32" 296' 771' 2,052' 3,974' 3,450 psi 6,820 psi 8,160 psi 13-3/8" 9-5/8" 1,950 psi 4,750 psi 7,030 psi Date: Abandoned WDSPL 0 0 7" 4,764' Tubing Grade: Perforation Depth MD (ft): 7268 to 8180; Packers and SSSV Type: 1,661' 3 1/2" Perforation Depth TVD (ft): 4238 to 4696; HES XXO Safety value @ 301' HES PHL retrievable packer @ 6, 4' 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Tubing MD (ft): # L-80@6,685' Packers and SSSV MD (ft): 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 0 Service 0 0 0 Plugged WINJ Commission Representative: 17. I hereby certify that the foregoing is true and correct t Printed Namll ,/J~le. Signatur~//âL the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY 27 -Sep-2004 Conditions of approval: Notify Commission so tht representative may witness Plug Integrity 0 BOP Test 0 Sundry Number: L-30 If - 4=r) Mechanical Integrity Test 0 0 Location Clearance Other: RBDMS BFl NOV 2 2 2DD4 Subsequent Form Required: Approved by: ~..3 Form 1 O~evised 12/2003 OqIG1~LAL APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION COMMISSIONER BY ORDER OF THE COMMISSION Date: Submit in Duplicate ..... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C ,MMISSION WELL COMPLETION OR RECOMPLETION REPORT 'O6 1. Status of Well Classification of Service Well OIL: GAS: X SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Union Oil Company of California (Unocal) 96-056 3. Address 8. APl Number P.O. Box 196247 Anchorage, AK 99519 50- 733-20473-00 4. Location of well at surface ~~ /!--.~:.- __~- ~"?!! ~! 9. Unit or Lease Name 1987' FNL, 478' FWL, Sec. 31, T9N, R12W, SM ~i:ii"ii:j. ~ ~ !.~ i~!i'~ ~~~r. 17595 AtTop Producing Interval 8,022' MD ~ /p/!o~_~t ? ~ 10. Well Number 4084' FSL, 1525' FWL, Sec. 30, T9N, R12W, SMi .............~ ~--,~-,-~-~' ........ ;! Baker # 32 At Total Depth ~'.'.17~_ !- ' 11. Field and Pool 930' FNL, 1650' FWL, Sec. 30, T9N, R12W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Middle Ground Shoal Field 118' RKB above MSLI ADL 17595 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions I · 4/18/97 5/26/97 12/10/1997,/ 102' feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8330' MD/4761' TVD 8250' MD/4726' TVDI Yes: x No:I 316 feet MD N/A 22. Type Electric or Other Logs Run DIL, GR, CNL, FDC, Dipmeter, TDT, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 32" 53' 296' Driven 0 13-3/8" 68# K-55 53' 792' 17-1/2" 795 sx 0 9-5/8" 53.5# L-80 53' 3015' 12-1/4" ! 136 sx 0 7" 29# L-80 2996' 6789' 8-1/2" 955 sx 0 3-1/2" 9.2# L-80 6659' 8320' 6" 372 sx 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.2# L-80 6650' 6624' Measured 7,268' - 7,344'; 7,396' - 7,440'; 8,070' - 8,180' :26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. True Vertical 4,238' - 4,277'; 4,301' - 4,327'; 4,639' - 4,682' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED None The interval 8,170' - 8,180' has 10 HPF: all others have 4HPF. 27. PRODUCTION TEST Date First Production t Method of Operation (Flowing, gas lift, etc.) ~,) ~ \ i ~ I t '~ ~ % L-- I There was no production. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD => Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAM E Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and ~Jme of each phase. Tyonek "A" 9,005' 5,099' 31. LIST OF A-I-rACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed.. ,~ ~ ~"~\ f,~ Dale A. Haines Title Drilling Manager Date 4/20/98 ,, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injec§on, steam injection, air injection, salt water disposal, water supply for injeclJon, observation, injection for in-situ combustion. Item 5: Indicate which elevalJon is used as reference (where not otherwise shown) for depth measurements given in other space on this form and in any attachments. ,. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the preductin intervals for only the interval reported in item 27. Submit a separate form for each addi~onal interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevafion (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BAKER PLATFORM API# 50-733-20473-00 MGS. ST. 17595 # 32 WELL HISTORY Well Baker #32 DATE COMPLETED EVENT 1997 4/9-19 ARRIVE ON PLATFORM 4/9/97 WITH SKELETON CREW. BEGIN RIG 428 RIG ACTIVATION. TEST AND INSPECT RIG AND EQUIPMENT. FULL CREWS ARRIVED ON 4/11/97. SKID RIG TO SLOT #8. BEGIN PU RISER. COMPLETE ACTIVATION OF RIG 428. 4/18-26 Drill 12-1/4" hole to 810'. Open hole 17-1/2". RIH with 13-3/8" 68 lb/ft K-55. Pump cement job. ND riser and NU BOPE. RIH with 1-1/4" tubing and tag cement 63'. Pump top job mid bring cement to surface. Test BOP. Drill 12-1/4" hole to 3,028'. Run 9-5/8" 53.5 lb/ft L-80. Pump cement job. 4/27-30 Drill 8-1/2" hole to 6,364' WITH HYCALOG DS 75 PDC BIT. LOST CIRCULATION. MOVE PIPE WHILE SPOTTING 50 BBL LCM PILL REGAIN CIRCULATION. SHORT TRIP. RIH. DRILL FROM 6,364'-6,405' AND LOST ALL RETURNS. SPOT 20 PPB LCM PILL. PUT WELL ON TRIP TANK. MONITOR LOSSES WHILE WORKING PIPE. SPOT SECOND LCM PILL AND POOH TO 9-5/8" SHOE. HOLE LOSING @ 2.0 BPH FOR 4 HOURS. HOLE STOPPED LOSING FLUID. RIH TO 6,330' AND LOST RETURNS WHILE CIRCULATING. SPOT LCM PILL AND MONITOR WELL. 5/1-4 Drill 8-1/2" hole F/6,426'-6,470'. Losing returns. Drill ahead to 6,500' without MWD. Hole taking fluid 30-40 BBL/hr. POOH to shoe. Attempt to spot LCM. MWD and motor plugged off. POOH and LD BHA. RIH with OEDP to shoe. Gas migrated to surface. Shut-in well. Annulus = 125 psi DP = 0 psi. CBU on ~ open choke. Shut-in and annulus built to 420 psi and DP = 90 psi. Circulate gas out using drillers method. No pressure on DP or annulus. Open well--wellbubbling and Iossing fluid. RIH to 6,460'. Circ 9.2 PPG mud and circ gas out. Monitor well--losing 26 bph. CBU & pump LCM pill. Down sqz Icm pill. circ 9.4 ppg mud. pu bha and rih. wash and ream f/6,213' to 6,500'. lost partial returns and mwd pulse. pump Icm pill and down sqz. static losses = 0. drill 8-1/2" hole 6,500'- 6,791'. pooh wet. rih with 7" 29 Ib/ft L-80 casing, pump 14.0 ppg cement and set liner hanger and liner top packer @ 2,696'. Reverse circ--no cement in returns, pooh. 5/5-6 LD 5" HWDP & 5" DP. Test BOP's. PU 3-1/2" HWDP, 3-1/2" DP, BHA and RIH. RIH AND TAG CEMENT @ 6,623'. DRILL CEMENT, FLOAT SHOE AND 10' OF NEW FORMATION TO 6,801'. PERFORM LOT: .696 PSI/FI'. DRILL 6.0" HOLE TO 7,876'. 5/7-8 DRILL 6" HOLE TO 8,332'. POOH DUE TO MOTOR PROBLEMS. CHANGE OUT BHA AND RIH. REAM TO BOTTOM AND DRILL 6" HOLE TO 8,360'. DRILL 6" HOLE TO 8,912'. 5/7-8 5/9-12 DRILL 6" HOLE TO 8,332'. POOH DUE TO MOTOR PROBLEMS. CHANGE OUT BHA AND RIH. REAM TO BOTTOM AND DRILL 6" HOLE TO 8,360'. DRILL 6" HOLE TO 8,912'. EXPERIENCING SIGNIFICANT PROBLEMS SLIDING. ASSEMBLY BUILDING ANGLE. POOH. PACKED OFF @ 8,535. WORK THROUGH TIGHT SPOT. CONT TO POOH. POOH FOR BHA. MU ROTARY ASSEMBLY AND RIH. DRILL 6" HOLE F/8,912' TO 9,478'. EXPERIENCED DRILLPIPE WASHOUT. POOH TO RUN DRILLPIPE CONVEYED LOGS. RIH WITH DIT-E, LDT, CNT-H, GR, AND AMS/TCC. WORK LOGS TO 8,959'- NO-GO. LOG 6" OPEN-HOLE. POOH AND LD LOGS AND PU DIPMETER. RIH WITH DIPMETER ON DP. LOGS WOULD NOT PASS 8,637'. LOG OUT WITH DIPMETER 8,628'-6,789'. POOH AND LD LOGGING TOOLS. RIH AND MAKE WIPER TRIP. CBU. POOH. RIH WITH 3-1/2" 9.3 LB/Fi' CS 5/13 RIH WITH 3-1/2." CS HYDRIL LINER, LINER HANGER, AND LINER TOP PACKER. RIH WITH NO PROBLEMS. CIRC. WELL CLEAN. PUMP 179 BBLS (767 SX) OF CEMENT. PLUGS DID NOT BUMP. PUMP 37 BBLS OVER DISPLACEMENT. ATTEMPT TO SET LINER-NO GO. ROTATE 4 TURNS TO RIGHT TO GET OFF HANGER. BACK-OFF 6 JOINTS BELOW LINER HANGER. TOF @ 6,864'. POOH. FLUSH STACK AND PREPARE FOR BOP TEST. LD 5" DP. DECISION WAS MADE TO REDRI J J THE WELL. BAKER 32 ST#1 5/14-15 CURRENT DEPTH 6,864' MD/4050' TVD. T' csg. @ 2,696'-6,789';MUD WT 9.8 PPG AFE NO.126652; AFE TIME = 30 DAYS; ACCEPT RIG:4/17/97 @ 2:30. CHANGE RAMS AND TEST BOPE. PU 655' OF 2-7/8" TBG. RIH AND TAG TOP OF FISH @ 6,862'. PUMP BALANCED KICK-OFF PLUG. CIP @ 21:30 HRS. POOH, REVERSE CIRC, AND CONT. TO POOH. PU MOTOR ASSEMBLY AND RIH. TAG CEMENT @ 6,560'. DRILL CEMENT TO 7" SHOE AND KICK-OFF CEMENT PLUG. DRILL 6" HOLE TO 7,053'. POOR ROP. POOH FOR PDC BIT AND XL MOTOR. 5/16-19 LD INSET BIT AND PU XL MOTOR AND PDC BIT. RIH AND DRILL 6" HOLE TO 9,121'. POOH. HOLE DID NOT TAKE CORRECT FILL 3 BBLS UNDER. CIRC OUT GAS USING DRILLERS METHOD. CHECK FOR FLOW--HOLE STATIC. CONT. TO POOH. CONT. TO POOH. CHANGE BITS AND RIG. WASH AND REAM FROM 8,300' TO 9,122'. DRILL 6" HOLE TO 9,470'. HOLE STARTED LOSING 40 BPH @ 9,180'. CIRCULATE AND CONDmON HOLE. 5/20-22 5/2-3 -25 POOH PUlvlPING OUT. RIH WITH 3-1/2" LINER. ATTEMPT TO WORK PAST 8,304'--NO GO. POOH FOR CLEANOUT RUN. POOF WITH 3-1/2" LINER. RIH WITH CLEANOUT ASSEMBLY AND TAG UP @ 8,275'. WASH AND REAM TO 9,100'. CONTINUE TO BOTTOM. PUMP HI-VIS SWEEP. HIGH AMOUNT OF COAL IN RETURNS. POOH STILL HAD TIGHT SPOTS. RIH AND MAKE ANOTHER WIPER TRIP. RIH WITH CLEAN OUT ASSEMBLY g'2. WASH AND REAM 6" HOLE. TIGHT SPOTS @ 8,300' AND 8,700'. RIH WITH 3-1/2" LINER AND COULD NOT WORK PAST 8,313'. POOH WITH 3-1/2" LINER. CONTINUE- TO POOH WITH 3-1/2" LINER. TEST BOPE. TEST OK EXCEPT HCR VALVE FAILED TEST. RIH WITH 3-1/2" LINER WORK DOWN TO 8,237'. SET HANGER. ATTElvlPT TO PRESSURE UP AND RELEASE FROM HANGER. NO GO. ROTATE TO LEFF TO EMERGENCY RELEASE. PUMP CEMENT JOB. BUMP PLUGS. ATYEMPT TO SET LINER TOP PACKER. FOUND OUT NEVER RELEASE FROM LINER HANGER. POOH SLOWLY WITH LINER. RIH WITH PDC BIT AND MOTOR AND CLEAN OUT HOLE TO 7,768'. PLUGGED NOZZLE. POOH. RIH WITH MWD AND MOTOR. CLEAN OUT CEMENT TO 8,100'. ACCIDENTLY SIDETRACK HOLE. DRILL NEW 6" HOLE TO 8,330'. PUMP HI-VIS SWEEP AND POOH TO RUN 3-1/2" LINER. 5/26-31 RIH WITH 3-1/2" LINER. SET LINER AND RELEASE RUNNING TOOL. PUMP 372 SX OF CEMENT. LOST RETURNS DURING CEMENT JOB. PLUGS DID NOT BUMP. POOH TO 4,800' AND CIRC. POOH AND LD RUNNING TOOLS. RD CEMENT EQ. RUN TIE-BACK MILL AND 7" SCRAPER. RIH WITH LINER TOP PACKER AND STAB INTO TIE-BACK RECEPTACLE. PRESSURE TEST ANNULUS TO 3,400 PSI FOR 30 MINTUES--OK. SET PACKER AND PRESSURE TEST 3-1/2" LINER TO 3,400 PSI. RELEASE RUNNING TOOL. RU CHART RECORDER AND PRESSURE TEST LINER TOP PACKER AND LINER POOH. RUN PBR MILL AND 9-5/8" SCRAPER. CHANGE WELL OVER TO FIW. POOH LAYING DOWN DRILLPIPE. 6/1-2 6/3 7/22 CONT RUNNING 3-1/2" COMPLETION. MU SSV & CONTROL LINE TST TO 5000 PSI. LANDED TBG @ 0400 HRS. PRESSURE UP ON TBG PKR TO 3400 PSI. SET PACKER & TST TBG FOR 15 MINS. (GOOD TST). SET PACK OFF PRESSURE UP TO 5000 PSI. RU ON ANNULAS & TST CSG TO 3400 PSI FOR 30 MINS. N/D BOP. N/U TREE. SET BACK PRESSURE VALVE. TESTING TREE REPAIR LEAKS, TEST TO 5000 PSI. RIH W/SLICKLINE DUMMY GUN 2.55" OD X 21.10' LONG TAG AT "X" NIPPLE IN LINER @ 6702'. COULD NOT PASS. REPAIRED LEAKS ON TREE, TEST SAME TO 5000 PSI, RIH W/SLICKLINE DUMMY GUN 2.55" OD X 21.10' LONG TAG AT 'X' NIPPLE IN 3 ½" LINER @ 6702'. COULD NOT PASS. CONTINUE TO ND BOPS AND PREPARE FOR RIG MOVE. REPAIRED LEAKS ON TREE, TEST SAME TO 5000 PSI, RIH W/SLICKLINE DUMMY GUN 2.55" OD X 21.10' LONG TAG AT 'X' NIPPLE IN 3 ½" LINER @ 6702'. COULD NOT PASS. CONTINUE TO ND BOPS AND PREPARE FOR RIG MOVE. 0000 HRS - 0600 HRS: PREPARING FOR RIG MOVE. CLEAN RIG. LOG - RIH with TDT/GR/CCL & tag fill @ 8,262', tie in. Log TDT main pass from 8,262' to 1,000'. Log TDT repeat pass from 8,262'-8,200'. Run GR/CCL from 8,210'-1,000'. 8/21 11/26 PF - Perforate W/2 1/2" Carrier Guns, 6HPF, ?0 Phase Zone Interval T-41 8,170' - 180' There was no production. PF - Perforate W/2 1/8" Carrier Guns, 4HPF, 60 Phase Zone Interval T-41 8,070' - 180' No There was no production. Tag - E-Line tag @ 8,262'. Feet 10' Feet 110' 12/2 WL - RIH W/2.25" bailer to 7,784'. Bailed cement from 7,784' to 7,789'. 12/10 PF - Perforate W/2 1/8" Hollow Carrier Guns, 4HPF, 60 Phase Zone Interval Feet T-40 7,396' - 440' 44' There was no production. 12/15 PF - Perforate W/2 1/8" Hollow Carrier Guns, 4HPF, 60 Phase Zone Interval' Feet T-40 7,268' - 344' 76' There was no production. 12/19 WL - RIH W/overshot baited W/2.50" GS to 3,799' WLM. Latched E-line fish, pulled up to 3,765'. Jarred 20 min, came free, POOH, fish 23' long. RIH to 3,792' WLM and tag Baker model N-3-035 bridge plug (2.765" OD). POOH RD. BAKER 32 DAY 19 (4/28/97) CURRENT DEPTH 5,422' MD / 3,271'TVD 32" COND @ 296' 13-3/8"@ 792' 9-5/8" @ 3,015' MUD WT 9.4 PPG DRILL 8-1/2" HOLE FROM 4,426' TO 5,422' WITH HYCALOG DS 75 PDC BIT. DAY 20 (4/29/97) CURRENT DEPTH 6,364' MD / 3,744' TVD 32" COND @ 296' 13-3/8"@ 792' 9-5/8" @ 3,015' MUD WT 9.4 PPG DRILL 8-1/2" HOLE FROM 5,422' TO 6,364' WITH HYCALOG DS 75 PDC BIT. LOST CIRCULATION. MOVE PIPE WHILE SPOq-rlNG 50 BBL LCM PILL. REGAIN CIRCULATION. SHORT TRIP. DAY 21 (4/30/97) CURRENT DEPTH 6,426' MD / 3,775' TVD 32" COND @ 296' 13-3/8" @ 792' 9-5/8"@ 3,015' MUD WT 9.0 PPG RIH. DRILL FROM 6,364'-6,405' AND LOST ALL RETURNS. SPOT 20 PPB LCM PILL. PUT WELL ON TRIP TANK. MONITOR LOSSES WHILE WORKING PIPE. SPOT SECOND LCM PILL AND POOH TO 9-5/8" SHOE. HOLE LOSING @ 20 BPH FOR 4 HOURS. HOLE STOPPED LOSING FLUID. RIH TO 6,330' AND LOST RETURNS WHILE CIRCULATING. SPOT LCM PILL AND MONITOR WELL. DAY 22 (5/1/97) CURRENT DEPTH 6,500' MD / 3,812' TVD 32" COND @ 296' 13-3/8" @ 792' 9-5/8" @ 3,015' MUD WT 9.4 PPG DRILL 8-1/2" HOLE F/6,426'-6,470'. LOSING RETURNS. DRILL AHEAD TO 6,500' WITHOUT MWD. HOLE TAKING FLUID 30-40 BBL/HR. POOH TO SHOE. ATTEMPT TO SPOT LCM. MWD AND MOTOR PLUGGED OFF. POOH AND LD BHA. RIH WITH OEDP TO SHOE. GAS MIGRATED TO SURFACE. SHUT-IN WELL. ANNULUS = 125 PSI DP = 0 PSI. CBU ON % OPEN CHOKE. SHUT-IN AND ANNULUS BUILT TO 420 PSI AND DP = 90 PSI. CIRCULATE GAS OUT USING DRILLERS METHOD. NO PRESSURE ON DP OR ANNULUS. OPEN WELLMWELLBUBBLING AND LOSSlNG FLUID. RIH TO 6,460'. ClRC 9.2 PPG MUD AND ClRC GAS OUT. MONITOR WELLm LOSING 26 BPH. CBU & PUMP LCM PILL. MAY 1,5 199'( Oil Cons. DAY 23-25 (5/2-5/4/97) CURRENT DEPTH 6,791' MD / 3,953' TVD 32" COND @ 296' 13-3/8" @ 792' 9-5/8" @ 3,015' 7" @ 2,696'-6,789' MUD WT 9.4 PPG DOWN SQZ LCM PILL. CIRC 9.4 PPG MUD. PU BHA AND RIH. WASH AND REAM F/6,213' TO 6,500'. LOST PARTIAL RETURNS AND MWD PULSE. PUMP LCM PILL AND DOWN SQZ. STATIC LOSSES - 0. DRILL 8-1/2" HOLE 6,500'-6,791'. POOH WET. RIH WITH 7" 29 LB/FT L-80 CASING. PUMP 14.0 PPG CEMENT AND SET LINER HANGER AND LINER TOP PACKER @ 2,696'. REVERSE CIRCmNO CEMENT IN RETURNS. POOH. DAY 26 (5/5/97) CURRENT DEPTH 6,791' MD / 3,953' TVD 32" COND @ 296' 13-3/8" @ 792' 9-5/8" @ 3,015' 7" @ 2,696'-6,789' MUD VVT 9.4 PPG LD 5" HWDP & 5" DP. TEST BOP'S. PU 3-1/2" HWDP, 3-1/2" DP, BHA AND RIH. DAY 27 (5/6/97) CURRENT DEPTH 7,876' MD / 4,502' TVD 32" COND @ 296' 13-3/8" @ 792' 9-5/8" @ 3,015' 7" @ 2,696'-6,789' MUD VVT 9.4 PPG RIH AND TAG CEMENT @ 6,623'. DRILL CEMENT, FLOAT SHOE AND 10' OF NEW FORMATION TO 6,801'. PERFORM LOT: .696 PSI/FT. DRILL 6.0" HOLE TO 7,876'. DAY 28 (5/7/97) CURRENT DEPTH 8,360' MD /4,745' TVD 32" COND @ 296' 13-3/8"@ 792' 9-5/8" @ 3,015' 7" @ 2,696'-6,789' MUD WT 9.4 PPG DRILL 6" HOLE TO 8,332'. POOH DUE TO MOTOR PROBLEMS. CHANGE OUT BHA AND RIH. REAM TO BOTTOM AND DRILL 6" HOLE TO 8,360'. (HAVING TROUBLES SLIDING.) DAY 29 (5/8/97) CURRENT DEPTH 8,912' MD / 5022' TVD 32" COND @ 296' 13-3/8" @ 792' 9-5/8" @ 3,015' 7" @ 2,696'-6,789' MUD WT 9.4 PPG DRILL 6" HOLE TO 8,912'. EXPERIENCING SIGNIFICANT PROBLEMS SLIDING. ASSEMBLY BUILDING ANGLE. POOH. PACKED OFF @ 8,535. WORK THROUGH TIGHT SPOT. CONT TO POOH. DAY 30-32 (5/9-5/11/97) CURRENT DEPTH 9,478' MD / 5,142' TVD 32" COND @ 296' 13-3/8" @ 792' 9-5/8" @ 3,015' 7" @ 2,696'-6,789' MUD VVT 9.4 PPG POOH FOR BHA. MU ROTARY ASSEMBLY AND RIH. DRILL 6" HOLE F/8,912' TO 9,478'. EXPERIENCED DRILLPIPE WASHOUT. POOH TO RUN DRILLPIPE CONVEYED LOGS. RIH WITH DIT-E, LDT, CNT-H, GR, AND AMSFFCC. WORK LOGS TO 8,959'--NO-GO. LOG 6" OPEN-HOLE. POOH AND LD LOGS AND PU DIPMETER. RIH WITH DIPMETER ON DP. DAY 33 (5/12/97) CURRENT DEPTH 9,478' MD / 5,142' "I'-VD 32" COND @ 296' 13-3/8" @ 792' 9-5/8" @ 3,015' 7" @ 2,696'-6,789' MUD WT 9.4 PPG CONT. RIH WITH DIPMETER ON DP. LOGS WOULD NOT PASS 8,637'. LOG OUT WITH DIPMETER 8,628'-6,789'. POOH AND LD LOGGING TOOLS. RIH AND MAKE WIPER TRIP. CBU. POOH. RIH WITH 3-1/2" 9.3 LB/FT CS HYDRIL LINER. RKB =56' Rig Fh~r to Wellhe~d Kvaerner SMS Wellhead Tel. $ 2 6 3 7 10 SIZE BAKEI{ ~eLATFORM WELL # 32 FINAL COMPLETllON: 6/02/97 CASING AND FUBING DETAIL WT GRADE CONN TOP BOTTOM 32" Inside Conduclor 296 13-3/8 68 K-55 BTC 792 9-518 47 L-80 BTC 73 %5/8 53.5 7" 29 L-80 I'KC-B'[C 2,696 6,789 3-I/2 9,2 t.-80 Bm{tess 6.659 8~320 3-i/2' 9,2 L-go Buttress 6,584 3-1/2" 9.2 L-80 CS-Hych'il 6,585 6,589 3-I/2" 9.2 t,-80 Buttress 6,589 6,685 JEWELRY DETAIL NO. ITEM DEIYI'H Kvaerner Tubing ltang~ 39 (AB TC 4S DWN X STD VAM Up) 3-1/2' TC-42 x Bu~iress Crossover HES XXO Safc~y Valve Landing Ntpple (ID = 2.81 40' 3O l' 4 Baker Oil T<x)ls HC-ZXP 15ncr Fop Packer 2,~96 & 9-5/8" X 7" HMC liner Hanger 112" Buttress X ( S~Hydril Crossover HES XU D!IRASI.Ei~VI (1l) = 2.813") HES 3-1/2" X 7" PHI, Relrievable Packer BeT HyIlo Ill l ,inet 'llop Packer. B(YI' High }qow 7" x 5" 15net Hanger wilh Tie-back sleeve, BeT 80-40 Seal Bore Exlension (I.ength = HES X-Nipple (ID = 2.813') t0 6,584 6,585' 6,624' 6,650' 6,666' 6,6'72' 6,688' PDTD = 8,240' MAX HOLE ANG]LE = B32 Final 62-97 PERFORATION DATA TOP BTM ZONE SPF DATE COMMENTS 7268 73'44 4 12/15/97 7396 7440 4 12/10/97 8170 8180 4 8/21/97 8070 8180 4 1 t/26/97 REVfSI 1): 3//05/98 DRAWN BY: MWI) UNOCAL BAKER Platform Ba32St2 slot #4-8 Middle Ground Shoals Cook Inlet, Alaska SURVEY LISTING Baker Hughes INTEQ Your ref : PMSS <7753 - 8330'> Our ref : svy5583 License : Date printed : 16-Apr-98 Date created : 27-May-97 Last revised : 23-Jun-97 Field is centred on n60 50 4.803,w151 29 11.941 Structure is centred on n60 50 4.803,w151 29 11.941 Slot location is n60 49 45.236,w151 29 2.299 Slot Grid coordinates are N 2498019.249, E 235187.398 Slot local coordinates are 1987.00 S 478.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Ail data is in feet unless otherwise stated. Coordinates from slot #4-8 and TVD from wellhead (118.00 Ft above mean sea level). Bottom hole distance is 6436.10 on azimuth 10.58 degrees from wellhead. Vertical section is from wellhead on azimuth 8.94 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL LISTING Page 1 BAKER Platform, Ba32St2 ref : PMSS <7753 - 8330'> Middle Ground Shoals,Cook Inlet, Alaska revised : 23-Jun-97 ORIGINAL SURVEY Your Last Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 30.00 0.17 12.08 30.00 40.00 0.18 20.90 40.00 50.00 0.18 47.32 50.00 60.00 0.16 47.45 60.00 70.00 0.22 55.63 70.00 80.00 0.22 74.47 80.00 90.00 0.19 70.98 90.00 100.00 0.14 46.55 100.00 110.00 0.23 27.64 110.00 R E C T A N G U L A R Dogleg C O O R D I N A T E S Deg/100ft 0.00 N 0.00 E 0.00 0.04 N 0.01 E 0.57 0.07 N 0.02 E 0.29 0.10 N 0.04 E 0.82 0.12 N 0.06 E 0.20 0.14 N 0.08 E 0.66 0.15 N 0.12 E 0.72 0.16 N 0.15 E 0.32 0.18 N 0.18 E 0.85 0.20 N 0.19 E 1.08 120.00 0.22 60.80 120.00 0.23 N 0.22 E 130.00 0.23 94.60 130.00 0.24 N 0.26 E 140.00 0.22 110.87 140.00 0.23 N 0.30 E 150.00 0.15 136.97 150.00 0.21 N 0.32 E 160.00 0.16 144.58 160.00 0.19 N 0.34 E 170.00 0.20 128.20 170.00 0.17 N 0.36 E 180.00 0.28 120.36 180.00 0.15 N 0.40 E 190.00 0.28 129.47 190.00 0.12 N 0.44 E 200.00 0.19 138.14 200.00 0.09 N 0.47 E 210.00 0.19 134.27 210.00 0.07 N 0.49 E 220.00 0.19 128.52 220.00 0.05 N 0.51 E 230.00 0.19 137.01 230.00 0.02 N 0.54 E 240.00 0.13 183.26 240.00 0.00 N 0.55 E 250.00 0.24 120.31 250.00 0.02 S 0.57 E 260.00 0.28 108.00 260.00 0.04 S 0.61 E 270.00 0.14 110.11 270.00 0.05 S 0.64 E 280.00 0.20 102.08 280.00 0.06 S 0.67 E - 285.20 0.11 112.96 285.20 0.06 S 0.68 E 348.00 1.06 308.62 348.00 0.28 N 0.29 E 441.00 5.36 332.06 440.83 4.65 N 2.42 W 537.90 14.47 351.12 536.20 20.65 N 6.42 W 625.00 21.45 354.27 619.01 47.28 N 9.70 W 660.00 23.83 353.77 651.31 60.68 N 11.10 W 691.00 24.80 353.90 679.56 73.37 N 12.47 W 720.00 23.98 353.17 705.97 85.27 N 13.82 W 767.00 24.80 354.50 748.78 832.00 25.40 1.30 807.65 869.00 26.30 0.30 840.95 900.00 28.00 0.00 868.53 931.00 29.80 1.40 895.67 960.00 31.20 3.00 920.66 1025.00 35.40 5.70 974.98 1067.00 38.50 6.85 1008.54 1098.00 40.30 7.80 1032.49 1148.00 41.90 8.00 1070.17 104.56 N 15.90 W 132.08 N 16.89 W 148.21 N 16.67 W 162.35 N 16.63 W 177.33 N 16.44 W 192.04 N 15.87 W 227.60 N 13.12 W 252.69 N 10.35 W 272.21 N 7.84 W 304.76 N 3.32 W 1.29 1.31 0.64 1.08 0.23 0.65 0.86 0.44 0.97 0.13 0.19 0.28 1.37 2.15 0.68 1.40 0.64 1.81 1.86 4.74 9.87 8.09 6.82 3.13 3.01 2.10 4.53 2.70 5.50 6.20 5.58 6.85 7.56 6.12 3.21 Vert Sect 0.00 0.04 0.07 0.10 0.13 0.15 0.17 0.19 0.20 0.23 0.26 0.28 0.27 0.26 0.24 0.23 0.21 0.19 0.16 0.14 0.13 0.11 0.09 0.07 0.06 0.05 0.05 O.04 0.32 4.22 19.40 45.20 58.22 70.54 82.09 100.82 127.85 143.82 157.80 172.62 187.24 222.80 248.01 267.68 300.54 1183.00 42.90 8.48 1096.01 328.12 N 0.06 E 3.00 324.14 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 1237.00 45.70 8.20 1134.66 1275.00 48.00 8.30 1160.64 1376.00 52.30 9.80 1225.35 1438.00 54.90 10.10 1262.14 1514.00 56.70 9.90 1304.85 1571.00 60.40 10.70 1334.59 1668.00 60.49 11.00 1382.44 1745.00 60.30 10.10 1420.48 1835.00 59.10 10.40 1465.88 1918.00 59.35 10.39 1508.35 2008.00 60.70 10.90 1553.32 2096.00 61.70 11.10 1595.71 2166.00 61.50 11.20 1629.00 2226.00 62.10 11.30 1657.36 2323.00 60.40 11.10 1704.01 2425.00 60.40 11.40 1754.39 2478.00 60.30 10.60 1780.61 2540.00 59.30 11.00 1811.80 2620.00 59.30 10.40 1852.64 2705.00 59.10 9.80 1896.17 2855.00 59.70 9.70 1972.52 2986.00 60.40 9.20 2037.92 3103.00 61.10 10.00 2095.09 3243.00 59.40 8.70 2164.56 3338.00 60.00 8.72 2212.49 3434.00 58.30 9.10 2261.72 3527.00 59.00 8.70 2310.10 3587.00 59.50 9.00 2340.78 3662.00 58.60 8.20 2379.35 3813.00 59.10 7.90 2457.46 3944.00 58.80 8.10 2525.03 4016.00 58.80 8.50 2562.33 4107.00 59.10 8.50 2609.26 4197.00 58.90 7.30 2655.62 4284.00 58.80 6.90 2700.62 4473.00 59.90 6.10 2796.97 4553.00 58.70 6.90 2837.82 4693.00 58.10 6.30 2911.17 4787.00 58.00 6.50 2960.92 4880.00 58.60 5.80 3009.79 4972.00 57.90 6.80 3058.20 5066.00 58.80 6.20 3107.52 5160.00 59.60 6.70 3155.66 5252.00 59.30 8.90 3202.42 5344.00 60.40 9.10 3248.63 5439.00 59.60 8.40 3296.13 RECTANGULAR COORDINATES 365.43 N 5.53 E 392.87 N 9.50 E 469.41 N 21.73 E 518.56 N 30.35 E 580.46 N 41.27 E 628.29 N 49.97 E 711.17 N 65.85 E 776.98 N 78.11 E 853.44 N 91.93 E 923.59 N 104.80 E 1000.20 N 119.20 E 1075.90 N 133.92 E 1136.31 N 145.83 E 1188.18 N 156.14 E 1271.60 N 172.66 E 1358.58 N 189.96 E 1403.79 N 198.75 E 1456.43 N 208.79 E 1524.02 N 221.56 E 1595.90 N 234.37 E 1723.15 N 256.23 E 1835.11 N 274.87 E 1935.76 N 291.89 E 2055.68 N 311.65 E Dogleg Deg/100ft 5.20 6.06 4.41 4.21 2.38 6.60 0.28 1.05 1.36 0.30 1.58 1.15 0.31 1.01 1.76 0.26 1.33 1.71 0.64 0.65 0.40 0.63 0.84 1.46 2136.76 N 324.07 E 0.63 2218.18 N 336.83 E 1.80 2296.65 N 349.12 E 0.84 2347.60 N 357.05 E 0.94 2411.19 N 366.67 E 1.51 2539.15 N 384.77 E 0.37 2650.28 N 400.39 E 0.26 2711.22 N 409.28 E 0.48 2788.33 N 420.80 E 0.33 2864.74 N 431.41 E 1.16 2938.62 N 440.61 E 3100.17 N 459.01 E 3168.52 N 466.79 E 3286.97 N 480.50 E 3366.23 N 489.39 E 3444.90 N 497.86 E 3522.66 N 506.45 E 3602.16 N 515.50 E 3682.39 N 524.57 E 3760.88 N 535.32 E 3839.45 N 547.77 E 3920.77 N 560.29 E 0.41 0.69 1.73 0.56 0.21 0.91 1.20 1.10 0.97 2.08 1.21 1.06 Vert Sect 361.85 389.57 467.09 516.98 579.82 628.43 712.76 779.68 857.36 928.65 1006.58 1083.64 1145.17 1198.01 1282.98 1371.59 1417.63 1471.18 1539.94 1612.93 1742.03 1855.53 1957.60 2079.14 2161.16 2243.58 2323.00 2374.56 2438.88 2568.09 2680.31 2741.89 2819.85 2896.98 2971.40 3133.84 3202.56 3321.70 3401.39 3480.42 3558.56 3638.51 3719.17 3798.38 3877.93 3960.20 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 5533.00 57.60 9.90 3345.10 5626.00 57.90 10.40 3394.73 5719.00 58.90 9.50 3443.46 R E C T A N G U L A R Dogleg C O O R D I N A T E S Deg/100ft 3999.97 N 573.03 E 2.53 4077.39 N 586.89 E 0.56 4155.41 N 600.58 E 1.35 Vert Sect 4040.43 4119.06 4198.26 5813.00 59.20 9.30 3491.80 5907.00 58.80 10.50 3540.22 5999.00 59.80 11.00 3587.19 6092.00 59.80 11.00 3633.97 6186.00 60.60 11.00 3680.69 4234.94 N 613.74 E 0.37 4314.32 N 627.59 E 1.17 4392.03 N 642.35 E 1.18 4470.93 N 657.69 E 0.00 4551.00 N 673.25 E 0.85 4278.87 4359.43 4438.50 4518.82 4600.34 6279.00 59.80 11.10 3726.90 6565.00 61.50 11.80 3867.08 6737.00 61.30 11.90 3949.42 6798.00 60.70 11.30 3978.99 6823.00 59.40 12.40 3991.47 4630.21 N 688.72 E 0.87 4874.52 N 738.22 E 0.63 5022.32 N 769.23 E 0.13 5074.58 N 779.96 E 1.31 5095.78 N 784.40 E 6.45 4680.99 4930.03 5080.84 5134.14 5155.77 6883.00 57.10 14.10 4023.04 6992.00 55.00 17.20 4083.92 7194.00 56.20 17.00 4198.04 7286.00 57.60 15.50 4248.29 7378.00 58.70 16.30 4296.83 7~70.00 58.80 19.00 4344.57 7564.00 60.10 17.60 4392.35 7753.00 59.80 19.50 4487.00 7839.00 59.40 19.40 4530.52 7932.00 60.30 18.90 4577.23 5145.44 N 796.09 E 4.53 5232.49 N 820.44 E 3.05 5391.79 N 869.45 E 0.60 5465.78 N 891.00 E 2.04 5540.94 N 912.42 E 1.41 5615.87 N 936.26 E 2.51 5692.73 N 961.67 E 1.89 5847.82 N 1013.71 E 0.88 5917.76 N 1038.41 E 0.48 5993.73 N 1064.79 E 1.07 5206.64 5296.42 5461.40 5537.84 5615.41 5693.15 5773.02 5934.31 6007.24 6086.38 8025.00 61.20 19.20 4622.67 8114.00 62.30 19.80 4664.79 8278.00 64.30 19.20 4738.48 8330.00 64.30 19.20 4761.03 Projected Data - NO SURVEY 6070.42 N 1091.27 E 1.01 6144.32 N 1117.44 E 1.37 6282.43 N 1166.34 E 1.26 6326.68 N 1181.75 E 0.00 6166.26 6243.33 6387.36 6433.46 Comments in wellpath MD TVD Rectangular Coords. 8330.00 4761.03 6326.68 N 1181.75 E Casing positions in string 'A' Comment Projected Data - NO SURVEY Top MD Top TVD Casing Rectangular Coords. Bot MD Bot TVD Rectangular Coords. 0.00 0.00 0.00N 0.00E 30" Casing 0.00 0.00 0.00N 0.00E- 13 3/8" Casing 0.00 0.00 0.00N 0~.00E 9 5/8" Casing 0.00 0.00 0.00N 0.00E 7" Casing Target name Geographic Location Ba-32(ST#1) 14-May-97 T.V.D. 5390.00 300.00 300.00 0.05S 792.00 771.45 115.06N 3015.00 2052.21 1860.02N 6789.00 3974.59 5066.88N Rectangular Coordinates 7400.00N 1600.00E 0.68E 16.67W 278.94E 778.41E Revised 14-May-97 I(e-CEIVED la. TEST: 'ANNUAL SPECIAL STATE OF ALASKA AUG 27 ]998 ALASKA OIL AND GAS CONSERVATION COMMISSlONAlaskaO!l_~GasOons GAS WELL OPEN FLOW POTENTIAL TEST REPORTAnchorag~C°rnmiss~on. ' -- lb. TYPE TEST STABILIZED E] NON STABILIZED El MULTIPOINT E] CONSTANT TIME I~ ISOCHRONAL [~ OTHER 2. Name of Operator' '~ ' C ' ~ 7. Permit No. Iqklt0~ ell ~P,~")' OF C~l..l~R~t~ C~ ~ ) ' 3. Address ~. , ~ ~ ~ 8. APl Number 41 Locatio~ of Well ~ ~ ~/ ..... ~ ~ 9. Unit or Lease Name 10. Well Number 5. Elevatio~ in'feet (indicate KB, DF etc.) t 6. Lease Designation and Serial No. ~ _, ~ 12. Completion Date ~13. Total Depth ~14. Plugback T.D. (M 0~15. Type Completion (Describe) 16. Csg. Size Weight per foot, lb. I.~.:ig~nches . Set at fL , Perforations: From_ - ~ To 17. Tbg. Size Weight per foot. lb. I.D. in inches S~I at ft. J~G V~: ~' ~; I 20. APl Liquid Hydrocarbons ~ 21. Specific Gravity Flowing fluid I 18.&g~.,.L~jPacker set at ft.~/~) ) ~J~9' GOR cf/bb~. 22. Producing thru: Reservoir Temp. o F. Tbg. J~ Csg. r-J ~ O 23. Length of flow channel (L) Vertical Depth (H) J Ga. J % CO2 J I I 24. Flow Data J Prover Choke J Line X Orifice No. J Size (in.) Size (in.) 2. J 4 x !-~' 3. J /~ t", / Pressure psig Mean Annual Temp. o F. ~' N2 I % H2S I Tubing Data Diff. Temp. Pressure hw ° F. psig Temp. Pressure ° F. psig Barometric Pressure (Pa), psia t~.~.5' Prover j Meterrun [ Taps Casing Data Duration of Temp. F Iow °F' Hr. i I No, 2. 3. 4. 5. Basic Coefficient (24-Hour) Fb or Fp Pressure Pm 22..0 2,~o Flow Tel,-np. J Gray.fy FactorFt [ FactorFg I. oo go !t.x~,5; Super Comp. Rate of Flow Factor Fpv Q, Mcfd I.o 5~ J Pr Temperature T Tr Critical Pressure Critical Temperature for Separator Gas Gg for Flowing Fluid G Form 10-421 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit ~n duplicate Pc No. 1. 2. 3. Pc2 - Pt2 [ Pw JPw2 pc2 . pw2 25. Remarks' I hereby certify that the foregoing is true and correct to t'he best of my knowledge n AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z DEFINITIONS OF SYMBOLS , . Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/,' hwPm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor=~,,· 1/z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air=1.000), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F.) per barrel oil (60 degrees F.) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia Shut-in pressure at vertical depth H, psia Static pressure at point of gas measurement, psia Reduced pressure, dim'snsionless Flowing pressure at vertical depth H,-psia . . Flowing wellhead pressure, psia · Static column wellhead pressure corresponding to Rt, psia Rate of flow, Mcfd (14.65 psia and 60 degrees F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual Of Back-Pressure Testing Of Gas Wells, Interstate Oil Compact Commission, Oklahoma CitY, Oklahoma. ., Form 10-421 - 60 - Baker Well 32 -- Flow-after-Flow Four Point Test Analysis (7/25/98) 10000000 3600000 1000000 100000 10000 i i i il iii I i iijllllll i i i iiiii F ..... F F--~--F-T-T-I ........... ~ ..... ~---~ I-~--I-~-T ............ I ...... I .... I---~--I--F-I--I- .......... F ..... F---F--~--F-T-T-I ........... ~ ..... ~---~---f-~--I-~-T-- ............ I ...... I .... I---F--I--F-I--I- .......... ~ ..... ~ - - - ~ - - ~ - -~ - + - ~ -~ ........... d ..... ~ - - - ~ - -~l- - ~ - -I- ~ - · ........... I ...... I .... t- - - ~ - -I- - ~ -I- -I- .......... 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I-- I------~----I----~--~--I-- ~ I I I I IIII I I I IIIII I I I I llll ~ I I I I llll I I I IIIII I I I IIIII ~ I I I IIIII I I I IIIII I I I I IIII / I I I IIIII I I I IIIII I I I IIIII I I I IIIII I I~ I IIIII I I I IIIII I I I I Il)l I I I IIIII I I I I IIli 1 10 AOF = 32 MMCFD 100 1000 Flow Rate, Q, MMCFD O:\Gas Cft\98SHP_ANAL.xls\Ba32chrt 8/18/98 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X 118' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Middle Ground Shoal 4. Location of well at surface Baker Platform, Leg #4, Slot #8 8. Well number 1987' FNL, 478' FWL, Sec. 31, T9N, R12W, SM Baker # 32 At top of productive interval 9.~ber/a~r~al n_um~ ~ 4084' FSL, 1525' FWL, Sec. 30, T9N, R12W, SM At effective depth 10. APl number 930' FNL, 1650' FWL, Sec. 30, T9N, R12W, SM 50- 733-20473-00 At total depth 11. Field/Pool 824' FSL, 1775' FWL, Sec. 19, T9N, R12W, SM Middle Ground Shoal 12. Present well condition summary Total depth: measured ~ 8330' feet Plugs (measured) true vertical 4761' feet Effective depth: measured 8250' feet Junk (measured) true vertical 4726' feet Casing Length Size Cemented Measured depth True vertical depth Structural 240' 32" Driven 296' 296' Conductor 740' 13-3/8" 795 sx to surface 792' 771' Surface 739' 9-5/8" 1136 sx 3015' 2052' Intermediate Production Liner 4039' 7" 955 sx 2696' - 6789' 1890' - 3973' Liner 1661' 3-1/2" 372 sx 6659' - 8320' 3904%~' Perforation depth: measured 7268' - 7344'; 7396' - 7440'; 8070' - 8180' true vertical 4238' - 4277'; 4301' - 4327'; 4639' - 4682' Tubing (size, grade, and measured depth) 3-1/2" 9.2# L-80 @ 6650' Packers and SSSV (type and measured depth) HES"PHL"Pkr@6625' [~cEIV~D_ 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A /~..~ ~ Treatment description including volumes used and final pressure N/A A~aS~(~ 0it & Gas Cons. C0mm~Ssio~' Anchorage 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation No Prior Production. Subsequent to operation 7/23/98 0 6,800 0 605' 1650 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~,,~ .-¢~? & ~t c''''-'' Dale Haines Title: Drilling Manager Date: Jul. 30, 1998 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE PERFORATION DATA SHEET BAKER PLATFORM WELL Cf 32 Perforate Tyonek W/2-1/2 HSD Carrier Guns, 6HPF, 60 Phase. D~e Zone Interval MD Interval TVD 6/22/98 Ty-40 7,268' - 7,344' 4,238' - 4,277' 8/21/97 Ty-4] 8,170' - 8,180' 4,677' - 4,682' Perforate Tyonek W/2-1/8 Hollow Carrier Guns, 4HPF, 60 Phase. Date Zone Interval /ViD Interval TVD 12/10/97 Ty-40 7,396' - 7,440' 4,301' - 4,327' 11/26/97 Ty-4! 8,070' - 8,180' 4,639' - 4,682' PERMIT AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 03/09/98 DATA T DATA PLUS RUN RECVD 96-056 7710 /~CHLUM DITE/LDT/CNTH 1 06~05~97 96-056 CN/LDT ~MYLAR 6786-8919 1 06/13/97 96-056 PIL/SFL J~MYLAR 6786-8947 1 06113/97 96-056 TDTP ~q~fLAR 1000-8258 1 09/16/97 96-056 COMP RCD 8/21/97&J~MYLAR 7700-8200 1 09/16/97 96-056 CMT MAP TOOL c~YLAR 62650-8270 1 09/16/97 10-407 R COMPLETION DATE / / / / / / DAILY WELL OPS R / / / TO / / / / / / Are dry ditch samples required? yes ~And received? Was the well cored? yes ~ysis & description received? Are well tests required?.yes ~_.Received? ~f~~' Well is in compliance Inmtial"- '~ COMMENTS T Unocal Agricultural Products Diversified Business Group 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-maih childersd @.unocal. com UNOf. Debra Childers Geotech Assistant DATA TRANSMITTAL March 9, 1998 To: Laurie Taylor 3001 Porcupine Anchorage, AK 9950 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Transmitting the following items: - · DILLON 2rd - DILLON 4 GP 18742-38 · GP 53 GP AN-26 · GP AN-52 . MGS 17595-11, MGS 17595-13. MGS B-30 · MGS MGS Baker 32 SRU 212-27 SRU 223-28 SRU 223-28 SRU 223-28 SRU 223-28 SRU 23-22 TBU D-11 TBU D-25rd Packer Setting Record 1/25/98 Packer Settin( Tie in Record 1/30/98 )letion Record with Gamma-Re, 11/17/97 Cement Evaluation Log with GR/Collars 8/28/98 )letion Record with Gamma 11/19/97 Thermal Decay Time 1/31/98 )letion Record 10/30/97 )letion Record with Gamma 12/10/97 )th Determination 11/12/97 )letion Record 11/24/97 )letion Record 12/10/97 )letion Record 9/11/97 Cement Bond Log 9/8/97 }letion Record 9/15/97 }letion Record 9/8/97 Thermal Decay Time Log 9/8/97 ~letion Record 9/12/97 ~letion Record 2.5 HSD. 31J UJ HMX 1/16/98 Perforation Record 2 Y2" Ultraiets 1/09/98 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. I Received by~~.__~, ,~')'~ Date'. TBU D-27 '~ ~ 1 1 I 5" Completion Record -~' 1 11/8/97 TBU D-2Ard · 1 1 5" Completion Record 1 11/9/97 TBU D-32 · 1 1 5" Completion Record 1 1/20/98 TBU D-3rd2 · 1 1 5" Bridge Plug 3 12/5/97 TBU D-3'd2 , 1 1 5" Bridge Plug Log 1 12/3/97 TBU D-3rd2 , 1 1 5" Perforation Record 2 1/2" Ultrajets 1 1/7/98 TBU D-3rd2 1 1 5" Production Packer 3 12/26/97 TBU D-48 · 1 1 5" Completion Record 1 11/6/97 TBU D-48 1 1 5" Completion Record 1 1/21/98 TBU D-5rd · 1 1 5" Gauge Ring/Bridge Plug 1 12/18/97 TBU D-5rd · 1 1 5" Gauge Ring/Bridge Plug 1/2 12/22/97 TBU D-5rd ' 1 1 5" Perforation Record 2 ~" Ultrajets 1 1/05/98 TBU D-5rd · 1 1 5" Production Packer 3 12/23/97 TBU G-12rd ~.. 1 1 5" Completion Record 1 1/26/98 TBU G-16 1 1 Water Flow Log 1 1/28/98 TBU G-22 1 1 1" Leak Detection Log Temperature & Spinner 1 12/17/97 TBU G-22 LS 1 1 Water Flow Log 1 12/18/97 TBU G-22 SS 1 1 1" Leak Detection Log 1 12/18/97 TBU G-36 D?~t ~ ~ 1 1 Water Flow Log 1 1/24/98 TBU G-3rd2 . 1 1 5" Completion Record 2 4/7/97 TBU G-40 1 1 5" Injection Profile 1 1/22/98 TBU G-40 1 1 Water Flow Log 1 1/22/98 TBU G-5 WO 1 1 Water Flow Log 1 1/19/98 TBU K-26rd · 1 1 5" Completion Record 1 10/8/97 TBU K-5 · 2 1 5" Gamma/CCL 1 9/22/97 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Unocal Agricultural Products Diversified Business Group 909 West 9th Ave. Anchorage, AK 99501 Tele: [907) 263-7889 Fax: (907) 263-7828 E-maih epardac I @anchorage. unocal eom UNOCAL ) Debra Childers Geoscience Clerk DATA TRANSMITTAL 97-24 June 10,1997 To: Laurie Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal - .-b . -- _ Transmitting the following item: :~ .~..:i.~:-:':-:-.-:-:-:-:: :-:-: -:-:-: :-.'-.'-: ~ .:.:.>:.;+:.:+:.:.:-.-.:..-:.::.:.:.::.:.:.× ,,:-: ....:+..,......-...-..<.-.-.-<...-.........-.-.-.- -...-.-.-.,..- BAKER 32 BLACKLINE 1 ~ _~QM_PLETION RECORD_~ I 5/11/97 BAKER 32 BLACKLINE 1 PHASOR INDUCTION-SFL 1 5/11/97 MGS 17595-15RD BLACKLINE 1 COMPLETION RECORD 1 2/25/97 SCU 12A-3 BLACKLINE 1 COMPLETION RECORD 1 5/8/97 SRU 23-22 BLACKLINE 1 COMPLETION RECORD 1 4/28/97 SRU 23-22 BLACKLINE 1 GAMMA RAY / CCL LOG 1 4/28/97 SRU 23-22 BLACKLINE 1 COMPLETION RECORD 1 4/30/97 SRU 23-22 BLACKLINE 1 COMPLETION RECORD 1 5/3/97 TBF A-27 BLACKLINE 1 DEPTH DETERMINATION 1 5/16/97 WHIPSTOCK TBU D-27 BLACKLINE 1 COMPLETION RECORD 1 5/21/97 TBU D-47 BLACKLINE 1 COMPLETION RECORD 2 5/20/97 TBU D-47 BLACKLINE 1 THERMAL DECAY TIME LOG 1 5/20/97 -.-~ .' . ~. ;'.?'t '~"~,~; Please acknowledge receipt by signing and returning one copy of this transmittal or Received by:". ..... ': .~;~...c~.~. ~"~ Date: .~ ~ .~., ~ Unocal Agricultural Products Diversified Business Group 909 West 9th Ave. Anchorage, AK 99501 Tele: (907) 263-7889 Fax: [907) 263-7828 E-mai/: epardac 1 @anchorage. unocal, corn UNOCAL Debra Childers Geo$cience Clerk DATA TRANSMITTAL 97-22 June 4,1997 To: Laurie Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 Unocal Tramsmitting the following item: ~ (.42 - C3 ~ ~-~ '~-- -'7--7 / ........... ' ......... ~ ~,~%1~'~~~ ........ . ......... ~: ~:'~4~.....,~:~:~,....~i ~ ~ ........... , ...... ~ .-' ......... ' ~- ': ,~:~:~:~:~s~~?~ MGS I BAKER 32 I TAPE AND LISTING Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263°7828. UnocalCorporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOCAL ) Dale A. Haines Drilling Manager Wednesday, May 14, 1997 Mr. Blair Wondzell AOCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell: As requested in your approval of Baker 32, I am sending a summary of the Baker 32 drilling operations since April 27, 1997. If you have any questions, please call Mitch Damm at 263-7679. /gac attachment Sincerely, Dale A. Haines Drilling Manager R[ E[V D MAY 1 5 1997 --- STATE OF ALASKA '- ALASKA C,.-AND GAS CONSERVATION t, OMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: x Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: x 118' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Middle Ground Shoal 4. Location of well at surface Baker Platform, Leg #4, Slot #8 8. Well number 1987' FNL, 478' FWL, Sec. 31, T9N, R12W, SM Baker 32 At top of productive interval 9. Permit number At effective depth 10. APl number 50- 733-20473 At total depth 11. Field/Pool 824' FSL, 1775' FWL, Sec. 19, T9N, R12W, SM Middle Ground Shoal 12. Present well condition summary Total depth: measured 6500 feet Plugs (measured) true vertical 3812 feet Junk Effective depth: measured 6500 feet (measured) true vertical 3812 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 240 32" Driven 296' 296' Surface 740 13-3/8" 795 sx to surface 792' 771' Intermediate 739' 9-5/8" 1136 sx 3015' 2052' Perforation depth: measured NIA true vertical N/A !V!AY 8 1997 Tubing (size, grade, and measured depth) N/A Alaska 0il & Gas Cons. C0mmiSs~u' ~ch0rage Packers and SSSV (type and measured depth) N/A 13. Attachements Description summary of proposal: x Detailed operations program: x BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: Ongoing 16. If proposal well verbally approved: Oil: Gas: x Suspended: Blair Wondzell 511197 Name of approver Date approved Service: ,-/-o O,-t'~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, r- Signed: Dale Haines /-)~,'~¥?-~ ~t C..-.J Title: Drilling Manager Date: 5~2~97 /~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApprov.~N~ Plug integrity BOP Test /..,/' Location clearancei ,~,,,~ -- / Mechanical Integrity Test Subsequent form required 10- ¢/0 0rigina! Signea By David W, Johnston A, rov , o,,,e Comm,ss,o. r ___.., ¢ Oomm,s ,o r ? 7 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE I UNOCAL Middle Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 UNOCAL Mid6~ _;round Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 II. Complete 8-1/2" Hole Secti6n: o MU the followSng BHA: 8-1/2" Hughes ATMGT-09 PS (Nozzles = 3 x 12/32) 6-3/4" M1-XL Motor with 8-3/8" UBHS4AKO=I.0 8-1/4" String Stabilizer 6-3/4" MWD 6-3/4" HOS Crossover Sub Multiple bypass circulating sub 3 JT of 5" HWDP 6-1/2" Jars 15 JT of 5" HWDP 6-1/2" Accelerator 18 JT of 5" HWDP . o , , RIH with BHA and CBU. Monitor losses, pressures. Be prepared for gas at surface. Note: Prepare a 50 BBL 20 PPB LCM pill. Drill 8-1/2" hole to 7,000' MD. Note: Do not go beyond this depth unless discuss with office. We are t~ing to set 7" shoe in a shale. Note: The target cylinder is 250 ft left or right of the line (plan view) and 125 ft below the line. No upper limit in the plan view. The cylinder above the line is defined by a maximum hole angle of 63°. Discuss circulating bottoms up with office. POOH standing back 5" drillpipe. MWD 32fin12.doc Page 1 of 10 5/2/97 / 2:37 PM UNOCAL Mid~ Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 III. Run and Cement 7" 29 lb/ft KC-Buttress Liner. Casing: 7" 29 #/FT L-80 Buttress TKC Coupling Collapse 7,030 psi, $.160 Burst psi, Tensile 676 Kips Torque RTG of Coupling: 24,300 ft-lbs max; 15,900 ft-lbs optimum, 7,400 fMbs min. General Information: Top Depth: Bottom Depth: Previous CSG: Hole Size: M.W.' 2,700' MD/1,893' TVD 7.000' MD/4,089' TVD 9-5/8" ~ 3,015' MD 8-1/2" 9.4 PPG (Estimated) Equip ment Requirements: Float Shoe: Baker Type V Bladed Float Shoe. "Baker-Lock" on the end of 1st casing jt. Float Collar: Baker Double Valve Float Collar. "Baker-Locked" on the end of the second casing jt. Landing Collar: Baker Type 1 Landing Collar "Baker-Locked" on the bottom of the third casing joint. 1st 4 Couplings: Baker Locked Plugs: Casing wiper plug and drillpipe wiper plug. Note: ali plugs and float equipment are PDC drillable. CSG hanger: Need 7" Kvaerner spacer sleeve for wellhead when tubing hanger is nm. CSG EQ' 4-1/2" IF X 7" Buttress Circ. Swedge. Frank's fill-up tool. AP1 modified pipe dope. Liner Hanger: 9-5/8" 53.5 Ib/ft x 7" 29 lb/ft B.O.T. HMC Liner Hanger ZXP Liner Top packer with C-2 Setting Sleeve with Extension C-2 Setting tool--non-rotating. Note: Since this ZXP LTP has the C-2 Setting Sleeve, we do not have the abili~' to rotate the 7" casing. MWD 32fin12.doc Page 2 of 10 5/2/97 / 2:37 PM UNOCAL Capacities: Midt. Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 7" CSG 0.0371 bbl/ft 8-1/2" OH x 7" 0.0226 bbl/fi 9-5/8" x 7" 0.02317 bbl/ft 9-5/8" x 5" DP 0.0465 bbl/ft 5" DP 0.01776 bbl/ft Excess Requirements: 150 % excess in open hole. No excess in the float track or in 9-5/8" x 7" annulus. Pump the entire 1.200 sx of cement you have on board Slur~ Data (Actual data should be checked with final lab test): Total volume: Total sacks: Slurry Weight: Cement Yield: Mix Water: Total Liquid: Thickening Time: Cement Composition: Liquid Additives: 1,836 ~/326 BBLS ~1,200 14.0 lb/gal 1.53 fCsk Filtered Inlet Water 7.78 gal/sk 4:21 "G" neat D029 LCM ~ 0.266% BWOC D145A Dispersant ~ 0.030 gal/sk D300 Fluid Loss ~ .85 gal/sk PAKC359.100 % BWOC BHST: BHCT: 120F 120 F MWD 32fin12.doc Page 3 of 10 5/2/97 / 2:37 PM UNOCAL ) Mida. _;round Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 i i Cement Procedure: Note: Verify all depths and volumes before cement job. Rathole volumes were not figured into calculations. o RU GBR casing Crew. Have GBR test equipment and power packs before RU to mn casing. Have two Frank's fill-up tools on board. Have casing crew supervisor document stabbing board inspection on UNOCAL form and Vendor Pre-job Checklist. Note: Check fill-up tool robber element. . RU Circ. swedge/Frank's fill-up tool. RU the 500 ton bails, 350- Ton BJ slip-type elevators, and 350 Ton spider slips. Note: Verify compatibility, of mainfold with both plugs prior to RU. o o o . PU the first three casing joints of casing (80 12 float track); and fill up casing. PU 40-50 It and verify flow path through float equipment. Note: Verify casing wiper plug is installed on nmning tool. RIH with 7" 29 lb/ft L-80 Liner Baker Float Shoe 1 JT 7" 291b/ft casing Baker Float Collar 1 JT 7" 29 lb/ft casing Baker Landing Collar 7" 29 lb/it L-80 TKC Buttress casing Baker HMC 9-5/8" x 7" Liner Hanger Baker ZXP Liner Top Packer with C-2 Setting Sleeve Extension. 5" Drillpipe Space-out so that the T.O.L is at ~ 2,700'. Establish circulation and obtain PU and SO weights. PU BOT's liner hanger cementing head. RU cementing lines and pressure test to 500psi/5,000 psi. MWD 32fin12.doc Page 4 of 10 5/2/97 / 2:37 PM . UNOCAL Pump the 1bllowing Cement Schedule: Mida. Ground Shoal Field Baker #32 Grass Roots Revised Drilling PrograTM Revised 5/2/97 Revision #3 Volume (BBLS) 30 Mud Weight (PPG) 11 Fluid Pumped Mudpush XT 203 14.0 Cement Slurry (includes 80 ft float track) 10 8.5 Filtered Inlet Water 47 9.4 Drillpipe Wiper Plug Displacement with Dowell Cement Unit *** DP plug contacts Casing Wiper Plug 159 9.4 Displacement with Dowell Cement Unit Note: To avoid setting the liner hanger prematurely, the internal pressure cannot exceed 2,000 psi over the annulus pressure during cement job. a) Reciprocate the pipe during pumping of the cement --if possible. When FIW rounds the comer pipe will become heavy, stop reciprocating. When cement is halfway up the annulus begin reciprocating casing in 10-15 ft strokes. If hole becomes sticky at any point, space-out liner hanger. b) Verify DP plug indicator has been activated. c) Monitor pressures to verify DP plug contacts casing wiper plug. d) Reset stroke counter as soon as DP plug contact wiper plug. . Bump Plugs in landing collar. Do not exceed 3 BBLS over calculated displacement. Note: If plugs don't bump discuss options with office. To get off hanger, set casing on bottom and rotate 6 tums to the fight. 9. Pressure up drillpipe to 2,500 psi and set liner hanger. 10. While maintaining drillpipe pressure, set down 20,000 lbs on the liner hanger to engage slips. 11. Increase drillpipe pressure to 4,000 psi; and shear hydraulic pusher tool. This will set ZXP liner top packer. 12. Bleed off all pressures. Rotate dfillpipe 6 fight-hand tums at the too[~tr~ release C-2 Setting Tool. ~ ,~, ~_; ~ ,.?, ~ ~;: MWD 32fin12.doc Page 5 of 10 UNOCAL ) Midt,. 3round Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 13. Pressure up driiipipe t© 800 psi. PU unit seals of C-2 Setting -fool are our of liner. Observe pressure drop while pulling seals out. 14. Reverse circulate out excess cement if plugs bump. Note: If plugs do not bump, POOH with drillpipe and PU clean-out assembly. 15. Continue to POOH and LD setting tools. MWD 32fin12.doc Page 6 of 10 5/2/97 / 2:37 PM UNOCAL Midt. Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 Drill 6" Hole from 7,000' to 10.337' Note: Change top pipe rams to VBR's 1. LD 7,000' of 5" drillpipe and PU 3-1/2" drillpipe. . Make-up the following assembly 6" Sec. DBS FM2643 PDC bit jetted at 4-3/4" M1-XL Motor set at AKO = 1.0 5-7/8" String stabilizer Crossover Sub 4-3/4" Navitrack MWD (Non-mag drill collar ) Hang-off sub Multiple Bypass Circ. Sub (Weatherford) 3-1/2" HWDP 4-3/4" Houston Engineering Jars (Jar up/Bumper Sub Down) 3-1/2" HWDP 3,000' of 3-1/2" 13.30 lb/ft drillpipe (Weatherford) 4,367' of 3-1/2" 15.5 lb/ft drillpipe (Weatherford) 2,700' of 5" 19.5 lb/ft drillpipe (UNOCAL) 3. RIH with BHA and tapered string and tag cement. Drill cement to landing collar. 4. Pressure test casing and liner top packer to 3,500 psi for 30 minutes. Note: use chart recorder and monitor the volume required to pressure up casing. 5. Drill landing float track and 10' of new formation. . Obtain pick-up, slack-off, and torque values and record on morning report. We need to accurately predict future torque and drag values. 7. Perform Leak-Off Test and fax results into office. Note: Call office if LOT is below 0.75 psi/ft. 8. Drill 6" hole from 7,000' to 10,337'. 9. Discuss circulating bottoms up and wiper trip with office prior to POOH. 10. POOH with BHA. MWD 32fin12.doc Page 7 of 10 5/2/97 / 2:37 PM UNOCAL MidQ~ .;round Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 V. Run Drillpipe Conveyed Wireline Logs: GR/DIL/CNL/DEN 1. Hold pre-job safety meeting and discuss use of nuclear tool with rig personnel. 2. RU Schlumberger WLU. . MU the following wireline logging tools: DIT-E (Phasor Induction with SP) LDT (Litho-density) CNT-H (Compensated Neutron) GR (Gamma Ray) AMS/TCC (Head Tension) Total 32.24 t~ 17.36 f~ 7.25 ft 5.0 ft 12.43 ft 74.28 ft Note: Ensure Schlumberger tums on the S.P. Log. SP is part of the DIT-E tool. 4. RIH xvith logging tools to 7,000'. 5. PU side-door entry-sub 6. RIH with Schlumberger's wireline and wet connect; stab into wet connect. Note: The wet connect may have to be pumped down. Also report ifwireline ran all the way to bottom. 7. Poxver up tools and ensure all equipment is functional. 8. RIH logging 6" hole. Do not tag bottom with tools. 9. Log 6.0" hole. Log ~ 1,800 ft/hr. 10. POOH with wireline and then logging tools. 11. RD SWS wireline trait. 12. Fax logs into drilling department ~ 263-7862. MWD 32fin12.doc Page 8 of 10 5/2/97 / 2:37 PM UNOCAL Midt,. Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 IV. Run 3-1/2" Liner, Liner Hanger, and Liner Top Packer Liner: 3-1/2" 9.2 lb/ft CS Hydril L-80 robing Collapse psi, Burst psi, Tensile Kips Make-up Torques: 3,000 ft-lbs General Information: Total Depth: Previous CSG: Liner Lap: Hole Size: M.W.' 10,337' MD/5,718' TVD 7" liner ~ =7,000' MD 150' 6.0" 9.4 PPG (Estimated) Note: Do not set liner hanger in a high dog leg section. Equipment Requirements: Float Shoe: Baker V Set Shoe on the end of first casing jt. 13-3/8" 9-5/8" 3-1/2 ~ Float Collar: Baker Double Valve Float Collar. Landing Collar: Plugs: Plug Baker Landing Collar "Baker-Locked" on the pin end of a casing jt.. Baker 5"x 3" Drillpipe Wiper Plug and Baker Type 1 3-1/2" Liner Wiper Centralizers: None Liner Hanger: Baker HMC Rotatable, Tandem Cone, Hydraulically Set, 5" 151b/t~ x 7" 29 lb/ft, Liner Hanger with lower PBR. HR-ZXP Liner top packer Setting Sleeve: Baker HR Setting Sleeve with 6' Tie-Back Extension and RS Nipple. 5" Buttress pin. Setting Tool: Capacities: Baker HR Setting Tool with RS pack-off Seal Assem_blv. 3-1/2" IF Box. 3-1/2" TBG i 0.0087 BBL/~ 3-1/2" x 7" 29 lb/ft i 0.0252 BBL/ft 3-1/2" x 6" OH i 0.0231 BBL/ft 3-1/2" 13.3 lb/f~ DP I 0.00742 BBL/fl: MWD 32fin12.doc Page 9 of 10 5/2/97 / 2:37 PM UNOCAL Mida..;round Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 3-1/2" 15.5 lb/ft DP ! 0.60658 BBL/ff 5" 19.0 lb/ft DP ] 0.01776 BBL/ff Excess Requirements' Tail Slurry: 300 % excess in open hole. No excess in the 5" x 7" annulus. No excess in the float track. Tail Slur~ Data (Actual data should be checked with final lab test): Total volume: Total sacks: Slurry Weight: Cement Yield: Total Liquid Required: Thickening Time: Cement Composition: Liquid Additives: 1,756.5 ft3 / 312.8 BBLS 1,340 sx 15.0 lb/gal 1.31 ft3isk 6.25gal/sk: 4 hr:49 mn "G" neat D110 0.020 GPS PAKD 145A 0.020 GPS PAKD300 1.100 GPS BHST: BHCT: 135F 125 F MWD 32fin12.doc Page 10 of 10 5/2/97 / 2:37 PM · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shu~own: Re-enter suspended well; Alter casing: Repair well: Plugging; Time extension: Stimulate: ....... C.h..a.n..ge.a. pproved pr°gram__!..._x. ......... Pull tu'--'~ing: Variance;. Perfora/e: .... Other; '~ ...... 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Compan_y of ca__!i_fo_m_!_a,.(.U..r~.0..c~. I) . Development: x___ 118' RK8 above MSL feet 3, Address Explorator3c, 7. Unit or Property name StratigraphJc: P.O. Rex 196~)47 Anchorage, AK 99519 Service: Middle Ground Shoal 4'.'Locatioh of well at surface Baker PIab"orm, Leg #4, S[o~'~8 .................... 8. Well num~3er --' 1987' FNL, 478' FWL, Sec, 31, TgN, R12W, SM Baker 32 At top of productive interval 9. Permit number At effective depth 10. APl number- 50- 733-20473 , ,, . . At total depth 11. Field/Pool ....... .8_24'__~SL. 1775' FWL. Sec. 19. TgN, R12W, SM .....Mid. d. !e G~IInL"~Ji~I~ 12.'Present well condition summary il~, 'L-'~,~ L Total depth: ' measured 6~00 feet Plugs (measured) ,,uev~i~, ~8~2 ~et ~'IAY 5 1997 Effective depth: measured 6500 feet Junk (measured) -~8~J~ .0it & Gas Cons. ,, ....~--c-0mmiS'$~u:' true vertical 3812 feet ' , Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 240 32" Driven 29B' 296' Surface 740 13-3/8" 795 sx to surface 792' 771' Intermediate 739' 9-5/8" 1136 sx 3015' 2052' Production ..................... _~_ ! -- F'erforaUon depth; measured N/A Post.~it~ Fax N, ote 7671 'o -' Tubing (size, grade, and measured depth) N/A ~hone #' - .... '~hon~' .,_J ...... - FSx # ............ I Fa~ Packers and SSSV (type and measured depth) N/A .~ ........... i ......... ....... - ...... . .. 13. Attachaments Description summary of proposal: x Detaile~ operations program; x BOP sketch: ............ 14,'Estimated'~J~;i~"~'&r'Tc~n~nb~cin~'-~i~-e'~'fJ0-~ ................... 15. status ofwell classification as: f,,.~o'r'~': 7f'~% -i6'i-IfP~'~po~al well verbalJy approved: " Oil: Gas: x Suspended; .... _N__am_e__of app.rover Date approved Service: 17, I hereby certify that the foregoing is true and Correct'{b-thb EJa~'l?~f'~J~'~,n-~l~b7 ........... Signed: Dale Haines /~~l~ Title; Drilling Manager Date: 5,2/97 .................. ......................... ..,,, ., , ............. f FOR COMMISSION USE ONLY Conditions ~ approval: Noti¢~ Commission so represen[aljve ma)' witness ]Approval No." Mechanical Integrity Test Subsequent form required 10- ~ ~ 0rigina! Signea David W. Johnsto~ Approved by order of the Commissioner Commissioner Date ~'~ '~ .,... · . I (:3 Form 10-403 Rev 06/15~88 Approved Copy Returned SUBMIT IN TRI~ LICATE 1tRY-02-97 FR I 03: 50 PI1 v, uE/l ~ ,-~ UNOCAL ) Middle Ground Shoal Field Baker #32 Grass Roots Revised DrillingPr0gram Revised 5/2/97 Revision #3 ,; I,'-RI U3:bU Pl'l UNOCAL Middle Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 II. Complete 8-1/2" Hole' ~M_U 8-l/2" Hughes ATMGT-09 PS (Nozzles = 3 x 12/32) 6-3/4" M1-XL Motor with 8-3/8" UBHS---AKO~1.0 8- !/4" String Stabilizer 6-3/4' .MWD 6-3/4" HOS Crossover Sub Multiple bypass circulating sub 3 JT of 5" HWDP 6-1/2" Sars 15 JT of 5" HWDP 6-1/2" Accelerator 18 JT of 5" HWDP Y, UJ/IJ . . . . RIH with BHA and CBU. Monitor losses, pressures. Be prepared for gas at surface. Note: Prepare a 50 BBL 20 PPB LCM pill. Dx/Il 8-1/2" hole to .7.,.000' MD. Note: Do not go beyond this depth unless discuss with office, We are trying to set 7" shoe in a shale. Note: The target cylinder is 250 ft left or right of the line (plan view) and 125 ft below the line. No upper limit in the plan view. The cylinder above the line is defined by a maximum hole angle of 63°. Discuss circulating bottoms up with office. POOH standing back 5" drillpipe. MWD 32fini2,do, Page I of I0 5/2/97 / 2:37 PM H~Y-O~-97 03:50 PM UNOCAL Middle Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 I i 1. R/i~'~-d c~men'~"7~,--29 lb/ft KC-Buttress'Liner. Casing_: 7" 29 #/FT L-80 Buttress TKC Coupling Collapse 7,030 psi, 8,160 Burst psi, Tensile 676 Kips Torque RTG of Coupling: 24,300 fi-lbs max; 15,900 R-lbs optimum, 7,400 fi-lbs min. General Information: Top Depth: Bottom Depth: Pre~dous CSG: Hole Size: M.W.: 2,700' MD/t,893' TVD 7,000' MD/4,089' TVD 94/$" @ 3,015' MD 8-I/2" 9.4 PPG (Estimated) _Equ_jpment Requirements: i 9-518" RECEIVED 13-3/8" · Float Shoe: .tVIAY 5 1997 ~Jas~.Oil & Gas Cons. CommiS~v~' ~lioraga Baker Type V Bladed Float Shoe. "Baker-Lock" on the end of I st casing jt. Float Collar: Baker Double Valve Float Collar. "Baker-Locked" on the end of the second casing jr. Landing Collar: Baker Type I Landing Collar "Baker-Locked" on the bottom of the third casing joint. Couplings: Baker Locked Plugs: Casing wiper plug and drillpipe wiper plug. Note: ail plugs and float equipment are PDC drillable. CSG hanger: Need 7" Kvaemer spacer sleeve for wellhead when tubing hanger is nm. CSG EQ: 4-1/2" IF X 7" Buttress Circ. Swedge. Frank's fill-up tool. APl modified pipe dope. Liner Hanger: 9-5/8" 53.5 lb/ft x 7" 29 lb/ff B.O.T. HMC Liner Hanger ZXP Liner Top packer with C-2 Setting Sleeve with Extension Setting tool--non-rotating. Note: Since this ZXP LTP has the C-2 Setting Sleev, e,, ,~e_do not have the ability., to rotate the 7" casing~ MWD 32fin12,do¢ Page 2 of 10 5/2197 / 2:37 PM I'I~Y-02-97 FRI 03:50 Pll v, ub/1~ UNOCAL Middle Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 c..c. Rpacities: 7-~' CSG -[ 0.0371 bbl/ft _8-1/27.~. O.H_ ?~.7.7~ .............. [ 0.0226 bbl/ff 9-5/8" x 7" 0.02317 bbl/ft 9-5/8" x 5" DP 0.0465 bbl/f~ 5" DP [ 0.01776 bl~l/ft Excess Requirements: 150 % excess in open hole. No excess in the float track or in 9-5/8" x 7" annulus. Pump the entire 1,200 sx of cement you have on board slur_.ry_,D~ta_.(A..~tua!.data should be checked with final lab test)3_ Total volume: Total sacks: Slurry Weight: Cement Yield: Mix Water: Total Liquid: Thickening Time: Cement Composition: Liquid Additives: 1,836 ft~ / 326 BBLS ~1,200 14.0 lb/gal 1.53 ft~/sk Filtered Inlet Water 7.78 gal/sk 4:21 "G" neat D029 LCM ~. 0.266% BWOC D145A Dispersant ~ 0.030 gal/sk D300 Fluid Loss ~ ,85 gaI/sk PAKC359 .I00 % BWOC BHST: BHCT: 120 F 120 F MWD 32fin12.~lo¢ Page 3 of 10 $/2/97 / 2:37 I'M M~Y-02-97 FRI 03:51 ?, UU/l~ UNOCALe Middle Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 ....... 1 lnll ,Ill ....... cen~i/t-Proce~ture: Note: Verify all depths and volmnes before cement job. Rathole volumes were not figured imo calculations. RU GBR casing Crew, Have GBR test equipment aud power packs before RU to run casing. Have two Frank's fill-up tools on board. Have casing crew supervisor document stabbing board inspection on UNOCAL form and Vendor Pre-job Checklist. Note: Check fill-up tool robber element. , RU Circ. swedgedFrank's fill-up tool. RU the 500 ton bails, 350- Ton BJ slip-tyPe elevators, and 350 Ton spider slips. Note: Verify compatibility of manifold with both plugs prior to RU. . . PU the first three casing joints of easing (80 ff float track); and fiI1 up casing. PU 40-50 and verify flow path through float equ/pment. Note: Verify casing wiper plug is installed on running tool. RIH with 7" 29 lb/fl L-80 Liner Baker Float Shoe 1 JT 7" 29Ib/fl casing Baker Float Collar 1 JT 7" 29 lb/it casing Baker Landing Collar 7" 29 lb/it L-80 TKC Buttress casing Baker HMC 9-5/8" x 7" Liner Hanger Baker ZXP Liner Top Packer with 02 Setting Sleeve Extension. 5" Vr/llpipe MAY .5 1997 ~il & Gas Cons..i;o. mrals,s~u~ Space-out so that the T.O.L is at ? 2,700', Establish circulation and obtain PU and SO weights. PU }lOT's liner hanger cementing head. RU cementing lines and pressure test to 500psi/5,000 psi. MWD 32fin12.doe Page 4 of 10 512/97 / 2:37 PM . 1", U(/15 UNOCAL ) Middle Ground Shoal Field Baker $$32 Grass Roots Revised Drilling Program Revised $/2/97 Revision $$3 . PUmp th~"f61It,~iifig Cement Schedule: Volume Mud Weight Fluid Pumped ......... (_B.BLS) (PPG) 30 I 1 Mudpush XT 203 14.0 Cement Slurry (includes 80 ft float track) 10 8.5 Filtered inlet Water *** [ Drillpipe Wiper Plug 47 9.4 Displacement with Dowell Cement ~hit ........ **¢ ...................... .D..P. plug contacts Casing Wiper Plug 159 9.4 Displacement with Dowell Cement Unit , 10. 11, 12. Note: To avoid setting the liner hanger prematurely, thc intemal pressure cannot exceed 2,000 psi over the annulus pressure during cement job. Reciprocate the pipe during pumping of the cement --if possible, When FIW rounds the comer pipe will become heavy, stop reciprocating. When cement is halfway up the annulus begin reciprocating casing in i0-15 ft strokes. If hole becomes sticky at any point, space-out liner hanger. 'b) Verify DP plug indicator has been activated. c) Monitor pressures to verify DP plug contacts casing wiper plug. d) Reset stroke counter as soon as DP plug contact wiper plug. Bump Plugs in landing collar. Do not exceed 3 BBLS over calculated d'_tsplaeement. Note: If plugs don't bump discuss options with office. To get off hanger, set casing on bottom and rotate 6 tums to the right. Pressure up drillpipe to 2,500 ~ and set liner hanger. While ma/ntaining drillpipe pressure, set down 20,000 lbs on the liner hanger to engage slips. Increase drillpipe pressure to 4,000 psi; and shear hydraulic pusher tool. This will set ZXP ___ liner top packer. Bleed off all pressures, Rotate drillpipe 6 right-hand roms at the tool and release C-2 Setting Tool. MWD 32fin12.doc Fage $ Of 10 5/2/9712:37 PM I1AY-U2-~Y Fl<l U3: 51 1'1t [-'i u~/,[ 13. 14. 15. UNOCAL ) Pressure up drillpipe to ~. Middle Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 PU unit seals of C-2 Setting Tool are our'b'fline3~ ' Oi~serve pressure drop while pulling seals out. Reverse circulate out excess cement if plugs bump. Note: IfpIugs do r~ot bump, POOH with drillpipe and PU clean-out assembly. Continue to POOH and LD setting tools. t'dAY ,5 !997 Ala$~ Oil .& Gas Cons. k;ommiss,, MWD ~2fin12,;lo~ Page 6 Of 10 5/2/97 / 2:37 PM llR¥-U;/-~ ( [' K [ U~: b 1 VFI Y, UU/1,.1 UNOCAL ) Imll I m III Drill 6" Hole from_7.,000' to 10~37' ..... Note: Clmnge top pipe rams to VBR's Middle Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 1. LD 7,000' ofS" drillpipe and PU 3-1/2" drillpipe. . Make-up the foHo~ing.asS_erm~blj_ 6" sec. DBS FM2643 PDC bit jetted at 4-3/4" M1-XL Motor set at AKO = 1.0 5-7/8" String stabilizer Crossover Sub 4-3/4" Navitmek MWD (Non-mag drill collar ) Hang-off sub Multiple Bypass Circ. Sub (Weathefford) 3-1/2" HWDP 4-3/4" Houston Engineering Jars (Jar up/Bumper Sub Down) 3-1/2" HWDP , 3,000' of 3-1/2" 13.30 lb/fi drillpipe (Weatherford) 4,367' of 3-1/2" 15.5 lb/fi dritlpipe (Weatherford) 2,700' of 5" 19.5 lb/ft drillpipe (UNOCAL) RIH with BHA and tapered string and tag cement. Drill cement to landing collar. 4. .Pressure test casing and liner top packer to 3,.5.00 psi for 30 minutes. , Note: use chart recorder and monitor the volume required to pressure up casing. DrilI landing float track and I 0' of new formation. 6, Obtain pick-up, slack-off, and torque values and record on morning report. We need to accurately predict future torque and drag values. 7. Perform Leak-OffTest and fax results into office. 1 Note: Call office if LOT is below 0_..75~psi/ft. Drill 6" hole from 7,000' to 10,337'. 9. Discuss circulating bottoms up and wiper trip with office prior to POOH. 1 O, POOH with BI-IA. MWD 32fin12,0o, Page 7 of 10 5/2/97 / 2:37 PM ~flY-02-97 FRI 03:51 ?~ ~', ~u/~ UNOCALe Middle Ground Shoal Field Baker #32 Grass Root~ Revised Drilling Program Revised 5/2/97 Revision #3 ..... '9-. Run Drillpip'6u'C~iiiveyed Wireline Logs: GR/DIL/CNL/DEN I, Hold pre-job safety meeting and discuss use of nuclear tool with rig personnel. 2. RU Schlumberger WLU. 3~ MU the following wi_reline logging tools: DIT-E (Phasor Induction with SP) LDT (Litho-density) CNT-H (Compensated Neutron) GR (Gamma Ray) AMS/TCC (Head Tension) Total 32.24 ft 17.36 ft 7.25 f~ 5.0 ft 12.43 f~ 74.28 ft Note: Ensure Schlumberger tums on the S.P. Log. SP is part of the DIT-E tool. 4. RIH with logging tools to 7,000'. 5. PU side-door entry-sub 6. RIH with Schlumberger's wir¢linc and wet conn~t; stab into wet connect. Note: The wet connect may have to be pumpeA down. Also report ifwireline ran all the way to bottom. Power up tools and ensure al1 equipment is functional. 1 9. 10. RIH logging 6" hole. Do not tag bottom with tools. Log 6.0" hole. Log ~ !~800 ft/hr. POOH with wireline and then logging tools. 11. RD SWS wireline unit. 12. Fax logs into drilling department 6~ 263-7562. MWD 32Iln12,doe Page $ Of 10 5/2/97 / 2;.~7 PM UNOCAL ) Middle Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2197 Revision #3 IV. Run 3-1/2" Liner, Liner Hanger, and Liner Top Packer Liner: 3-1/2' 9.2 lb/ft CS Hydril L-80 tubing Collapse psi, Burst psi, Tensile Kips Make-up Torques: 3,000 fi-lbs General Information: Total Depth: Previous CSG: Liner Lap: Hole Size: M.W.: 10,337' ~M.D/5,7I 8' TVD 7" liner ~ =7,000' MD I50' 9,4 PPG (Estimated) Note: Do not set liner hanger in a high dog leg section. Equipment Requirements: Float Shoe: Baker V Set Shoe on the end of first casing jr. 13- 8" ~;. 3-1/2" Float Collar: Baker Double Valve Float Collar. Landing Collar: Baker Landing Collar "Baker-Locked" on the pin end of a casing jr.. Plugs: Plug Baker 5"x 3" Drillpipe Wiper Plug and Baker Type I 3-1/2" Liner Wiper Centralizers: None Liner Hanger: Baker HMC Rotatable, Tandem Cone, Hydraulically Set, 5" 151b/ff x 7" 29 lb/fi, Liner Hanger with lower PBR. HR-ZXP Liner top packer Setting Sleeve: Baker HR Setting Sleeve with 6' Tie-Back Extension and. RS Nipple. 5" Buttress pin. Setting Tool: Baker HR Setting Tool with RS pack-offSeal Assembly, 3q/2" IF Box. c_C_~pacities: 3-1/2" TBG i 0.0087 BBL/fi 1 3-1./2" X 7" 29 lb/fi i 0.0252 BBL/fi , , ,, ........... : ......... ~.__ _ 3-1/2" x 6" OH ] 0.0231 BBL/ff I 3-1/2" 13.3 lb/ff DP I 0.00742 BBL/ft MWD 32fin12.doc Page 9 of l0 5/2/97 / 2:37 PM ~RY-02-97 FRI 03:52 ?~ ~,t~/id UNOCAL Middle Ground Shoal Field Baker #32 Grass Roots Revised Drilling Program Revised 5/2/97 Revision #3 t3-1/2" 15.5 lb/fi DP 0,00658 BBL/ft i 5" 19.0 lb/ft DP 0.01776 BBL/ft Excess Requirements: Tail Slurry: 300 % excess in open hole. No excess in the 5" x 7" annulus, No excess in the float track. Tai!.S!_u_r~.D_a_t_a (Actual data should be checked with final lab test): Total volume: Total sacks: Slurry Weight: Cem~t Yield: Total Liquid Kequired: Thickvnmg Time: Cement Composition; Liquid Additives: BHST: BHCT: 1,756,5 aD / 312.8 BBLS 1,340 sx 15.0 lb/gal 1.31 fl'*/sk 6.25gal/sk: 4 hr:49 nm "G" neat D1 I0 0.020 GPS PAKD 145A 0.020 GPS PAKD300 1.100 GPS I35 F 125 F Anchorage MWD 32fm12.doc Page 10 of 10 5/2197 / 2;37 PM DHY-U?-U~ l~K~ U:5:bk' k'F1 UNOCAL imlll ii .......... RKB --$6' Rig Floor to Wellhead Kvaerner SMS Wellhead BAKER PLATFORM WELL # 32 PROPOSED MONOBORE COMPLETION 1", 131 13 CASING AND TUBING DETAIL SIZE WT GRADE CONN TOP BOTTOM 32" Inside Conductor 296 13-3/8 68 K-55 BTC 792 9-5/8 47 L-80 BTC 73 9-5/8 53.5 P-110 BTC 73 3,015 7" 29 L-80 TKC-BTC 2,700 7,000 3A/2 9.2 L~80 CS Hydril 6,850 10,337 3-1/2" 9.2 L~80 CS Hydril 51 6,840 JEWELRY DETAIL NO. ITEM DEPTH Kvaemer Tubing Hang~r (AB TC4S 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") Baker 7" X 5" HIVlC liner Hanger and HC-ZXP Liner Top Packer with PBI~ Seal-assembly run on tubing string. Baker 9-5/8" x 7" HMC Liner Hanger and ZXP Liner Top Packer. PERFORATION DATA TOP BTM ZONE SPF DATE COMIVfENTS Actual depths will be fletermined from open-hole logs PDTD = 10,257' MAX HOLE ANGLE -- 60~ ~ 1,515' B32PR2.DOC REVISED: 5/02/97 DRAWN BY: MWD Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7660 UNOCAL Dale A. Haines Drilling Manager Monday, April 28, 1997 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Wondzell' As requested in your approval of Baker 32, I am sending the weekly summary of Baker 32 drilling operations. If you have any questions, please call Mitch Damm at 263-7679. Sincerely, Dale A. Haines Drilling Manager /leg ALASI~ OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 10, 1996 G. Russell Schmidt, Ddlling Manager Union Oil Company of California (Unocal) P O Box 196247 Anchorage, AK 99519-6247 Re: Company Permit # Surf Loc Btmhole LOC Chakachatna MGS Baker 32 Unocal 96-56 1987'FNL, 478'FWL, Sec 31, T9N, R12W, SM 824'FSL, 1775'FWL, Sec 19, T9N, R12W, SM Dear Mr. Schmidt: EnClosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Your request for a diverter vadance 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 ddlling 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. Since~ J. David Norton, P. E. Commissioner BY ORDER OF THE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl ..... STATE OF ALASKA ~~,¢¢ ~v ALASKA OIL AND GAS CONSERVATION COMMISSION .~ Cj)~'~ i) APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: x 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: x 118 RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Chakachatna MGS 4. Location of well at surface 8. Well number Baker Pit Leg 4, Slot 8, 1987' FNL, 478' FWL, Sec. 31, T9N, Rt2W, SM Baker 32 At top of produc'"--'"----~ive interval 9. Permit number Pending approval At effective depth ~ ~ 10. APl number 0 R I L 50- Pending Assignment At total depth 11. Field/Pool Middle Ground Shoal undefined 12. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural 240' 32" Driven 296' RKB (76' BML) Conductor Surface Intermediate Production Liner ~, (~" " ~' ' .... Perforation depth: measured ~ [; .... L= ~ 'v i'... true vertical ,. ¢ - Tubing (size, grade, and measured depth) /}~2:'.'.i-:2 ~'~;: Packers and SSSV (type and measured depth) '~\: ': ::;::; :; '; 13. Attachements Description summary of proposal: x Detailed operations program: x BOP sketch: 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: 17' I herebyC6e[tify/~at the"~Jl/I?. ,(\f, lf°r~g°ing ~ (~ ~-~ is true and cb~.ect to the best of my k%dge. ~ ' ' ("2~. (% S~ ned . 'g : ~.~~ _ ~/..~.,vw.-,,~J_,~,J Title: ~i~) &i,(,,~,~ A,~ .Q~ /~A3 kC---~.-.~-~ Date: FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval~).. Plug integrity BOP Test Location clearancei /~ '- Mechanical Integrity Test Subsequent form required 10- /-~--~ Approved ~;opy Original Signed By Tuckerman Babcock I/"/! Approved by order of the Commissioner Commissioner Date ~[ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Baker Well #32 March 8, 1996 Drilling Hazards: Lost circulation zones: Low pressure zones: Over pressured zones: Shallow gas zones: 4750' - 5800' (150 - 300 bbl/day) Baker 30 0' - 5718' TVI) None 0' - 5718' Time Est. Cum Time .5 .5 2 2.5 2 4.5 3.5 8 1 9 1.5 10.5 10.75 21.25 1 22.25 1 23.25 2 25.25 .75 26 1 27 .75 27.75 .5 28.25 Preliminary Procedure: 1. MIRU, Leg #4, Conductor #8. 2. Drill 17-1/2" hole to 13-3/8" casing point of+/- 800'. 3. Run and cement 13-3/8" casing. Install 13-5/8" BOP. 4. Drill 12-1/4" hole to 9-5/8" casing point of+/- 3000'. 5. Run open hole log LWD MAD pass. 6. Run and cement 9-5/8" casing. 7. Drill 8-1/2" hole to 7" casing point at +/- 10357'. 8. Run open hole log LWD MAD pass. 9. Run and cement 7" casing. 10. Clean out 7" casing. 11. Change well over to completion fluid. 12. Land 3-1/2" tubing. 13. Nipple down BOP. Install and test tree. 14. RU to perforate. Depth Baker32 Depth vs. Days -2 -4 -6 --"-- Baker #32 AFE -8 -10 -12 5 10 15 20 25 30 35 40 45 50 Days BAKER PLATFORM WELL # 32 MDDLE GROUND SHOALS SCHEMATIC PRIOR TO COMPLETION J L 32" Structural Casing ~ 296' RKB (76'BML) X 13-3/8" 68# K-55 BTC Surface Casing ~ 800' 9-5/8" 53.5# L-80 BTC Intermediate Casing @ 3000' 7" 29# L-80 BTC Production Casing @ 10357' BAKER PLATFORM WELL # 32 MIDDLE GROUND SHOALS SCHEMATIC AFTER COMPLETION COMPLETION DESCRIPTION 1) Single 3-1/2" 9.2# L-80 BTC Tubing 2) SCSSSV ~ +/- 300' 3) Sliding Sleeve 4) Production Packer ~ +/- 6800' md 5) Through Tubing Perforations as Required RKB= 118' 32" Structural Casing ~ 296' RKB (76'BML) 13-3/8" 68# K-55 BTC Surface Casing @ 800' 9-5/8" 53.5# L-80 BTC h~termediate Casing ~ 3000' 7" 29# L-80 BTC Production Casing ~ 10357' BAKER PLATFORM WELL # 32 MIDDLE GROUND SHOALS ROTARY KELLY BUSHING (RKB) Elev. 118' DRILL DECK LEVEL Elev. 78' PRODUCTION DECK LEVEL Elev. 62' SEA LEVEL (MLW) Elev. 0' MUD LINE Elev. -102' 32" Structural Casing ~ 296' RKB (76'BML) X 13-3/8" 68# K-55 BTC Surface Casing @ 800' 9-5/8" 53.5# L-gO BTC Intermediate Casing ~ 3000' 7" 29# L-80 BTC Production Casing ~ 10357' WELL: BAKER #32 FIELD: 1. MUD WT. I 8.8 PPG 2. MUD WT. II 9.4 PPG 3. MUD WT. III 9.4 PPG CASING DESIGN MIDDLE GROUND SHOALS DATE: 8-Mar-96 INTERVAL DESCRIPTION CASING SIZE Bo'FrOM TOP LENGTH WT__..~ GRADE THREAD I 13-3/8" 800 56 744 68 K-55 BTC TVD 793 56 2 9-5/8" 3000 56 2944 53.5 L-80 BTC TVD 2039 56 3 7" 10357 56 10301 29 L-80 BTC TVD 5718 56 DESIGN BY: P.A. RYAN M.S.P. TENSION MINIMUM WEIGHT TOP OF STRENGTH W/O BF SECTION TENSION LB.__~S LB~S J 000 LBS 50592 50592 1069 157504 157504 1329 298729 298729 746 271 psi 697 psi 1956 psi 21.13 8.44 2.50 COLLAPSE COLLAPSE PRESS @ RESIST. BO'FI'OM W/O TENSION PSI.....~* PS__[I 284 1950 793 6620 2223 7020 CDF 8.88 8.35 3.18 BURST MINIMUM PRESSURE YIELD PSI** PS~I 459 3450 1287 7930 1287 8160 BD~F 7.52 6.16 6.34 NOTES: M.S,P. is .442 psi/ft times TVD less .1 psi/ft gas gradient. * Collapse pressure is calculated by drilling mud weight less a .1 psi/ft gas gradient. ** Burst pressure is calculated; (BHP @ depth next csg X TVD next csg) X (0.5 half evacuated). Baker Platform Well # 32 Pressure Calculations Baker Platform Well # 32 Middle Ground Shoals March 8, 1996 Hole Section 1 Depth Interval: 0'-800' 17-1/2" hole size 13-3/8" casing to 800' Mud weight: Shoe depth (13-3/8"): Est. fracture gradient of 13-3/8" shoe: Depth of next hole section (12-1/4"): BHP gradient: Gas gradient (assume worst case): 9.4 ppg=0.49 psi/ft 800' MD/793' TVD 0.80 psi/ft 3000' MD/2039' TVD 0.45 psi/fi 0.0 psi/ft Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - Hydrostatic Pressure MSP=BHP - (3/4 mud + 1/4 gas) MSP=(2039'x.45 psi/fO - ((.75(2039'x0.49 psi/fi)) + (.25(2039'x0.0 psi/fi))) MSP= 168 psi Therefore, the hydrostatic pressure at the 13-3/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 13-3/8" shoe, if a constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 13-3/8" casing depth (Hpcsg). Hpsh= MSP + Hpcsg Hpsh= 168 + (793'x0.49 psi/fi) HPsh= 557 psi This (Hpsh --- 557 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 557 psi < Fpsh = 0.80 psi/ft x 793' = 634 psi. Baker Platform Well # 32 Pressure Calculations Hole Section 2 Depth Interval: 800'-3000' 12-1/4" hole size 9-5/8" casing to 3000' Mud weight: Shoe depth (9-5/8"): Est. fracture gradient of 9-5/8" shoe: Depth of next hole section (8-1/2"): BHP gradient: Gas gradient (assume worst case): 9.4 ppg=0.49 psi/ft 3000' MD/2039' TVD 0.80 psi/ft 10357' MD/5718' TVD 0.45 psi/ft 0.0 psi/fi Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - Hydrostatic Pressure MSP=BHP - (3/4 mud + 1/4 gas) MSP=(5718'x.45 psi/fi) - ((.75(5718'x0.49 psi/fi)) + (.25(5718'x0.0 psi/fi))) MSP= 472 psi Therefore, the hydrostatic pressure at the 9-5/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 9-5/8" shoe, if a constant BlIP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 9-5/8" casing depth (Hpcsg). Hpsh= MSP + Hpcsg Hpsh= 472 + (2039'x0.49 psi/fi) HPsh= 1471 psi This (Hpsh = 1471 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 1471 psi < Fpsh = 0.80 psi/fi x 2039' = 1631 psi. File name: 32ca12.doc Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7676 UNOCAL G. Russell Schmidt Drilling Manager Tuesday, March 12, 1996 Dear Mr. Johnston: Mr. David Johnston Commissioner AOGCC 3001 Porcupine Drive Anchorage, AK. 99501-3192 Please find enclosed an Application for Sundry Approvals (Form 10-403) and supporting documentation for the Baker Platform well #32, amending the application for Permit to Drill (Form 10-401) that was submitted February 29, 1996. The timing to spud this well is approximately April 11, 1996 upon the completion of scheduled workovers. After an internal company review of the well design and completion method, the Baker #32 proposed well design has changed sufficiently to warrant amending the aforementioned Permit to Drill. The proposed changes in design are specifically as follows: o Drilling an 8-1/2" hole from 9-5/8" casing point at 3,000' MD to total depth of 10,357' MD. 2. Run and cement 7" casing to total depth of 10,357' MD. 3. Increasing 9-5/8" casing weight from 47# to 53.5#. , Changing the completion tubing from 2-718" to 3-1/2" 9.2# L-80 BTC. Letter David Johnston Page 2 March 12, 1996 The above changes will result in a more economic well while not compromising the integrity of the design. If you should have any questions regarding this application please contact Pat Ryan (Senior Drilling Engineer) assigned to this project. Thank you for your attention to this matter. Enclosure Sincerely, G. Russell Schmidt Drilling Manager PAR/par STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive ~Anchorage Alaska 99501-3192 TI~E APPLICATION OF UNION ) OIL COMPANY OF CALIFORNIA) for an order granting an exception ) to spacing requirements of Title ) 20 AAC 25.055 to provide for the ) drilling of the Baker No. 32 ) development gas well. ) Conservation Order No. 378 Union Oil Company of California Baker No. 32 March 26, 1996 IT APPEARING THAT: Union Oil Company of California (Unocal) submitted an application dated March 6, 1996 requesting exception to 20 AAC 25.055(a)(4) to allow drilling the Granite Point State No. 54 development gas well to a producing location that is closer than 1500 feet to a drilling unit boundary. 2. Notice of opportunity for public hearing was published in the Anchorage Daily News on March 8, 1996 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: o The Unocal Baker No. 32 well as proposed will be a deviated hole drilled from a surface location 1987' from the north line and 478' from the west line of Section 31, T9N, R12W, Seward Meridian (SM) to a bottom-hole location 824' from the south line and 1775' from the west line of Section 19, T9N, R12W SM. 2 Unocal is the owner of all off setting spacing units. 3. An exception to 20 AAC 25.055(a)(4) is necessary to allow drilling ofthis well. CONCLUSION: Granting a spacing exception to allow drilling of the Unocal Baker No. 32 well as proposed will not result in waste nor jeopardize correlative rights. Conservation Order No. ', , March 26, 1996 Page 2 NOW, THEREFORE, IT IS ORDERED: Unocal's application for exception to 20 AAC 25.055 for the purpose of drilling the Baker No. 32 well is approved as proposed. DONE at Anchorage, Alaska and dated March 26, 1996. Dav~:d W' Jgtmst°n' ChX~i~an ~om~ission Alask~rvation J. David Norton, P.E., Commissioner Alaska Oil and Gas Conservation Commission kerman Babcock, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an apphcation for reheating. A request for reheating must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a hohday or weekend, to be timely filed. The Commission shah grant or refuse the application in whole or in part within 10 days. The Commission can refuse an apphcation by notacting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon reheating, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the apphcation for rehearing was filed). Unocal Alaska Resource''~ - Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL August 19, 1998 Dear Mr. Hartz: Mr. Jack Hartz Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Baker Platform Well #32 -- APl # 50-733-20473-00~ Form 10-421, Gas Well Open Flow Potential Test Report Attached is Form 10-421 for the modified isochronal flow test on Baker Platform, Well #32 conducted on July 25, 1998. Please direct any questions to Sam Darkwah at 263-7864. Sincerely, Sam A. Darkwah Reservoir Engineering Technician SAD:csw Attach: Log-Log Plot of Test Data RECEIVED AU6 21 1998 Alaska 0il & Gas Cong. C0mrnissio~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Re-Entry O Deepen O Service O Development Gas O Sing,e Zone O Multiple Zone O 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Union Oil Company of California (Unocal) 118' RKB above MSL feet Middle Ground Shoals 3. Address 6. Property Designation Undefined P.O. Box 196247, Anchorage, AK 99519 ADL 17595 4. Location of well at surface Baker Pit Leg //4, Slot #8 7. Unit or property name I 1 .Type Bond (SEE 20 ACC 25.025) 1987' FNL, 478' FWL, Sec. 31, T9N, R1 2W, SM Chakachatna MGS AK Statewide Oil & Gas Bond At top of productive interval '(3000' MD/2039' TVD) 8. Well number Number 168' FNL, 729' FWL, Sec. 31 TgN, R12W, SM Baker 32 U62 - 9269 At total depth {10357' MD/5718' TVD) 9. Approximate spud date Amount 824' FSL, 1775' FWL, Sec. 19, TgN, R12W, SM 4/11/90 $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 lineI Baker 23 1600 feet 1.3' @ 370' MD feet 5106 10,357' MD/5718' TVD feet 16. To be completed for deviated wells 17. Anticipated Pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 320 feet Maximum hole angle 60 deg Max surface 1955 psig At total depth {TVD) 2527 psig 18. Casing progra \ 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" t 3-3/8" 68 K-55 BTC 744 56 56 800 793 1400 cf 1 2-1/4" 9-5/8" 47 L-80 BTC 2944 56 50 3000 2039 2350 cf 8-1/2" 7" 29 L-80 BTC 6944 56 56 7000 4039 2200 cf 6" 2-7/8" 6.4 L-80 BTC 3557 6800 3939 10357 5718 1350 cf 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 240 32" Driven 296 RKB (76' BML) Surface Intermediate Product,on L ,AP, 0 1 10'SS Liner Perforation depth: measured ~,im'~t'~ (])i~ ~ 0~ ,_,~J{'lb. f ....... i'~ true vertical '~J'~Oh 0 'l'~ ~] ~ 20. Attachments Filing fee r~ Property plat 0 BOP Sketch r'~ Dive,or Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs dept~ plot ~ Refraction analysis O Seabed report O 20 AAC 25.050 requirements ~ that the foregoing i~kr~e~d corregf~9 t~ ~t of ~¢~nowledge 21. I hereby certify~ ~ · , ~ Signed G. Russell Schmidt----~~'~ f~~tle Drilling Manager Date 02/22/96 Commission Use Only Permit Number __~ I50- 73~- 2 0 ~~ ~/~ --~ ~ for other requirements Conditions of approval Samples required O Ye, ~ No ~udlogrequired O Y es~ No Hydrogen sulfidemeasures O Yes ~ NO Directional su~ey required ~ Yes O ~o' Required working pressure for BOPE ~¢M; m3M; O SM; O 1OM; O 15M o,,,~: O~GI~ SIGNE by the order of ~__/~ __~ App .... d by J, Da~ N~0n, P, E. Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate Unocal North Ameri~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region February 23, 1996 Mr. David Johnston Commissioner Alaska Oil & Gas Conservation Commissioner 3001 Porcupine Drive Anchorage, AK. 99501-3192 Dear Mr. Johnston: Please find enclosed apphcation for Permit to Drill (Form 10-401) for the Baker Platform well #32. The timing to spud this well is approximately April 11, 1996 upon the completion of scheduled workovers. UNOCAL is requesting that the AOGCC waive the diverter system requirement on both the (32") structural and (13-3/8") surface casing strings. This waiver request is similar to our December 1995 request for well #31 at the Baker Platform which was subsequently approved by the AOGCC. As outlined in the well procedure, UNOCAL is intending to drill out the 32" structural casing to +800' with a flow nipple then install a 13-5/8" 5M BOPE stack on the 13-3/8" casing that will be cemented at +800' to surface. The 13-3/8" casing will then be drilled out to a depth of+3000' and 9-5/8" intermediate casing will be cemented at that depth. UNOCAL has selected the casing points for the 13-3/8" at +800' and the 9-5/8" at +3000' to be areas of competent formations. No gas bearing zones are evident above +800', based on offset well data. It is anticipated that the minimum formation fracture gradients at both shoe depths to be 0.80 psi/fi. UNOCAL's recent experience in the Middle Ground Shoals Field at the Baker and Dillon Platforms and elsewhere in the Cook Inlet (see Leak Off Test Data) has demonstrated true fracture gradients ranging from 0.75 - 0.94 psi/fi. In the Baker #32, maximum surface pressure (MSP) expected while drilling below the 13-3/8" surface casing will be far less than the anticipated fracture pressures. Since the casing shoes will not break down in a well kick situation and the setting depths are in competent formations, UNOCAL believes these are prudent casing designs and warranted operations. Mr. David Johnston February 23, 1996 Page - 2 UNOCAL plans to complete the Baker #32 as a flowing gas completion. If you should have any questions regarding this permit please contact Pat Ryan (Senior Drilling Engineer) assigned to this project. Thank you for your attention to these matters. ~Sincere!y, G. Russell Schmidt Drilling Manager PAR/par enclosure: Baker Well #32 February 18. 1996 Drilling Hazards: Lost circulation zones: Low pressure zones: Over pressured zones: Shallow gas zones: 4750' - 5800' (150 - 300 bbi/day) Baker 30 0' - 5718' TVD None 0' - 5718' Time Est. Cum Time .5 .5 2 2.5 2 4.5 3.5 8 1 9 1.5 10.5 5 15.5 I 16.5 1 17.5 5.75 23.25 1 24.25 I 25.25 2 27.25 .75 28 1 29 .75 29.75 .5 30.25 Preliminary Procedure: 1. MIRU. Leg gl, Conductor #8. 2. Drill 17-I/2" hole to 13-3/8" casing point of+/- 800'. 3. Run and cement 13-3/8" casing. Install 13-5/8" BOP. 4. Drill 12-I/4' hole to 9-5/8" casing point of+/- 3000'. 5. Run open hole log LWD MAD pass. 6. Run and cement 9-5/8" casing. 7. Drill 8-1/2" hole to 7' casing point at +/- 7000'. 8. Run open hole log LWD MAS pass. 9. Run and cement 7" casing. 10. Drill 6" hole to 2-7/8" casing point at +/- 10357'. 11. Run open hole log LWD MAD pass. 12. Run and cement 2-7/8' liner f/10357' - 6800'. 13. Clean out 2-7/8" liner. 14. Change well over to completion fluid. 15. Land 2-7/8" tubing. 16. Nipple down BOP. Install and test tree. 17. RU to perforate. Depth Baker32 Depth vs. Days -4 -6 -8 -10 -12 5 10 15 20 25 30 35 40 45 50 --'- Baker #32 AFE Days BAKER PLATFORM WELL # 3 2 MIDDLE GROUND SHOALS SCHEMATIC PRIOR TO COMPLETION 32" Structural Casing ~ 296' RKB (76'BML) ~, 13-3/8" 68# K-55 BTC Surface Casing(~ 800' ~. 9-5/8" 47# L-80 BTC Intermediate Casing ~, 3000' 7" 29//L-80 BTC Intermediate Casing (~ 7000' L 'x 2-7/8" 6.4# L-80 BTC Liner F/10357' - 6800' BAKER PLATFORM WELL # 3 2 MIDDLE GROUND SHOALS SCHEMATIC AFTER COMPLETION COMPLETION DESCRIPTION 1) Single 2-7/8" 6.4# L-80 SCBT 2) SCSSSV ~ +/- 300' 3) Sliding Sleeve 4) Permanent Production Packer 5) Through Tubing Perforations as Required RKB= 118' 32" Structural Casing ~ 296' RKB (76'BML) ~. 13-3/8" 68# K-55 BTC Surface Casing ~ 800' ~ 9-5/8" 47# L-80 BTC Intermediate Casing ~ 3000' 7" 29tt L-80 BTC Intermediate Casing @ 7000' 2-7/8" 6.4/t L-go BTC Liner F/10357' - 6800' J iStructure : BAKER Platform Well : Bo-S2 i Field : Middle Ground Shoals Locolion : Cook '.nlef, Alaska i WELL PROFILE DATA Point MD Inc Dir r, vD hlorth East Deg/!O0! i'fie on 0 0.00 310.00 0 C 0 jKOP 320 0.00 310.00 320 C 0 C.OOi ~egin Turn to Target 420 5.25 310.00 420 3 -4 5.25i fend of Build 1515 60.06 9.46 1315 550 40 5.25i Forg~t 7332 60.06 9.46 4218 5522 869 0.00! iend of Hold 10338 60.06 9.46 5718 8091 1297 O.OOi Created by : jones D~te plotted : 22-Feb--96 Plot Reference is 13~32 Option ~6 Vcrs.#2. Coordinates ore in feet reference slot #4-8. True Vertical Depths ore reference wellhead. --- Baker Hughes INTEO .... East --> 600 0 ,~00 1200 1800 I I I I ~ I I I I I _8400 _ _7800 7200 _6600 _ 6000 _5400 _ _4800 - 0 Tie on End of Hold t Kick off Point 500 ~13.74 ~23.88 ~.~44.64 "%, ;5.08 End - - 3~_ .4200 Z _3600 0 _3000 ---f- _ _2400 _1800 I I I I ! I I I ] II Ii II i I I I ;I I I I I I I I i I I I I I 0 500 1000 1500 2000 2500 3090 3500 4000 4500 5000 552-2 6000 6500 7000 7500 8000 8500 Scale 1 - 250.00 Veriical Section on 8.94 azimuth with reference 0.00 N, 0.00 E from slat #4-8 UNOCAL BAKER Platform Ba-32 slot #4-8 Middle Ground Shoats Cook Inlet, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : Ba32 Option fh5 Vers.#2 Our ref : prop1530 License : Date printed : 22-Feb-96 Date created : 31-Jan-96 Last revised : 20-Feb-96 Field is centred on n60 50 4.803,w151 29 11.941 Structure is centred on n60 50 4.803,w151 29 11.941 Slot location is n60 49 45.236,w151 29 2.299 Slot Grid coordinates are N 2498019.249, E 235187.398 Slot local coordinates are 1987.00 S 478.00 E Reference North is True North UNOCAL BAKER Platform,Ba-32 Middle Ground Shoals,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : Ba32 Option ~6 Vers.#2 Last revised : 20-Feb-96 Measured [nc[in. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect ' 0.00 -0.00 310.00 0.00 0.00 N 0.00 E 0.00 0.00 320.00 0.00 310.00 320.00 0.00 N 0.00 E 0.00 0.00 420.00 5.25 310.00 419.86 2.94 N 3.51 W 5.25 2.36 500.00 8.10 337.36 499.33 10.50 N 8.48 W 5.25 9.06 600.00 12.76 351.13 597.66 27.94 N 12.90 ~ 5.25 25.59 700.00 17.75 357.44 694.11 54.10 N 15.29 ~ 5.25 51.06 800.00 22.85 1.03 787.88 88.76 N 15.62 ~ 5.25 85.26 900.00 28.01 3.36 878.16 131.65 N 13.89 W 5.25 127.89 1000.00 33.19 5.01 964.20 182.39 N 10.12 W 5.25 178.60 1100.00 38.39 6.26 1045.30 240.56 N 4.34 W 5.25 236.96 1200.00 43.60 7.25 1120.75 305.67 N 3.40 E 5.25 302.49 1300.00 48.82 8.07 1189.93 377.18 N 13.04 E 5.25 374.63 1400.00 54.04 8.77 1252.26 454.49 N 24.50 E 5.25 452.78 1500.00 59.26 9.38 1307.22 536.95 N 37.68 E 5.25 536.28 1515.29 60.06 9.46 1314.94 549.97 N 39.84 E 5.25 549.48 2000.00 60.06 9.46 1556.84 964.28 N 108.91 E 0.00 969.49 2500.00 60.06 9.46 1806.37 1391.67 N 180.15 E 0.00 1402.76 3000.00 60.06 9.46 2055.91 1819.05 N 251.40 E 0.00 1836.02 3500.00 60.06 9.46 2305.44 2246.44 N 322.64 E 0.00 2269.29 4000.00 60.06 9.46 2554.97 2673.82 N 393.88 E 0.00 2702.55 4500.00 60.06 9.46 2804.50 3101.21 N 465.13 E 0.00 3135.82 5000.00 60.06 9.46 3054.04 3528.59 N 536.37 E 0.00 3569.08 5500.00 60.06 9.46 3303.57 3955.98 N 607.62 E 0.00 4002.34 6000.00 60.06 9.46 3553.10 4383.36 N 678.86 E 0.00 4435.61 6500.00 60.06 9.46 3802.63 4810.75 N 750.11 E 0.00 4868.87 7000.00 60.06 9.46 4052.16 5238.13 N 821.35 E 0.00 5302.14 7332.30 60.06 9.46 4218.00 5522.17 N 868.70 E 0.00 5590.08 7500.00 60.06 9.46 4301.70 5665.52 N 892.60 E 0.00 5735.40 8000.00 60.06 9.46 4551.23 6092.90 N 963.84 E 0.00 6168.66 8500.00 60.06 9.46 4800.76 6520.29 N 1035.08 E 0.00 6601.93 9000.00 60.06 9.46 5050.29 6947.67 N 1106.33 E 0.00 7035.19 9500.00 60.06 9.46 5299.82 7375.06 N 1177.57 E 0.00 7468.46 10000.00 60.06 9.46 5549.36 7802.44 N 1248.82 E 0.00 7901.72 10337.92 60.06 9.46 5718.00 8091.29 N 1296.97 E 0.00 8194.54 All data is in feet unless otherwise stated Coordinates from slot ~4-8 and TVD from wellhead (118.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 8.94 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL BAKER Platform,Ba-32 Middle Ground Shoals,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : Ba32 Option ~6 Vers.#2 Last revised : 20-Feb-96 Targets associated with this wellpath ' Target name Position T.V.D. Local rectangular coords. Date revised not specified 4218.00 5522.17N 868.70E 20-Feb-96 a!as~ Ojt & 6as Cons. Commission $nchoraSe All data is Jn feet unless otherwise stated Coordinates from slot ~4-8 and TVD from wellhead (118.00 Ft above mean sea level). Bottom hole distance is 8194.58 on azimuth 9.11 degrees from wellhead. Total Dogleg for wel[path is 62.75 degrees. Vertical section is from wellhead on azimuth 8.94 degrees. Declination is 0.00 degrees, Convergence is -1.30 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ UNOCAL BAKER Platform Ba-32 slot ~4-8 Middle Ground Shoals Cook Inlet, Alaska C L E A R A N C E R E P 0 R T by Baker Hughes INTEQ Your ref : Ba32 Option ~A5 Vers.#2 Our ref : prop1530 License : Date printed : 20-Feb-96 Date created : 31-Jan-96 Last revised : 20-Feb-96 Field is centred on n60 50 4.803,w151 29 11.941 Structure is centred on n60 50 4.803,w151 29 11.941 Slot location is n60 49 45.236,w151 29 2.299 Slot Grid coordinates are N 2498019.249, E 235187.398 Slot local coordinates are 1987.00 S 478.00 E Reference North is True North Main calculation performed with 3-D Minimum Distance method Object wellpath PMSS <2180-10280'),,Ba-29,BAKER Platform PGMS <0-9722'>,,23,BAKER Platform GMS <8300-9445'),,7, BAKER Platform GMS (0-7232'),,17, BAKER Platform GMS <0-9645'),,16,BAKER Platform MSS <1039-12500'),,lO,BAKER Platform PMSS <843 - 11275'),,Ba-30,BAKER Platform MSS <711?-8642'),,25,BAKER Platform PGMS <7200-9800'),,25Rd,BAKER Platform MSS <0-9215'),,4,BAKER Platform GMS <0-9250'),,8Rd, BAKER Platform MSS <2008-10314'),,8,BAKER Platform GMS <0-1894'),,MGS501,BAKER Platform MSS (6950-10116'),,15Rd,BAKER Platform PGMS <0-9544'),,15,BAKER Platform GMS <0-10691'),,13,BAKER Platform GMS <0-11600'),,27,BAKER Platform GMS <O-?400'),,6,8AKER Platform PGMS <0-9642'),,20,BAKER Platform MSS ~670-10000'),,12,BAKER Platform MSS (3165-10455'),,14,BAKER Platform GMS <0-11128'),,5,BAKER Platform MSS <6757-9944'~,,9Rd~1,BAKER Platform GMS <0-9760~,,9RcI#2,BAKER Platform MSS <2653'11495'),,9,BAKER Platform MSS <765-9543'),,11,BAKER Platform MSS <5626-10231'),,18,BAKER Platform PMSS <2721-10582'),,28 St#2,BAKER Platform PMSS <1420-4720'~,,8a-28,BAKER Platform Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 17-Jan-94 8~.5 280.0 9300.0 13-Feb-96 1.3 370.0 370.0 24-May-93 4.9 140.0 8900.0 24-May-93 5.0 0.0 220.0 24-May-93 115.1 0.0 10101.5 23-May-93 2.1 370.0 6700.0 6-Jul-94 76.4 750.0 10320.0 3-Jun-93 5.0 100.0 120.0 3-Jun-93 5.0 100.0 120.0 24-May-93 114.1 320.0 320.0 3-Jun-93 4.0 370.0 9300.0 3-Jun-93 4.0 370.0 9300.0 3-Sep-93 110.0 240.0 240.0 3-Jun-93 115.0 100.0 9300.0 3-Jun-93 115.0 100.0 9300.0 23-May-93 111.0 320.0 320.0 24-May-93 107.0 240.0 10101.5 24-May-93 104.2 345.0 345.0 24-May-93 107.2 160.0 10101.5 24-Jan-93 110.5 320.0 9300.0 23-May-93 88.8 280.0 750.0 24-May-93 86.8 675.0 8500.0 23-Ma¥-93 84.0 650.0 650.0 23-Mayo93 84.0 650.0 650.0 23-May-93 84.0 650.0 650.0 23-May-93 80.9 100.0 650.0 24-May-93 71.4 750.0 750.0 21-Mar-94 81.9 725.0 5920.0 3-Dec-93 81.9 725.0 4380.0 PMSS <3617-5479'>,,26 ~C#1,BAKER Platform Ba31 Version ~,,Ba-31,BAKER P(atform 3-Dec-93 8-Feb-96 81 .~ 5.0 725.0 320.0 5120.0 8480.0 UNOCAL BAKER PLATFORM WELL #32 DEPTH INTERVAL MUD TYPE MUD ADDITIVES POTENTIAL PROBLEMS 0- _+800' 17-1/2" HOLE 13-3/8" CASING GENERIC MUD #2 M-I GEL/M-I BAR/SODA ASH/CAUSTIC SODA/LIME HOLE CLEANING/GRAVEL/GAS KICK/LOST CIRCULATION o . . TREATMENTS/PROCEDURES Build spud mud system with prehydrated bentonite in fresh water and filtered inlet water, if possible utilize mud from Baker #31. Drill hole. Adjust viscosity as required. Drill to +_800'. Use all solids control equipment. Raise viscosity if gravel sections are encountered. Run 13-3/8" casing. Evaluate quality of mud and if possible recycle for 12-1/4" interval. Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss (APl) pH 8.8 - 9.4 ppg 44 - 100 sec/qt 10- 15 cps 10- 30 #/100 ft2 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-193 (2/19/96/LD/Ihc) UNOCAL BAKER PLATFORM WELL #32 DEPTH INTERVAL __+800' - __+3000' (2,000' TVD) 12-1/4" HOLE 9-5/8" CASING MUD TYPE GENERIC MUD #2 MUD ADDITIVES POTENTIAL PROBLEMS M-i GEL/M-I BAR/SODA ASH/POLYPAC/SPERSENE/SODIUM BICARBONATE/CAUSTIC SODA/FLO- VIS HOLE CLEANING/TIGHT HOLE/BIT BALLLING/GUMBO CLAYS/HOLE ENLARGEMENT/GAS KICKS/COAL SLOUGHING . . o o . . TREATMENTS/PROCEDURES Use the surface mud to drill the 13-3/8" collar, cement and shoe. Treat this fluid as required to avoid excessive cement contamination. Build additional volume as required with prehydrated bentonite in fresh water and filtered inlet water. Pump viscous sweeps if required by hole conditions. Control density with barite, F.I.W., and solids control equipment. Dump all sand traps as required. Report drill solids analysis on mud check sheet. Use Defoam-X if foaming becomes a problem. Prehydrate all bentonite in fresh water. DM-193 (2/19/96/LD/Ihc) 9. Drill to T.D. 5/8" casing. 10. If hole conditions warrant, spot a viscous pill on bottom. Run 9- Evaluate quality of mud and save for reuse on 8-1/2" interval. Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss (APl) pH MBT Drilled Solids 9.0 - 9.6 ppg 40 - 70 sec/qt 10- 15 cps 10 - 2O #/100 f¢ 6/12/18 No Control 8.5 - 11.0 < 30 ppb < 75 ppb NOTE: This mud program is a guideline only. Hole conditions should dictate actual mud properties. DO NOT exceed M.A.C. of products or use products not approved in the discharge 'l~ermit. See letter requesting authorization of list of approved products and M.A.C. D M-193 (2/19/96/LD/ihc) UNOCAL BAKER PLATFORM WELL #32 DEPTH INTERVAL 3000'- 7000' 2000' - 4000'(TVD) MUD TYPE GENERIC MUD #2 MUD ADDITIVES POTENTIAL PROBLEMS M-I GEL/M-I BAR/SODA ASH/POLYPAC/FLO-VIS/SODIUM BICARBONATE/RESIN EX/SOLTEX/ SPERSENE/CAUSTIC SODA/LCM MATERIAL/DEFOAM X/LUBE 167 HOLE CLEANING/TIGHT HOLE/BIT BALLING/SLOUGHING COAL/GAS KICKS/HOLE ENLARGEMENT o . . . TREATMENTS/PROCEDURES Treat system for cement contamination. Evaluate mud from 12-1/4" interval. Build new mud if drilled solids are excessive. High hole angles (Baker 32 - 60°) increase the probability of cuttings bed formation. Elevated Iow shear rate rheologies can be increased to inhibit the formation of cuttings beds. Maintain 3 rpm readings - >_10. If cutting beds form rotation and reciprocation are the most effective method of removal. Sloughing coal bed may become a problem the addition of Soltex and Resinex has proven beneficial in minimizing these problems in Cook Inlet. Drill to 7" casing T.D. Save mud for use on 6" interval. D M-193 (2/19/96/LD/Ihc) 8-1/2" ANTICIPATED'MUD PROPERTIES Mud Weight ppg Funnel Viscosity Plastic Viscosity YP Gels 3 rpm Fluid Loss (APl) Fluid Loss (HPHT) pH MBT Drilled Solids 9.0- 9.6 ppg 40 - 70 sec/qt 10- 15 cps 10 - 20 #/100ft2 6/12/18 >_10 6-8cc <_15 cc 8.5 - 11.0 < 30 ppb < 75 ppb NOTE: This mud program is a guideline only. Hole conditions should dictate actual mud properties. DO NOT exceed M.A.C. of products or use products not approved in the discharge permit. See letter requesting authorization of list approved products and M.A.C. DM-193 (2/19/96/LD/Ihc) UNOCAL BAKER PLATFORM WELL #32 o . DEPTH INTERVAL MUD TYPE MUD ADDITIVES POTENTIAL PROBLEMS TREATMENTS Maintain properties in 6" hole. 7000' - 10,357' 4000' - 5718'(TVD) GENERIC MUD #2 M-I GEL/M-I BAR/POLYPAC/SODA ASH/FLO-VIS/SODIUM BICARBONATE/RESINEX SOLTEX/SPERSEN E/CAUSTIC SODA/LCM MATERIAL DEFOAM X/LUBE 167 HOLE CLEANING/TIGHT HOLE/BIT BALLING/SLOUGHING COAL/GAS KICKS/HOLE ENLARGEMENT ~PROCEDURES Fluid loss values can be lowered with Polypac, Resinex, and Soltex. Drill to T.D. Run and cement 5" liner. ANTICIPATED 6"'MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels 3 rpm Fluid Loss (APl) Fluid Loss (HPHT) pH MBT Drilled Solids 9.0 - 9.6 ppg 40 - 70 sec/qt 10- 15 cps 10 - 20 #/100ft2 6/12/18 >10 6-8cc _< 15cc 8.5 - 11.0 < 30 ppb < 75 ppb &!aska Oil & Gas (,-~,,~. Anchor~.ge ~iOTE: This mud program is a guideline only. Hole conditions should dictate actual mud properties. DM-193 (2/19/96/LD/]hc) DO NOT exceed M.A.C. of products or use products not approved in the discharge permit. See letter requesting authorization of list approved products and M.A.C. DM-193 (2/191961LDIIhc) KILL LINE FILL-UP : FLOW = ANNULAR BOP 13%"5000 psi , I PIPE RAMS 13%"5000 psi 3" - t OM BLIND RAMS CHECK ALYE HCR HCR V ' 13%"5000 ps~ - ' MANUAL~'] DRILLING{~ MANUAL [ i i - 3s/~5ooo p~ C H O KE 3-i M 4"-10M GATE VALVES [ PIPE RAMS ]GATE VALVES13%"5000 psi LINE~=~> RISER ~3%" 5000 pm CHAKACHATNA RIG BOPE STACK 13 %" 5000 psi OF HtlNDWAI.~ FL,ei~£ ,~' PANIC LINE BLINO V[NJ' Iff' DERRICK ,f R£LIEF VALVE SEI' IT 40 PSI VENT LINE ~/ILLI$ ADd. CHOKE- 4" 5,000 PSI ~ BALL CLAJUP HUB COAINEC]~ON BUFFER TANK TO PRODUCIION SEP,~ATOR · I0" 1,50 lb, FL~dVGE .S~E~TOR Z' SIPttON LINE ~ 150 lb. FLANGE I TO SttAXER MUD RETURN UNE UNOC.~L CHOKE 14ANIFOL I) HI m m pmmmmml IL~ Ir Av~mm Ii mom W p.~ cOOK INtEl '-"~ ~ .,r,. PLAN VIEW ON SOUTHWEST LL'G ~ ~ ., / .... LLLA N_.._ v/g'.!E._...:_. 'JLL'!)_:./-_~ _o_ !2! !..L',:/! N'J'._ L, .?tlOWN ON NOI~'I'IIf,.:A.%'T I,F,G DIVERTER LINE LAYOUT SOUTHWEST & EAST LEG PosmoNs POOL mc 428 I I I J:I~H PRESSURE RISERS LAYOUT DIVERTER STACK AND BOP STACK UOC PLATFORMS BAKER, DILLION, & ANNA PM 18 ')PP['R' . ....................... z .\...., .... ..-., . ~ I ' ' ~ ~ : " ~ : , : ~: ..... ~; .7 : . . / I ' I: ' ~ : :-- [~ 1~3~ ~ ' I: : J~'. I I / f ........ ~-L ..... / r ~t; ~r /I : _~' ! I .... I'-' · i~/..l;/ """ / ,-. ~1~:~ ...... 55 ag ~ / I ' * ' '~" ' (~ _ _ L ~ ~ A.: I t:, .. ' sc~?~w / . ..-.-~t~ .... [5.~&.-..X N~E__~,~____~ ........ ~ ~,. ~~ ..fl:t ..... :.~ ....... , , L ~ _ ~'~.- - / o --~ - ~ ~ ............... : ....... ~ ~ ~" :;; ;(' J ' ..... I , ~ .............. ~ ~ ................. / i ~ ~--~l I~I~,~? ~e'~:, i"Fl~Z-'~-~;~ : i i ~ i+.r' "l' .-l- ~ / ~ ,:, . . ......... ....... I I ~ , . I . I .3 m ~ ' ' . ' ' ' l~l-f[O : . . _... I I '-:- ' ~ i ................... :~ ..... 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I : ~ 1-1'1 ' ~,,~~-~ ~ / ~ '. ~/ IIX '~ ~ ............................... ~ ............ t~ - - t. pt ......... -- / i i ~- II ~,~ ~ ~,,. ~."' .................... ~ ....... ~..s lift L~ ~ / ~.-. ~l ..... 'X ............................................. I ' ~.- ' ...... a.l-.I -93 LOW PRESSURE MUD ~EM / '~ ~ I I- I~[ ~ ~8.-~ lqd ~ BAKER PLATFORM WELL # 32 MIDDLE GROUND SHOALS ROTARY KELLY BUSHING (RKB) Elev. 118' DRILL DECK LEVEL Elev. 78' PRODUCTION DECK LEVEL Elev. 62' Z x L SEA LEVEL (MLW) Elev. 0' MUD LINE Elev. -102' 32" Structural Casing @ 296' RKB (76'BML) 13-3/8" 68# K-55 BTC Surface Casing (~ 800' 9-5/8" 47# L-80 BTC Intermediate Casing ~ 3000' X 7" 29# L-80 BTC Intermediate Casing @ 7000' 2-7/8" 6.4# L-80 BTC Lin~ F/10357' - 6800' WELL: BAKER #32 FIELD: 1. MUD VVT. I 8.8 PPG 2. MUD WT. II 9.4 PPG 3. MUD VVT. III 9.4 PPG 4. MUD WT. IV 9.4 PPG CASING DESIGN MIDDLE GROUND SHOALS DATE: 19-Feb-96 DESIGN BY: P.A. RYAN M.S.P, TENSION MINIMUM WEIGHT TOP OF STRENGTH INTERVAL DESCRIPTION W/O BF SECTION TENSION CASING SIZE BOTTOM TO.___.~P LENGTH WT_.__~. GRADE THREAD LBS LB__~S 1000 LBS 1 13-3/8" 800 56 744 68 K-55 BTC 50592 50592 1069 TVD 793 56 2 9-5/8" 3000 56 2944 47 L-60 BTC 138368 138368 1086 TVD 2039 56 3 7" 7000 56 6944 29 L-80 BTC 201376 201376 676 TVD 4039 56 4 2-7/8" 10357 6800 3557 6,4 L-80 BTC 22765 22765 105 'FVD 5718 3939 NOTES: M.S.P. is .4~2 psi/ft times TVD less .1 psi/ft gas gradient. * Collapse pressure is calculated by drilling mud weight less a ,1 psi/ft gas gradient. ** Burst pressure is calculated; (BHP @ depth next csg X TVD next csg) X (0,5 half evacuated). 271 psi 697 psi 1381 psi 1956 psi COLLAPSE COLLAPSE PRESS @ RESIST. BOTTOM W/O TENSION TD_.._~F PSI__~* PS~I 21.13 284 1950 7.85 793 4750 3.36 1570 7020 4.61 2223 11160 BURST MINIMUM PRESSURE YIELD CD_._~F PSI** PS~I BD.__.~F 6.88 459 3450 7.52 5.99 909 , 6870 7.56 4.47 1287 8160 6.34 5.02 1287 10570 8.22 Baker Platform Well # 32 Pressure Calculations Baker Platform Well # 32 Middle Ground Shoals February 19, 1996 Hole Section 1 Depth Interval: 0'-800' 17-1/2" hole size 13-3/8" casing to 800' Mud weight: Shoe depth (13-3/8"): Est. fracture gradient of 13-3/8" shoe: Depth of next hole section (12-1/4"): BHP gradient: Gas gradient (assume worst case): 9.4 ppg=0.49 psi/fi 80O' MD/793' TVD 0.80 psi/fi 3000' MD/2039' TVD 0.45 psi/fi 0.0 psi/fi Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - Hydrostatic Pressure MSP=-BHP - (3/4 mud + 1/4 gas) MSP=(2039'x.45 psi/fi) - ((.75(2039'x0.49 psi/fi)) + (.25(2039'x0.0 psi/fi))) MSP= 168 psi Therefore, the hydrostatic pressure at the 13-3/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 13-3/8" shoe, if a constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 13-3/8" casing depth (Hpcsg). Hpsh= MSP + Hpcsg Hpsh= 168 + (793'x0.49 psi/fi) HPsh= 557 psi This (Hpsh = 557 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 557 psi < Fpsh = 0.80 psi/fi x 793' = 634 psi. Baker Platform Well # 32 Pressure Calculations Hole Section 2 Depth Interval: 800'-3000' 12-1/4" hole size 9-5/8" casing to 3000' Mud weight: Shoe depth (9-5/8"): Est. fracture gradient of 9-5/8" shoe: Depth of next hole section (8-1/2"): BHP gradient: Gas gradient (assme worst case): 9.4 ppg=0.49 psi/ft 3000' MD/2039' TVD 0.80 psi/ft 7000' MD/4039' TVD 0.45 psifft 0.0 psi/ft Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - Hydrostatic Pressure MSP=BHP - (3/4 mud + 1/4 gas) MSP=(4039'x.45 psi/fO - ((.75(4039'x0.49 psi/fl)) + (.25(4039'x0.0 psi/fi))) MSP= 333 psi Therefore, the hydrostatic pressure at the 9-5/8" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 9-5/8" shoe, if a constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 9-5/8" casing depth (Hpcsg). Hpsh= MSP + Hpcsg Hpsh= 333 + (2039'x0.49 psi/fO HPsh= 1332 psi This (Hpsh = 1332 psi) is less than the fracture pressure .at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 1332 psi < Fpsh = 0.80 psi/ft x 2039' = 1631 psi. Baker Platform Well # 3 2 Pressure Calculations Hole Section 3 Depth Interval: 3000'-7000' 8-1/2" hole size 7" casing to 7000' Mud weight: Shoe depth (7"): Est. fracture gradient of 7" shoe: Depth of next hole section (6"): BHP gradient: Gas gradient (assume worst case): 9.4 ppg--0.49 psi/ft 7000' MD/4039' TVD 0.80 psi/ft 10357' MD/5718' TVD 0.45 psi/ft 0.0 psi/ft Gas kick situation in wellbore. Assume 3/4 mud & 1/4 gas. MSP=BHP - Hydrostatic Pressure MSP=BHP - (3/4 mud + 1/4 gas) MSP=(5718'x.45 psi/fO - ((.75(5718'x0.49 psi/ft)) + (.25(5718'x0.0 psi/ft))) MSP= 472 psi Therefore, the hydrostatic pressure at the 7" shoe (Hpsh) is the greatest when the gas (kick) bubble reaches the 7" shoe, if a constant BHP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 7" casing depth (Hpcsg). Hpsh= MSP + Hpcsg Hpsh= 472 + (4039'x0.49 psi/fo HPsh= 2451 psi This (Hpsh = 2451 psi) is less than the fracture pressure at the same shoe (Fpsh) and thus adequate to handle the well kick scenario. Hpsh = 2451 psi < Fpsh = 0.80 psi/ft x 4039' = 3231 psi. File name: bkr32cal.doc Well # Date Baker Platfom Ba 28 10-10-93 Ba 30 10-24-93 Ba 30 10-28-93 Ba 28 11-17-93 Ba 29 12-17-94 Ba 29 12-29-93 Ba 30 01-27-94 Ba 28 03-01-94 Grayling Platfom G-40 01-24-90 G-40 Monopod Platform A-lrd 04-04-91 A-8rd 07-01-89 A-20rd 03-30-90 ^-20rd 04-13-90 A-28rd 11-20-89 A-28rd 11-27-89 Granite Point Platform 11-13rd 02-14-92 51 08-07-92 51 07-28-92 51 08-25-92 50 05-27-92 50 06-04-92 50 06-27-92 Dillon Platform Leak Off Test (LOT) Data Cook Inlet, Alaska Revised August 25, 1995 Unocal Energy Resources Alaska Csg Size Shoe Depth Frac Grad. (TVD) EMW (PPg) 24" 802' 0.94 18.10 24" 803' 0.83 15.90 18-5/8" 2011' 0.94 18.10 18-5/8" 2135' 0.75 14.50 18-5/8" 2054' 0.76 14.61 13-3/8" 5869' 0.85 16.33 13-3/8" 5467' 0.93 17.96 13-3/8" 3509' 0.75 14.40 16" 1926' 0.96 18.46 13-3/8" 4977' 0.86 16.54 9-5/8" 1132' 1.07 20.57 9-5/8" 3760' 1.02 19.61 13-3/8" 755' 0.95 18.20 9-5/8" 1931' 0.85 16.30 20" 240' 0.75 14.42 13-3/8" 1140' 0.97 18.65 9-5/8" 9966' 0.96 18.40 13-3/8" 3803' 1.00 19.20 18-5/8" 1010' 0.87 16.80 9-5/8" 9592' 1.05 20.20 18-5/8" 982' 0.91 17.50 13-3/8" 4208' 0.84 16.20 9-5/8" 9877' 0.93 17.90 1.12 0.82 NA 1.01 0.83 NA 1.02 0.80 16 04-22-94 18-5/8" 1131' 16 06-16-94 13-3/8" 3640' 16 07-04-94 9-5/8" 9469' 17 04-27-94 18-5/8" 1142' 17 05-01-94 13-3/8" 3560' 17 05- 9-5/8" 9213' 18 07-26-94 18-5/8" 1132' 18 08-01-94 13-3/8" 3988' 21.72 15.80 14.2 (FIT) 19.47 15.90 16.5 (FIT) 19.63 15.3 Leak Off Test (LOT) Data Page 2 Anna Platform 1 lrd 10-23-94 13-3/8" 2976' 1 lrd 11-11-94 9-5/8" 8750' 3rd 12/10/94 9-5/8" 7839' 50 2/8/95 18-5/8" 1160' 50 2/13/95 13~3/8" 4251 50 3/8/95 9-5/8" 9844' 51 1/29/95 18-5/8" 1130' 51 5/15/95 13-3/8" 3796' 51 6/3/95 9-5/8" 9842' 52 2/3/95 18-5/8" 1153' 52 3/27/95 13-3/8" 3940' 52 4/15/95 9-5/8" 9470' 7rd2 8/25/95 9-5/8" 4439' Notes: All fracture gradients reported have been corrected for air and water gaps. (FIT)-Formation Integrity Test 0.89 0.92 0.75 1.38 1.01 .86 1.36 .71 .88 1.41 .84 .91 .96 (FIT) 17.2 17.7 14.5 26.6 19.5 16.5 26.2 13.6 17.0 (FIT) 27.0 16.15 17.6 (FIT) 18.5 Filename Lotdata.doc Unocal Corporation Oil & Gas Operations 909 West 9th Avenue, P.O. Box .196247 Anchorage, Alaska 995'19-6247 UNOCAL( February 29, 1996 Kevin A. Tabler Land Manager Alaska Business Unit Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 BAKER PLA TFORM #32 PERMIT TO DRILL ADL 17595 Dear Chairman Johnson: Enclosed, in triplicate, is Union Oil Company of California' s (Unocal) application for Permit to Drill Middle Ground Shoal' s Baker Platform #32 (form 10-401) pursuant to 20 AAC 25.005 and our check No. 2000030 in the amount of $100.00 as required under 20 AAC 25.005 (c) (1). If you require additional information, please contact Roxanne Sinz at (907) 263-7623 or Pat Ryan at (907) 263-7864. We appreciate your review and trust the enclosed is satisfactory. Very truly yours, ~/Kevin A. Tabler Enclosures ,v:LL PERMIT CHECKLIST dev D redrll [] serv [] wellbore seg [] ON/O~F s~o~ ADMINISTRATION REMARKS 1. 2. 3 4 5 6 7 8 9. 10. ll. 12. 13. Permit fee attached .................. Lease number appropriate ............... Unique well name and nu/nber .............. Well located in a defined pool .............. Well located proper distance from drlg unit boundary.. ~_~- Well located proper distance from other wells Sufficient acreage available in drilling unit If deviated, is wellbore plat included ........ Operator only affected party .............. ENGINEERING APPR DATE Operator has appropriate bond in force ........ Can permit be approved before 15-day wait 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . .~ N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N /_'_% 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate ........... Y N 24. Drilling fluid program schematic & equip list adequate .~ N 25 BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~(~O psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... Y~ N 29. Is presence of ~2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures Data presented on potential overpressure zones ..... ~i Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports . . . ~'. Y [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: TAB 4 '~'~,; .... Comments/Instructions: ,Z m HOW/lib - A:%FORMS\cheklist rev 11195 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. * AI_~SKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : UNOCAL WELL NAME : BA]OER 32 FIELD NACRE : MIDDLE GROUND SHOAL BOROUGH : KENAI STATE · ALASKA API NUMBER : 50-733-20473 REFERENCE NO : 97218 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-~Y-1997 09:09 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/05/13 ORIGIN . FLIC REEL NAME : 97218 CONTINUATION # : PREVIOUS REEL : COM~4ENT . UNOCAL,MIDDLE GROt~krD SHOAL, SAtCER 32.API #50-733-20473 **** TAPE HEADER **** SERVICE NAME : EDIT DATE . 97/05/13 ORIGIN : FLIC TAPE NAME · 97218 CONTINUATION # : 1 PREVIOUS TAPE : CO~94F2TT : UNOCAL, MIDDLE GROUND SHOAL, BAKER 32,API #50-733-20473 **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE . FLIC VERSION . O01AiO DATE · 97/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE -EDIT. O01 ~tOCAL MIDDLE GROUND SHOAL BAKER 32 50-733-20473 "MAIN PASS LOG DATA" DATA SAMPLED ~qIERY -.5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME DIT-E .DTE LDT . LDT PHASOR DUAL INDUCTION SFL LIT~.O D~SITY LiS Tape Verification Listing Schlu~Juerger Alaska Computing Center 13-MAY-1997 09:09 PAGE * CNT~A/D/H . CNL COMPENSATED NEUTRON . ****************************************************************************** ** DATA FO.~V~AT SPECIFICATION RECORD ** ** SET TYPE ~ 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 244 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 I 0 66 0 ** SET TYPE - Ci~%N ** NAME SERV UNIT SERVICE API API API API FILE NUM~ ~VO~fB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 593718 O0 000 O0 0 1 1 i 4 68 0000000000 CIDP DTE t4~O 593718 O0 000 O0 0 1 1 I 4 68 0000000000 IDPH DTE 0HN~I593718 O0 000 O0 0 1 1 1 4 68 0000000000 CIMP DTE I4MH. 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I 4 68 0000000000 CNTC C~ CPS 593718 O0 000 O0 0 ! ! 1 4 68 0000000000 CFTC CNL CPS 593718 O0 000 O0 0 1 i 1 4 68 0000000000 GR ~L GAPI 593718 O0 000 O0 0 1 ! 1 4 68 0000000000 CALI CNL IN 593718 O0 000 O0 0 1 i ! 4 68 0000000000 TENS ~VL LB 593718 O0 000 O0 0 ! 1 1 4 68 0000000000 f4RES ~ 0~2vi~5937!8 O0 000 O0 0 1 I ! 4 68 0000000000 MTEMC_NL DEGF 593718 O0 000 O0 0 ! ! 1 4 68 0000000000 HTEN~'~TL LB 593718 O0 000 O0 0 1 t 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center !3-MAY-1997 09:09 PAGE: DEPT. 9000. 500 CIDP. DTE IMPH.DTE 33. 000 CILD.DTE !r,,~. DTE 32. 031 IFRE. DTE IIRD. DTE 12. 703 IIXD. DTE SFLU. DTE 154. 875 SP. DTE MT~f. DTE 122. 063 MRES.DTE RHOB. LDT 1. 644 DRHO. QSS.LDT -0. 050 LS. LET LITH. LDT 159. 250 SSI . LDT SSHV. LDT 1581. 000 S1RH.LDT CALI. LDT 2. 383 GR. LDT NiRES . LDT O . 170 HTEN. LD T TNPH. CNL 36. 795 TNRA. RCFT. CNL 904. 250 CNTC. CNL CAL I . CNL 2.383 TENS. CNL HTEN. CNL 1623. 000 DEPT. 6712. 000 CIDP. DTE IMPH.DTE 1950. 000 CILD.DTE ILM. DTE 1950. 000 IFRE.DTE IIRD.DTE 45. 531 IIXD.DTE SFLU. DTE O. 090 SP. DTE MTEM. DTE 109. 375 I4~ES.DTE RHOB. LDT 2.105 DRHO. LDT QSS.LDT -0. 041 LS.LDT LITH. LDT 16. 906 SSi. LDT SSHV. LDT 1592. 000 S1RH. LDT CALI. LDT 5.367 GR. LDT ,~ES. LDT O . 181 HTEN. LDT TNPH. CNL 38.001 TNRA. CNL RCFT. CNL 586. 426 CNTC. CAL I . CNL 5.367 TENS. HTEN. CNL 391 . 000 13.133 IDPH. DTE 76.125 13.906 ILD.DTE 71.875 20.000 IDQF.DTE 3.000 2.355 II~4.DTE 29.688 244.375 GR.DTE 159.375 0.170 HTEN.DTE 1623.000 -0.015 PEF. LDT 8.328 1!33.000 LU.LDT 1099.000 241.375 SS2.LDT 430.250 1.713 LSRH.LDT 1.658 159.375 TENS.LDT 1275.000 1623.000 NPHI.CNL 41.631 3.031 NPOR.CNL 36.795 2901.498 CFTC. CNL 966.540 1275.000 NiRES.CNL 0.170 47.875 IDPH.DTE 50.406 ILD.DTE 20.000 IDQF.DTE 1.846 IIRM. DTE 64.125 GR.DTE 0.181 HTEN. DTE -0.719 PEF. LDT 150.000 LU. L DT 74.188 SS2.LDT 4.281 LSRH.LDT 93.750 TENS.LDT 391.000 NPHi. CNL 3.125 NPOR.CNL 1930.138 CFTC. CNL 1730.000 NZPOES.CNL 20.875 19 828 0 000 -271 250 93 750 391 000 15 797 145 500 105 125 2 822 1730 000 40 074 38. 001 626. 823 0.181 CIMP.DTE CILM. DTE IMQF.DTE IIXM. DTE TENS.DTE DPHI.LDT QLS.LDT LL.LDT LSHV. LDT LURH. LDT MTEM. LDT RTNR.CNL RCNT. CNL GR.CNL MTEM. CNL CIMP. DTE CILM. DTE IMQF. DTE I IXM. DTE TENS. DTE DPHI . LDT QLS. LDT LL. LDT LSHV. LDT LURH. LDT MTE~f . LDT RTI~R. CNL RCNT. CNL GR. CNL MT~f. 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CNR COMPF_dYSATED NEUTRON . ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 244 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1997 09:09 PAGE TYPE REPR CODE ~i~UE 7 65 $ 68 9 65 FT II 66 4 12 68 13 66 14 65 15 66 16 66 0 66 ** SET TYPE - C~41V ** NAME SERV UNIT SERVICE API API APi API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~S MOD NUMB SAMP ELE~ CODE (HEX) DEPT F? 593718 O0 000 O0 0 2 1 1 4 68 0000000000 CIDP DTR ~E~O 593718 O0 000 O0 0 2 1 1 4 68 0000000000 IDPH DTR 0~593718 O0 000 O0 0 2 1 1 4 68 0000000000 CIMP DTR ~941~0 593718 O0 000 O0 0 2 1 1 4 68 0000000000 IMPH DTR O~E~I 593718 O0 000 O0 0 2 1 1 4 68 0000000000 CILD DTR M~£~O 593718 O0 000 O0 0 2 1 1 4 68 0000000000 iLD DTR 0~ 593718 O0 000 O0 0 2 ! 1 4 68 0000000000 CILMDTR MI~40 593718 O0 000 O0 0 2 i 1 4 68 0000000000 ILM DTR 0~593718 O0 000 O0 0 2 ! ! 4 68 0000000000 IFRE DTR HZ 593718 O0 000 O0 0 2 1 1 4 68 0000000000 IDQF DTR 593718 O0 000 O0 0 2 t 1 4 68 0000000000 IMQF DTR 593718 O0 000 O0 0 2 1 1 4 68 0000000000 IIRDDTR ~l~IO 593718 O0 000 O0 0 2 1 1 4 68 0000000000 IIXDDTR P~f~.O593718 O0 000 O0 0 2 1 1 4 68 0000000000 IIRMDTR ~94~.0593718 O0 000 O0 0 2 1 1 4 68 ~000000000 IIXI~DTR M2vlHO593718 O0 000 O0 0 2 i 1 4 68 0000000000 SFLU DTR 0~2414593718 O0 '000 O0 0 2 1 1 4 68 0000000000 SP DTR MV 593718 O0 000 O0 0 2 1 1 4 68 0000000000 GR DTR GAPI 593718 O0 000 O0 0 2 t 1 4 68 0000000000 TENS DTR LB 593718 O0 000 O0 0 2 1 1 4 68 0000000000 MTEMDTR DEGF 593718 O0 000 O0 0 2 1 1 4 68 0000000000 ?~ES DTR OPEW2~593718 O0 000 O0 0 2 1 1 4 68 0000000000 HTENDTR LB 593718 O0 000 O0 0 2 1 1 4 68 0000000000 DPHI LDR PU 593718 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LDR G/C3 593718 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LDR G/C3 593718 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LDR 593718 O0 000 O0 0 2 1 1 4 68 0000000000 QLS LDR 593718 O0 000 O0 0 2 1 1 4 68 0000000000 QSS LDR 593718 O0 000 O0 0 2 1 1 4 68 0000000000 LS LDR CPS 593718 O0 000 O0 0 2 1 1 4 68 0000000000 LU LDR CPS 593718 O0 000 O0 0 2 1 1 4 68 0000000000 LL LDR CPS 593718 O0 000 O0 0 2 1 1 4 68 0000000000 LITHLDR CPS 593718 O0 000 O0 0 2 i 1 4 68 0000000000 SSi LDR CPS 593718 O0 000 O0 0 2 1 I 4 68 0000000000 SS2 LDR CPS 593718 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1997 09:09 PAGE: NAME SERV UNIT SERVICE API API API API FILE NU~B NU~B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) LSHV LDR V 593718 O0 000 SSHV LDR V 593718 O0 000 S1RH LDR G/C3 593718 O0 000 LSRH LDR G/C3 593718 O0 000 LURH LDR G/C3 593718 O0 000 CALI LDR IN 593718 O0 000 GR LDR GAPI 593718 O0 000 TENS LDR LB 593718 O0 000 MTE~LDR DEGF 593718 O0 000 MRES LDR 0H1~593718 O0 000 HTENLDR LB 593718 O0 000 NPHI CNR PU 593718 O0 000 RTNR CNR 593718 O0 000 TNPH CNR PU 593718 O0 000 TNRA C~ 593718 O0 000 NPOR CITR PU 593718 O0 000 RCNT CNR CPS 593718 O0 000 RCFT CNR CPS 593718 O0 000 CATTC CNR CPS 593718 O0 000 CFTC CNR CPS 593718 O0 000 GR CNR GAPI 593718 O0 000 CALI CNR IN 593718 O0 000 TENS CNR LB 593718 O0 000 MRES CNR 0H~4~593718 O0 000 ~FfE~ C.~ DEGF 593718 O0 000 HTEN ~ LB 593718 O0 000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 i 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 ! 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7108.500 CIDP.DTR IMPH. DTR 6. 703 CILD.DTR ILM. DTR 6. 605 IFRE.DTR IIRD.DTR 122. 375 IIY_D.DTR SFLU. DTR 6.594 SP. DTR MTE~. DTR I 10. 063 f4~ES. DTR RHOB. LDR 1.720 DRHO. LDR QSS. LDR O. 078 LS. L_DR LITH. LDR 278. 750 SSi . LDR SSHV. LDR 1582. 000 S1RH.LDR CALI . LDR 2.383 GR..LDR MRES. LDR 0.183 HTEN. LDR TNPH. C~VR 32. 792 ~A. C~%~R RCFT. ClVR 962. 949 CNTC. CNR CALI. C.~R 2.383 TENS. C~R HTEN. CNR 21. 953 136. 625 IDPH.DTR 7. 313 CIMP.DTR 139. 000 ILD.DTR 7. 191 CILM.DTR 20. 000 IDQF.DTR 3. 000 IMQF.DTR 9. 102 IIRM.DTR 142. 750 IIX~.DTR 193. 625 GR.DTR 98. 500 TENS.DTR 0.183 HTEN.DTR 21.953 DPHI.LDR O. 037 PEF. LDR 2. 764 QLS.LDR 1128.000 LU. LDR 1062.000 LL.LDR 268. 250 SS2. LDR 395. 750 LSHV. LDR 1. 584 LSP~. LDR 1. 683 LO-RH. LDR 98. 500 TENS. LDR 485. 000 MTEM. LDR 21 . 953 NPHI. CNR 36. 921 RTNR. CNR 2 . 774 NPOR. CNR 32. 792 RCNT. CNR 2824.170 CFTC. CNR 1029. 282 GR. CNR 485. 000 M}~ES. CNR O. 183 MTEM. CNR 149 125 151 250 2 000 9 563 485 000 56 360 -0.011 597. 000 1369. 000 1. 707 110. 063 2. 885 2819. 019 98. 500 11 O. 063 LIS Tape Verification Listing Schi~Derger Alaska Computing Center 13-MAY-199? 09:09 PAGE: DEPT. iMPH. DTR i LM. DTR iI~. DTR SFLU. DTR R~%'OB. LDR Qss. LDR LiTH. LDR SSi-U/. LDR C_ALI. LD R ~E S . LD R INPH. CNR R CFT. CNR C-ALi. CNR HTE~N. CNR 6605 500 1950 000 1950 000 49 750 0 303 108 813 2 340 -0 117 12 625 1580 000 5 242 0.181 8. 938 1633.150 5.242 387.750 CIDP. DTR CILD. DTR I FRE . DTR I IXD. DTR SP. DTR MRES . DTR DRHO. LDR LS. LDR SSi. LDR S1RH. LDR GR. LDR HTEN. LDR TNRAoCNR ONTO. CNR TENS. CNR 53 . 250 IDPH. DTR 55.156 ILD. DTR 20. 000 IDQF.DTR -2.617 iIRM. DTR 61. 125 GR. DTR O. 181 HTF~¥. DTR - O. 705 PEF. LDR 112. 250 LU. 67. 500 SS2. LDR 4 . 551 LSRH. LDR 52. 438 TENS. I_JR 387. 750 NPHI. CNR 1. 804 NPOR. CNR 3103 . 415 CFTC. -20. 000 MIRES. ~ 18. 766 CIMP.DTR 18. 125 CILM.DTR O . 000 IMQF. DTR -216. 125 II,~f. DTR 52. 438 TENS.DTR 387. 750 DPHI. LDR 14 . 820 QLS. LDR 113. 625 LL.LDR 101.375 LSHV. LDR 3. 045 LUR~. LDR -20. 000 MTEM. LDR 10. 619 RTNR. CNR 8. 938 RCNT. CNR 1745. 660 GR. CNR 0.181 MT~. CNR -216.250 -223.125 0.000 -609.000 -20.000 18.769 0.073 55.469 1377.090 3.102 108.813 1.877 3097.754 52.438 108.813 ** END OF DATA ** **** FILE TRAILER **** FiLE NAME : EDIT .002 S~qVICE : FLIC V~SION : O01A!O DATE : 97/05/13 M~tXREC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/05/13 ORIGIN : FLIC TAPE NAME : 97218 CONTINUATION # : 1 PP, EVIOUS TAPE: COM34ENT : UNOCAL,MIDDLE GROUND SHOAL, BAKER 32,API #50-733-20473 **** REEL TRAILER **** SERVICE NAM~ : EDIT DATE : 97/05/13 ORIGIN : FLIC REEL NAFIE : 97218 C©b~INUATION # : P~VIOUS REEL C3M~IENT : UNOCAL,MIDDLE GROUND SHOAL, BAKER 32,API #50-733-20473
