The URL can be used to link to this page

Home My WebLink About172-016THE STATE °fALASKA. GOVERNOR MIKE DUNLEAVY Taylor Wellman Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beluga River Field, Undefined Oil Pool, BRU 241-34 Permit to Drill Number: 172-016 Sundry Number: 320-097 Dear Mr. Wellman: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, JJ ssie�lowski Commissioner DATED this Aday of March, 2020. 1BDMS f'4 -"MAR 3 1 7T STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECEIVED MAR 2 �CV f20pp7 /zo AOG 1. Type of Request: Abandon ❑� • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ _ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory p ry ❑ Development Q Stratigraphic ❑ Service ❑ 172-016 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-283-20038-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A , Will planned perforations require a spacing exception? Yes ❑ No Beluga River Unit (BRU) 241-34 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA029657 b Beluga River/ Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): 5,477' Junk (MD): 6,501' 6,501' 5,477' 5,477' -211 psi 2,979'(LS), 3,015'(SS) 4,007' Casing Length Size MD TVD Burst Collapse Structural Conductor 44' 30" 44' 44' Surface 405' 20" 405' 405' 1,530psi 520psi Intermediate 2,380' 13-3/8" 2,380' 2,380' 3,450psi 1,950psi Production 112' 10-3/4" 112' 112' 8,060psi 3,670psi Production 6,388' 9-5/8" 6,500' 16,500' 1 6,330psi 3,810psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 2-3/8" Heater, Tubing Grade: 4.6# / N-80, Tubing MD (ft): 1,829', See Attached Schematic See Attached Schematic 2-7/8" LS, & 2-7/8" SS 6.5# / N-80, & 6.5# / N-80 5,429', & 3,543' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Brown HS -17-2C Dual Fir, Brown HB -01 (x4) and N/A 2,997', 3,583', 4,010% 4,685', & 5,105' MD/ -VD and N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Strati ra hic g p ❑ Development ❑� Service ❑ 14. Estimated Date for 15. Well Status after proposed work: June 1, 2020 Operations: OIL E]WINJ F]WDSPL F] Suspended ElCommencing GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑✓ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Taylor Wellmap 907-777-8449 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramertrDhilcoro com Contact Phone: 777-8420 Authorized Signature: Date: e; -Z- Z� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I — O Plug Integrity 5 NoTl st Mechanical Integrity Test ❑ Location Clearance D ,Q „I Other: Q O/'C el �.y� . r1 , � Z , � 0- S7 i ; z -C Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes El No Subsequent Form Required: U `� r/ 7— RBDNIS -116L/MAR 3 12U20 APPROVED BY 1- Approved by: � COMMISSIONER THE COMMISSION Date: `�"�'L /��/moi✓ A >/31I -A Submit Form and Form 10- 3 Revised 41201 R//7 Approved application is v I O f��'e^[f2 R l.TI'.S19TP h to of approval. Attach ents T Duplicate K Hilcorp Alaska, LU Well Prognosis Well: BRU 241-34 Date:01/24/2020 Well Name: BRU 241-34 API Number: Status: Shut -In Gas Well Leg: Estimated Start Date: June1,2020 Rig: Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd:Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: t50-283-20038-00Current First Call Engineer: Ted Kramer (907) 777-8420 (0) )Second Call Engineer: Taylor Wellman (907) 777-8449 (0) M) AFE Number: Maximum Expected BHP: — 600 psi @ 3,887' TVD (Estimated from offset wells) Max. Potential Surface Pressure: — 211 psi (Based on the Max. Exp. BHP and a 0.10 psi/ft gas gradient to Surface) Brief Well Summary: Beluga River Unit 241-34 (BRU 241-34) was drilled and completed in 1972 as a Beluga gas well. The well was initially completed as a triple string completion to control production/drawdown from individual Beluga intervals (to minimize sand production). BRU 241-34 was worked over in September 1986, to add additional Beluga and Sterling perforations. At this time the well was completed as a dual completion, with two 2-7/8" production tubing strings. The dual completion also contained individual zonal isolation via four (4) sliding sleeves and associated packers in the Long String and one (1) sliding sleeve in the Short String, The dual completion also contained a 2-3/8" Heater String, landed above the dual packer. In (or before) 2019, BRU 241-34 developed some integrity issues between the IA and OA and was h t -in in September 2019 to address these issues. As part of the workover, the Short String was P&A'd and a Cement Packer was placed above the mechanical Brown Dual Packer in the well. Following placement of the Cement Packer, a milled CIBP became stuck in the second Sliding Sleeve (@ 4,007') of the Long String. Fishing operations (wireline and coil) were unsuccessful in removing the fish. A Packoff Plug was then placed up -hole in the Long String (10/17/19) and the well has remained shut-in ever since. Yk The purpose of this Sundry is to permanently P&A the BRU 241-34 wellbore. .;�_ . As part of this work, Hilcorp requests a variance -from 20 AAC 25.112 (b) (1) (A) from setting plugs below and yv� above each perforated interval in the Sterling and Beluga formations. The various intervals are currently V separated by five Brown packers (one dual HS -17-2C & four HB -1) and one CIBP. A cement plug ("Cement Packer") was placed on top of the dual packer and a CBL (run 9/3/19) shows good cement from 2,997' (depth of dual packer) to 2,300' and questionable cement from 2,300' to 2,068'. Considering the cement on top of the dual packer, the down -hole completion can't be removed from the wellbore Note that the 2-7/8' Short String has he -en already been P&A'rl and that the 2-7/8" Lone String has a fish (milled CIBP) stuck in the second Sliding Sleeve (@ 4,007'). Hilcorp has been unable to retrieve, or push to bottom, this plug. As a result, there is no access to the lower four sets of Beluga perforations (Beluga zones E, F, G, & H). They will be isolated using a CIBP, with cement placed on top. Regarding the upper two intervals, Hilcorp intends to, ? squeeze cement them separately, prior to cutting and pulling the tubine strives ahove the deal nackarla foment BJP H Hile.1, Alaska, LD Pre - CTU Work: Well Prognosis Well: BRU 241-34 Date:01/24/2020 1. Provide 24 hour notice to AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 112(h). Notify BLM of P&A as per 43 CFR 3160 G. 2. RU Pump Truck. RU on IA and perform a pressure test to 2,000 psi on chart for 30 min. Bleed down O pressure. a. Note that there is casing leak at 103.8' in the 9-5/8" Production casing string (ACX Log, dated 7/6/19). Thus the OA (9-5/8" x 13-3/8" annulus) is in pressure communication with the IA. b. Both the IA and OA will need to be charted. 3. MIRU Slickline on the Long String. Pressure test lubricator to 3,000 psi. RIH and pull Packoff Plug and AD -2 Stop @ 2,979'. 4. RIH with slickline and close the upper Sliding Sleeve @ 3,5801. POOH & RD Slickline. 5. MIRU E -line on the Long String. Pressure test lubricator to 3,000 psi. 6. PU and RIH with 2-7/8" CIBP, to -3,970'. Set same depth and POOH. a. Note that there is a Fish (partially milled CIBP) in the Sliding Sleeve at 4,007', with a safety jointjust above. The plan is to set the CIBP just above the safety joint. 7. PU Dump Bailer and dump bail 35' of cement on top of the CIBP (from� 3,970' -3,935'). WOC. 8. Pressure test the Long String to 2,500 psi, for 30 minutes. IC4( k a. If pressure test fails, it is likely due to the upper Sliding Sleeve (@ 3,580') not holding pressure. If necessary, MIRU Slickline to close the Sliding Sleeve. 9. PU and RIH with Tubing Punch to 3,604'. Punch 4' of holes (3,604' - 3,600') in the 2-7/8" tubing (Long String). POOH. 10. RU Pump Truck on the 2_7/8" Long String and bullhead 9.8 oog heavy brine down to (& into) the Beluga D & E perforations. a. In addition to insuring kill weight fluid at the perforations, this will also ensure fluid injectivity prior to squeeze cementing. - - Coiled Tubing Unit: C�v 11. MIRU the Coiled Tubing Unit (CTU), onto the 2-7/8" Long String. 12. PU and RIH with a 2-7/8" Cement Retainer, on 1.75" coiled tubing. 13. Set Cement Retainer @ "3,590' (just below Brown HB -1 Packer @ 3,583'). 14. RU Cementers and squeeze the Beluga D`& Eperforations (by down squeeze method) with 38 bbls SGtZ of 15.8 ppg cement. #t a. Note: Tubing + Annular volume =-31bbls. b. 25% excess pumped/squeezed to ensure perforation isolation 15. Pull out of the Cement Retainer, leaving 75' of cement on top of the retainer (an additional 0.5 bbls). a. Note that the 75' of cement placed on top of the cement retainer (in the 2-7/8" tubing) will extend past the first Sliding Sleeve (@ 3,580') in the tubing. b. TOC should be at (or above) 3,515'. 16. POOH with 1.75" coil. WOC. 17. Pressure test well to 2,500 psi, for 30 minutes. 18. MIRU E -line (on the Long String). Pressure test lubricator to 3,000 psi. O75Y H I3ilmrp Alaska, LU Well Prognosis Well: BRU 241-34 Date:01/24/2020 y _ 19. PU and RIH with Tubing Punch to 3,054'. Punch 4' of holes (3,054' - 3,050') in the 2-7/8" tubing P (Long String). POOH. 3050 20. RU Pump Truck on the 2-7/8" Lang String and bullhead 9.8 ppg heavy brine down to (& into) the Sterling (A, B, & C) and Upper Beluga (D) perforations. a. In addition to insuring kill weight fluid at the perforations, this will also ensure fluid injectivity prior to squeeze cementing. 21. RU CTU onto the 2-7/8" Long String. 22. PU and RIH with a tad 2-7/8" Cement Retainer, on 1.75" coiled tubing. 4J,c r✓"' 23. Set Cement Retainer @ - 960' (just above the safety joint @ 2,965'). 24. RU Cementers and squeeze the Sterling and Upper Beluga perforations (by down squeeze method) 48 bbls of 15.8 ppg cement. LD c. Note: Tubing + Annular volume = -39 bbls. Dwith d. 25% excess pumped/squeezed to ensure perforation isolation 25. Pull out of the Cement Retainer, leaving 75' of cement on top of the retainer (an additional 0.5 bbls). a. TOC should beat (or above) 2,85. 26. POOH with 1.75" coil. WOC. 27. Pressure test well to 2,500 psi, for 30 minutes. 28. RDMO CTU. cj-5 ) Post CTU / /// Pre -Rig Work: �� C.c� /71 29. MIRU E -line (on the Long String). Pressure test lubricator to 3,000 psi. ;, ol 30. PU & RIH with Perforating Guns (sufficient to penetrate the 9-5/8" casing, through the cemented 2- 7 /8" x 9-5/8" annulus) to 2,505'. 31. Perforate the 2-7/8" Tubing and 9-5/8" Casing (with cement in the annulus) over the 5' interval: 2,500'- 2,505'. POOH. 32. RU Pump Truck on the 2-7/8" Long String and try to circulate brine down the tubing and up the 9- - 5/8"x13-3/8" annulus. 5/8"x13-3/8"annulus. Notes Ne+ Pi-d6iz ,H� C?.�r�X. a. The perforations should be within the cemented volume on top of the Brown Dual Packer (@ 2,997'). b. The TOC on top of the dual packer is estimated/calculated to be at - 2,142'. c. A Cement Bond Log, run 9/3/19, showed Good Cement from 2,997' up to 2,300' and Vie✓ Questionable Cement from 2,300'- 2,068'. cA �3. If circulation is established between the 2-7/8" Tubing and the 9-5/8" x 13-3/8" Annulus, go to Step 35. lJ l(lo 34. If circulation is not established between the 2-7/8" Tubing and the 9-5/8" x 13-3/8" Annulus, skip xb}l Steps 35 & 36 and go to Step 37. f,Wy 35. �n U RU Cementers and pump cement (down the Long String) up the 9-5/8" x 13-3/8" annulus. Place 250' of cement in the annulus, across the Intermediate Casing Shoe. WOC. a. Cement volume to fill 250' of 9-5/8" x 13-3/8" annulus, is 15 bbls. 36. Pressure test the 9-5/8" x 13-3/8" annulus to psi for 10 minutes. C A4 37. RU E -line on the 2-7/8" Short Tubing String. dttAkl 38. PU and RIH with Tubing Cutter to 2,060'. Well Prognosis Well: BRU 241-34 H leorp Alaska, LLi Date: 01/24/2020 39. Cut Short String off @ 2,060'. POOH & RD from Short String. a. A Cement Bond Log, run 9/3/19, showed Good Cement from 2,997' up to 2,300' and k1E/� Questionable Cement from 2,300'- 2,069'. Tubing should be free above 2,068'. 40. RU E -line on the 2-7/8" Long Tubing String. 41. PU and RIH with Tubing Cutter to 2,055'. 42. Cut Long String off @ 2,055'. POOH & RD E -line. t_ 7 Rig#401: 43. MIRU Rig 401. �t1 44. Set Back Pressure valve. ND wellhead, NU BOP and test 250 low & 2,600 psi high, annular to 250 psi low & 2,500 psi high. Record accumulator pre -charge pressures and chart tests. Notify AOGCC and BLM 24 hours in advance of test to extend the opportunity to witness. 0 ryJ a. Perform Test. b. Test VBR rams on 2-7/8" and 2-3/8" test joints. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Copy to BLM. 45. PU tension on the 2-7/8" Long String. > U4-1- /d /7-4 46. RU pump truck and circulate the wellbore with a 3.8 ppg heavy kill weight fluid. 47. POOH with Long String, standing back the tubing. 48. PU & POOH with Short String, laying down the tubing. 49.k't too PU & POOH with 2-3/8" Heater String, laying down the tubing.�J s 50. RU E -line. a �C 51. PU & RIH with 9-5/8" CIBP to -2,050'. Set same depth and POOH. 52. If in Step 32, circulation was established between the Long String and the 9-5/8" x 13-3/8" Annulus and the annulus was subsequently cemented (Steps 35 & 36), go to Step 54. 53. If in Step 32 circulation was not established, skip Steps 54 & 55 and go to Step 56. J%� b . 54. _PU Dump Bailer and dump bail 35' of cement on top of the 9-5/8" CIBP (from 2,050'- 2,015'). WOC. a. 35' of cement in 9-5/8" casing, is 2.6 bbls. ' o„ 3� - �A(zA S,4mF 5. ressure test well to-3;96BT1si, for,i0 minutes. Go to Stepp 64. 4.. /°/•e -ss iD p", a. Once again, note that the 9-5/8" casing is in communication with the 9-5/8" x 13-3/8" _10r"L4 annulus, due to the casing leak @ 103.8'. 30 56. PU 1� set of casing punches and RIH to 2,049'. Punch casing from 2,049' to 2,045'. POOH. 57. PU 2nd set of casing punches and RIH to 1,975'. Punch casing from 1,975' to 1,971'. POOH & RD E - line. L__.�, L,rC tcc{F Va 1A ,1 D` , 58. RIH with 2-7/8" tubing to 2,049'. us ¢cam 59. RU Cementers. Spot a 15.8 ppg cement plug from 2,050' up to 1,800' (250' of cement). a. 100' of Annulus (9-5/8" x 13-3/8") Volume = 6.0 bbls. b. 75' of 9-5/8" casing volume= 5.6 bbls. c. 250' of 9-5/8" casing volume= 18.6 bbls, which is 60% excess cement. 60. PU above cement plug and clean out tubing. 61. Pressure up to 500 psi and hold for 30 minutes, to force cement behind the 9-5/8" casing. a. Casing Punch placement will ensure at least 75' of cement remains on top of the CIBP (which meets all regulatory requirements) and should place at least 100' of cement in the annulus. b. Note that the inside of the 9-5/8" casing is already cemented across the Intermediate Casing Shoe interval (Existing Dual Cement Packer from 2,997' to 2,068'). 62. POOH with tubing, laying down. WOC. H Hikorp Alaska, Lb Well Prognosis Well: BRU 241-34 Date:01/24/2020 i3ex.2 -3o 63. Pressure test well toy,960'psi for inutes. ✓ Note: Records indicate that both the 20" Surface Casing and the 13-3/8' intermediteCasingrwere cemented to surface. The surface Casing was cemented with 800 sacks of cement and reported to have "cement returns to surface". The 13-3/8" casing was cemented with 1,620 sacks of cement, followed by an additional 85 sack "Top Job". With both casing strings cemented to surface, the surface casing shoe is isolated from above and below. Cement Bond Logs (CBLs) run in the 9-5/8" casing (dated 7/20/72 & 7/26/72) show a TOC behind the 9-5/8" casing @ ^'2,755', which is 375' below the Intermediate Casing Shoe. Efforts to isolate the Intermediate Casing Shoe have been addressed in Steps 35-36 and Steps 56-63. 64. RU E -line. PU & RIH with a 9-5/8" CIBP to 160'. Set same depth & POOH. 65. PU Casing Punches and RIH to 159'. Punch casing from 159' to 155'. POOH and RD E -line. a. Note that the 9-5/8" casing has a known leak at 103.8'. 66. Rig up cementers to back side. Establish circulation down the IA through the casing punches and up the 9-5/8" casing. Circulate a 15.8 ppg cement plug from 159'to surface. RD Cementers, WOC. 67. Place dry hole tree on well. 68. RDMO Workover Rig. Post Rig Abandonment Procedures: 69. Excavate cellar, cut off casing 3' below natural GL. 70. NotifyAOGCC and BLM 48hrs in advance. 71. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10. The following must be bead -welded directly to the marker plate: a. Hilcorp Alaska, LLC b. PTD: 172-016 c. Well Name: BRU 241-34 d. API: 50-283-20038-00 72. Set marker plate per -20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. 73. Photo document casing cut-off and Welded Plate install. 74. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic BOPE Schematic CTU BOPE Schematic RWO Sundry Revision Change Form i10'20- RKB to MSL 109.7' RKB to GL=21.5' 1 2 TOC@�` 2,792' 3A S / - 4 C- �i� � 5 6 7 8 9&9A 10 11 12 13 14 ' 15 9 16 17 18 j 19 A i 20 21 p P1 1 P2 �k HA �r TOC @ 18.".. 0,01 -2,142' Z rj�TOC @ 1B2 2,307' C A B C SD D 3sY3` D E WY AiK.4q'-, a/-" TD = 6,501' MD/TVD PBTD = 5,477'Mp/ TVD Max Angle = 1.5 deg @ 958' Holo E E E F Lt G G 5105, H H i_o H CASING DETAII Size Type Beluga River Unit Well: BRU 241-34 Description nn SCHEMATIC � �^ f� j Last Completed: 1986 PTD: 150-283-20038-002-0 Hllcorp Alaake, LLC i10'20- RKB to MSL 109.7' RKB to GL=21.5' 1 2 TOC@�` 2,792' 3A S / - 4 C- �i� � 5 6 7 8 9&9A 10 11 12 13 14 ' 15 9 16 17 18 j 19 A i 20 21 p P1 1 P2 �k HA �r TOC @ 18.".. 0,01 -2,142' Z rj�TOC @ 1B2 2,307' C A B C SD D 3sY3` D E WY AiK.4q'-, a/-" TD = 6,501' MD/TVD PBTD = 5,477'Mp/ TVD Max Angle = 1.5 deg @ 958' Holo E E E F Lt G G 5105, H H i_o H CASING DETAII Size Type WTVH-40Butt Description nn ID Btm 20" Surface 94#tt 2.313 Otis'X' Nipple 19.124" 405'13-3/8" 2.437 Intermediate 68#tt 2,979' 2.313 12.415" 2,380'10-3/4" 2,997 Production Casing 51#d 5 3,548 9.85" 112'9-5/8" 6 Production Casing 43.5#d Otis'XD'Sliding Sleeve, Closed 9/10/94 7 8.755" 5,238'9-5/8" Brown HB -1 Packerw/XO'5, 50k# Production Casing 43.5#tt 2.441 Brown Straight Pull Safety joint32k# 2-3/8" Heater String 46#utt 1.995" 1,829' TUBING DETAILS 1 nn, Strino ID. Depth MD (ft.) ID (in.) Description 1 22 2.41 FMCTubing hanger 2 777 2.313 Otis'X' Nipple 3 2,965 2.437 Brown'CC"Safety joint 3A 2,979' 2.313 2-7/8" Packoff Plug w/ 2-7/8" AD -2 Stop 10/17/19 4 2,997 2.375 Brown Dual Packer, HS -17-2C, SOO 5 3,548 2.441 Brown Straight Pull Safetyjoint 32k# 6 3,580 2.313 Otis'XD'Sliding Sleeve, Closed 9/10/94 7 3,583 4 Brown HB -1 Packerw/XO'5, 50k# 8 3,975 2.441 Brown Straight Pull Safety joint32k# Otis'XD'Sliding Sleeve, Closed 9/20/94 Fish (Plug) 9/2/19 4 Brown HB -1 Packer w/ XO's, 50k# 115U2.313 2.313 Otis'X' Nipple 2.437 Brown 'CC" Safety joint 2.313 Otis'XD'Sliding Sleeve Open 9/20/94 4 Brown HB -1 Packer w/XO's,50k# 2.313 Otis'X' Nipple 16 5,070 2.437 Brown 'CC" Safetyjoint 17 5,102 2.313 Otis'XD'Sliding Sleeve Open 9/20/94 18 5,105 4 Brown HB -1 Packer w/XO's, Sok# 19 5,145 2.313 Otix'X' Nipple 20 5,396 2.205 Otis'XN' Nipple 21 5,428 2.441 Brown Shear Sub Chnrt Ctrina ID. Depth MD (ft.) ID (in.) Description 1A 685 2.313 Oti1%Nipple 1B 2,998 2.313 Otis 'XD'Sliding Sleeve, Open 7/29/98 1B2 3,015 COP 8/31/19 SC 3,037 2.313 Otis'X' Nipple 1D 3,541 2.205" Otis'XN' Nipple Minimum i D Heater String Heater string: 1.751" ID. Depth MD (ft.) ID (in.) Description Short string: 2.205" HA 1,828 1 1.751 1 Otis'XN'Nipple Long string: 2.205" PID2c/Othar Pg' 1 Updated by PMW 03-20-20 Depth MD (ft.) ID (in.) Description MID. 01 2,143 - Cement Pkr-855'9/2/19 P1 5,477 Halliburton Cast Iron BP 07/72 P2 6,455 Float Collar 07/72 Pg' 1 Updated by PMW 03-20-20 B Hilcom Alaska, LLC SCHEMATIC PERFORATION DETAII Beluga River Unit Well: BRU 241-34 Last Completed: 9/21/1986 PTD: 172-016 API: 50-283-20038-00 Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Phase Date$R'pe WSO 3,056'._ 3,057' 3,056' 3,057' 1' 4 0 . 7/26/1972A 3,066' 3,167' 3,066' 3167' 64'* 12 0 9/15/1986B 3,244' 3,340' 3,244' 3,340' 51'* 12 0 9/15/1986C 3,362' 3,503' 3,362' 3,503' 67'* 12 0 9/15/1986D 3,518' 3,545' 3,518'3545' 12'* 12 0 9/15/1986D 3,614' 3,738' 3,614' 3,738' 61'* 4 0 7/30/1972E 3,797' 3,968' 3,797' 3,968' 42'* 4 0 7/29/1972E 4,072' 4,138' 4,072' 4138' 66' 4 0 7/29/1972 F 4,499' 4,503' 4,499' 4,503' 4' 4 0 7/29/1972 Open G 4,732' 5,048' 4,732' 5,048' 74'* 8 0 9/14/1986 Open H 5,137' 5,375' 5,137' 5,375' 110'* 9 0 9/14/1986 R'perf H 5,490' 5,742' 5,490' 5,742' 35'* 4 0 7/23/1972 Plugged, DST H2 *Partially Perforated Interval Pg' 2 Updated by PMW 01-20-20 RKB to MSL 109.7' RKB to GL 21.5' i - B' 20" i C-,i"g =wan: 155' -159' Perforations: _ 2,5001-21505' 12 13 14 15 16 ? 17 ' 18 20 , 21 P1 P2 , 9-5/8 TD=6,501'MD/ND PBTD = 0'M D/TVD Max Angle =1.5 deg @ 958' PROPOSED SCHEMATIC C g Leak @104' TOC @ 1 -2,142' TOC@ 2,307' A B C D E� E E E F G G H H H Beluga River Unit Well: BRU 241-34 Last Completed: 9/21/1986 PTD: 172-016 API: 50-283-20038-00 CASING DETAII C i Grade TOC@��• ID Btm 3 2,792' 3A- Surface 94# 4, s Butt 19.124" 405' Tubing Punch: ' F-- 68# - 3,050-3,054' 12.415" 2,380' r2-3/8" Production Casing 51# P-110 8rd J •nt 112' Production Casing pr N -80/P-110 gr d 8.755 6 Brown HB -1 Packer w/XO's, 50k# r ,' 7 P-110 Butt 8.755" 6,500' 2.313 Tubing Punch: 3,600'-3,604' H I • N-80 • 1.995" • f 4,010 4 Brown HB -1 Packer w/XO's, 50k# 11 4,051 2.313 9 & 9A 12 4,648 10 , Brown 'CC" Safetyjoint 13 11 2.313 - 12 13 14 15 16 ? 17 ' 18 20 , 21 P1 P2 , 9-5/8 TD=6,501'MD/ND PBTD = 0'M D/TVD Max Angle =1.5 deg @ 958' PROPOSED SCHEMATIC C g Leak @104' TOC @ 1 -2,142' TOC@ 2,307' A B C D E� E E E F G G H H H Beluga River Unit Well: BRU 241-34 Last Completed: 9/21/1986 PTD: 172-016 API: 50-283-20038-00 CASING DETAII TUBING DETAILS JEWELRY DETAIL 1 nno Ctrina Type WT Grade Conn ID Btm Top of tubing stub Surface 94# H-40 Butt 19.124" 405' 2.437 Intermediate 68# K-55 .Butt 12.415" 2,380' r2-3/8" Production Casing 51# P-110 8rd 9.85" 112' Production Casing 43.5# N -80/P-110 gr d 8.755 5,238' Brown HB -1 Packer w/XO's, 50k# Production Casing 43.5# P-110 Butt 8.755" 6,500' 2.313 Heater String 4.6# N-80 Butt 1.995" 1,829' TUBING DETAILS JEWELRY DETAIL 1 nno Ctrina P&A PLUGS & CEMENT (ft.) ID (in.) Description A 155' 2.441 Top of tubing stub 160' 9-5/8"CIBP w/ Cement to Surface C -2,050' 9-5/8" CIBPCement on top (TOC @ ^2,015' W2,9972.375 2.437 Brown 'CC" Safety joint E -2,960' 2-7/8" Cement Retainer w/ 75' of Cement on top (TO @ ^2,885') +.S (Squeeze perforations from 3,066' -3,5451) 2-7/8" Packoff Plug w/ 2-7/8" AD -2 Stop 10/17/19 3,050' Tubing Punch from 3,050'-3,054' 2.375 Brown Dual Packer, HS -17-2C, SOO 2-7/8" Cement Retainer w/ 75' of Cement on top (TOC @ "3,515') (Squeeze perforations from 3,614'-3,968') R 2.441 Brown Straight Pull Safety joint 32k# -3,970' 1 2,313 Otis'XD' Sliding Sleeve, Closed 9/10/94 7 3,583 4 Brown HB -1 Packer w/XO's, 50k# 8 3,975 2.441 Brown Straight Pull Safety joint 32k# 9 4,007 2.313 Otis'XD' Sliding Sleeve, Closed 9/20/94 9A 4,007 Fish (Plug) 9/2/19 10 4,010 4 Brown HB -1 Packer w/XO's, 50k# 11 4,051 2.313 Otis'X' Nipple 12 4,648 2.437 Brown 'CC" Safetyjoint 13 4,682 2.313 Otis'XD'Sliding Sleeve Open 9/20/94 14 4,685 4 Brown HB -1 Packer w/ XO's, 50k# 15 4,726 2.313 Otis'X' Nipple 16 5,070 2.437 Brown 'CC" Safety joint 17 5,102 2.313 Otis'XD' Sliding Sleeve Open 9/20/94 18 5,105 4 Brown HB -1 Packer w/XO's, 50k# 19 5,145 2.313 OWX' Nipple 20 5,396 2.205 1 Otis'XN' Nipple 21 5,428 2.441 1 Brown Shear Sub P&A PLUGS & CEMENT Letter: Depth: Description: A 155' Casing Punches from 155'-159' B 160' 9-5/8"CIBP w/ Cement to Surface C -2,050' 9-5/8" CIBPCement on top (TOC @ ^2,015' D 2,500' Tubing/Casing Perforations from 2,500'-2,505' i E -2,960' 2-7/8" Cement Retainer w/ 75' of Cement on top (TO @ ^2,885') +.S (Squeeze perforations from 3,066' -3,5451) F 3,050' Tubing Punch from 3,050'-3,054' 6 -3,590 2-7/8" Cement Retainer w/ 75' of Cement on top (TOC @ "3,515') (Squeeze perforations from 3,614'-3,968') R 3,600' 1 Tubing Punch from 3,600'-3,604' L$ -3,970' 1 2-7/8" CIBP w/ 35' of Cement on top (TOC @ -3,9351) L5 Pg. 1 Updated by PM W 01-21-20 PROPOSED SCHEMATIC eom Alaska, LLC Minimum I.D.: Short string: 2.205" Long string: 2.205" Short Strin¢ Beluga River Unit Well: BRU 241-34 Last Completed: 9/21/1986 PTD: 172-016 API: 50-283-20038-00 Plugs/Other ID. Depth MD I III Depth MD (ft.) ID (in.) Description 2115,477 2,060 2.441 Top of tubin stub VID 2,998313 Otis'XD'Sliding Sleeve, Open 7/29/98 3,057' 3,015 3,057' CIBP 8/31/19 3,037 2.313 Otis'X' Nipple rD 3,541 2.205 Otis'XN' Nipple Plugs/Other ID. Depth MD I III ID (in.) Description 01 1 2,143 - Cement Pkr-855'9/2/19 2115,477 - Halliburton Cast Iron B P2 6,455 - Float Collar 07/72 7!9 PERFORATION DFTAII *Partially Perforated Interval Pg' 2 Updated by PMW 01-21-20 Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Phase Date Status 3,056' 3,057' 3,056' 3,057' 1'4 0 7/26/1972 Sqz rD 3,066' 3,167' 3,066' 3,167' 64'* 12 0 9/15/1986 R'perf 3,244' 3,340' 3,244' 3,340' 51'* 12 0 9/15/1986 R'perf 3,362' 3,503' 3,362' 3,503' 67'* 12 0 9/15/1986 R'perf 3,518' 3,545' 3,518' 3,545' 12'* 12 0 9/15/1986 R'perf D 3,614' 3,738' 3,614' 3,738' 61'* 4 0 7/30/1972 Open E 3,797' 3,968' 3,797' 3,968' 42'* 4 0 7/29/1972 Open E 4,072' 4,138' 4,072' 4,138' 66' 4 0 7/29/1972 Open P 4,499' 4,503' 4,499' 4,503' 4' 4 0 7/29/1972 Open G 4,732' 5,048' 4,732' 5,048' 74'* g 0 9/14/1986 Open H 5,137' 5,375'1 5,137' 5,375' 110'* 9 0 9/14/1986 R'perf H 5,490' 5,742' 5,490' 5,742' 35'* 4 0 7/23/1972 Plugged, DS -F#2 *Partially Perforated Interval Pg' 2 Updated by PMW 01-21-20 YELLOWACKET OILFIELD SERVICES W 13-5/8" SM DOUBLE BOP STACK iA FORGED ANNULAR 3-5/8" 5M IWS DOUBLE RAM BOP •7/8" TO 5" VBR RAMS IN TOP BORE LIND RAMS IN BOTTOM BORE 4-1-16" 5M GATE VALVES 4-1/16" X 2-1/16" DSA ON ENDS TO CO -FLEX 11" 5M DSA TOTAL STACK HEIGHT 106.3 INCLUDING BOTTOM DSA OPEN AND CLOSE DATA OPEN CLOSE 13-5/8" 5M ANNULAR 17.41 23.58 13-5/8" 5M RAMS PER CAVI 4.7 5.34 4-1/16" 5M HCR 0.61 0.52 ff 111Wep At"ka. l,tj: KFII P WH P: 2. 1502 x 2-il Flanged V; (Manual 2-1116 1 O tOK Raige (Manu Coil Tubing BOP Coiled Tubing HR5801njector Head &Gooseneck Weight = 12,8501 4.1116" 10K Conventional Stripper �— 5K 0062 Lubrica—� SK C062 x 4-1/4' 10K Flange 4-1/16" 10K Comb] BOPT,T -- c Ser. , Rp hear Second Sete: Pi,a6llp ' 116" 1OK Flow Cross :77m,-7w4,z-P,,-v Valve 1, T 1501 x&1/16'10K RaNe alva 2.2-1116• i0K x24116' IOK flog,1.3. &1/16' 10K x2-1116" 10K naNe Valva 4. T 1502 x 2-1116' 10K RaWe :1 4.1116" 1 O x Wellhead Adapter Flange Wellhead U a u s v d :n C N d d � R U ❑ U A c U^ v L y G ¢ as Q � a > y o o CX 5 dN Y TA gym L a M N 'O Z d O'} Z d d rn c m r U a) 7 a d u 0 IL Y f0 ❑ d m R a u d rn El -o M Q CL w R I] Beluga River Unit BRU 241-34 133/8 x 103/4 x 27/8x 27/8x23/8 Valve, Swabs, OCT -20, 2 9/16 3M Nple segmen! FE, HWO, T-21 Valve, Masters, OC -20, 2 9/16 3M triple segmented FE, HWO, T-21 Valve, Masters, OC -20, 2 9/16 3M triple segmented FE, HWO, T-21 String #3 Beluga River 241-34 Current 06/26/2019 Tree Cap, 2 9/16 3M Triple segmented x 2 7/8 EUE 8rd lift Valve, Swabs, OC 20, 2 9/16 3M triple segmen FE, HWO, T-21 Valve, Masters, OC -20, 2 9/16 3M tnple segmented FE, HWO, T-21 Valve, Masters, OC -20, 2 9/16 3M triple segmented FE, HWO, T-21 Tubing head, FMC -TC -00, 13 5/8 3M x 11 3M, W/ 2- 2 1/16 SM EFO, BG bottom prep Casinghead, CIW-WF, 13 5/8 3M x 13 3/8 SOW, w/ 2- 2 1/16 5M EFO 2 3/8" -0419 hanger, Triple, FMC. TC -3C. 11 x 2 7!8 EUE 8rd lift and susp, w.r 2 112" type H BPv proliies, AA trim Void test g"" Do 250/3000p5 06/26v'314 V0t0 te,t good to 20CA)pu, t is packed oft With pla ncmje-tion sealaCt in order to mann ain slip seat 06/26/2019 Schwartz, Guy L (CED) From: Ted Kramer <tkramer@hilcorp.com> Sent: Monday, March 16, 2020 4:12 PM To: Schwartz, Guy L (CED) Subject: BRU 241-34 P&A Sundry Application PTD 172-016 - Explanation of Wellhead Attachments: BRU 241-34 current wellhead drawing.docx Follow Up Flag: Follow up Flag Status: Flagged Guy, Attached is a drawing of the current BRU 241-34 wellhead. The construction of this wellhead is a "Master Bowl" setup whereby each string sets in its own mini bowl within the main bowl and each string can be pulled independently from the other two. Hilcorp asks for a waiver to pull the 2-3/8" heater string with the annular. Hilcorp will have a 2-3/8" X 2-7/8" safety joint on the floor during this pull. If any issues develop, the safety joint will be screwed into the 2-3/8" heater string and lowered into the 2-7/8" rams. The rams will then be closed shutting in the well. " ©k r The double gate of the BOP will have 2-7/8" rams in the top cavity and blind rams in the bottom cavity. Hilcorp will pull the 2-3/8" heater string first, then each 2-7/8" string will be cut and pulled one at a time. The hanger will be "hooked" and pulled after the other three strings are out of the well. I hope this clarifies the sequence of the pulling of the well. -8 *%?I" Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp-Alaska LLC Office — 907-777-8420 Cell — 985-867-0665 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 17 20 16 Debra Oudean Hilcorp Alaska, LLC 3 1 4 4 9 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Hfln,.p AlaA.. LU Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE 11/20/2019 To: Alaska Oil & Gas Conservation Commission Natural h Resources Technician RECEIVED 333 W. 7t^ Ave. Ste# 100 `drr Anchorage, AK 99501 NOV 2 0 2019 AOGCC CD: ACJ(.06JUL19 7/30/201911:06AM Filefolder MFC _05)UL19_LS 7/30/201911:05AM Filefolder MFC 05JUL19 SS 7/30;'201911;06Ah4 Filefolder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS r1 r.lU C 1'1 L U NOV 15 2019 AOCaCC 1. Operations Abandon LJ Plug Perforations Fracture Stimulate Lj Pull Tubing U Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well �2r Re-enter Susp Well ❑ Other: XZ I ikzj ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 15. Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ Stratigraphic❑ Service 116. 172-016 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, API Number: AK 99503 50-283-20038-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA029657 Beluga River Unit (BRU) 241-34 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beluga River/ Undefined Gas 11. Present Well Condition Summary: Total Depth measured 6,501 feet Plugs measured 5,477 feet true vertical 6,501 feet Junk measured N/A feet Effective Depth measured 5,477 feet Packer measured 3,001 feet true vertical 5,477 feet true vertical 3,001 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 16' 30" 44' 44' Surface 381' 20" 405' 405' 1,530psi 520psi Intermediate 2,356' 13-3/8" 2,380' 2,380' 3,450psi 1,950psi Production 90' 10-3/4" 112' 112' 8,060psi 3,670psi Liner 6,267' 9-5/8" 6,389' 6,389' 6,330psi 3,810psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 2-3/8" Heater 4.6# / N-80 1,829' MD/TVD Tubing (size, grade, measured and true vertical depth) (2) 2-7/8" 6.5# / N-80 5,429'& 3,543' MD/TVD Bm HS -17-2C Dual Pkr 3,001' MD/TVD Packers and SSSV (type, measured and true vertical depth) N/A N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mct Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 10 4591 43 1 175 166 Subsequent to operation:1 0 0 0 1 265 1255 14. Attachments (required per 20 AAc 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory❑ Development p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Lj Gas ✓ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ sUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-330 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(o)hilcoro.com d /A� Authorized Signature: �/%^ W/� D�i! ' 1 �/s 17ontact Phone: 777-8420 Form 10-404 Revised 4/2017 X I//yf/Y -141 /j-2;�—, .IT-4gDMSA /Nnv i n mia Submit Original Only / C Beluga River Unit Well:BRU 241-34 S/fEMATSl0 Last Complete d: 9/21/1986 " PTD: 172-016 HlLC _6-45-.t4 API: 50-283-20038-00 RKB to MSL =109.7 RKB to G1.=21.5' CACINlr: nGTAII 13-3/8-M TOC @ 2,792' 3 3A 4 I 9-5/8" TD = 6,501' MD/TVD PBTD = 5,477'MD/TV D Max Angle =1.5 deg @ 958' Size Type WT GradMnI AID-. 1 D Btm20" FMC Tubing hanger Surface 94# H-4024" Otis'X' Nipple 3 405'13-3/8" 2.437 Intermediate 68# K-5515" 2.313 2-7/8" Packoff Plug w/ 2-7/8" AD -2 Stop 10/17/19 2,380'10-3/4" 2,997 Production Casing 51# P-1105" 2.441 113'9-5/8" Production Casing 43.5# N -80/P-55" 5,238'9-5/8" Brown HB -1 Packerw/XO8 Production Casing 43.5# P-11055" Brown Straight Pull Safety9 6,500'2-3/8" 2.313 Heater String 46# N-8095" Fish (Plug) 9/2/19 1,829' `Min I.D. L Heater string: 1.751" 1 Short string: 2.205" \ng string: 2.205" A � i" B C �VV �Jf{{ D „.C)r"t I UUINCi JEWELRY DETAIL Lona Strina Short Strina Depth MD (ft.) ID (in.) Description AID-. 1 22 2.41 FMC Tubing hanger 2 777 2.313 Otis'X' Nipple 3 2,965 2.437 Brown 'CC" Safetyjoint 3A 2,979' 2.313 2-7/8" Packoff Plug w/ 2-7/8" AD -2 Stop 10/17/19 4 2,997 2.375 Brown Dual Packer, HS -17050k#3,548 2.441 Brown Straight Pull Safety3,580 2.313 Otis'XD' Sliding Sleeve, Cl943,583 4 Brown HB -1 Packerw/XO8 3,975 2.441 Brown Straight Pull Safety9 4,007 2.313 Otis'XD'Sliding Sleeve, Cl949 4,007 Fish (Plug) 9/2/19 4,010 4 Brown HB -1 Packer w/XO' 1 4,051 2.313 Otis'X' Nipple 12 4,648 2.437 Brown 'CC"Safetyjoint 13 4,682 2.313 Otis XV Sliding Sleeve Open 9/20/94 14 4,685 4 Brown HB -1 Packer w/ XO's, 50k# 15 4,726 2.313. Otis'X' Nipple 16 5,070 2.437 Brown 'CC" Safety joint 17 5,102 2.313 Otis'XD'Sliding Sleeve Open 9/20/94 5,105 4 Brown HB -1 Packer w/XO's, 50k# a202l 5,145 2.313 Otix'X' Nipple 5,396 2.205 Otis'XN'Nipple 5,428 2.441 Brown Shear Sub Short Strina Heater String 11 ID. 1 Depth MD D Descpo HA 1,828 1.751Otis'N Plugs/rlthpr ID. Depth MD (ft.) ID (in.) Description 2,143 - Cement Pkr-855' 9/2/19 2.313 Otis'X'Nipple ;1D.M3,O P2 2.313 Otis'XD'Sliding Sleeve, Open 7/29/98 CIBP 8/31/19 2.313 Otis'X' Nipple 2.205" Otis'XN' Nipple Heater String 11 ID. 1 Depth MD D Descpo HA 1,828 1.751Otis'N Plugs/rlthpr ID. Depth MD (ft.) ID (in.) Description 01 2,143 - Cement Pkr-855' 9/2/19 Pl 5,477 - Halliburton Cast Iron BP 07/72 P2 6,455 - Float Collar 07/72 Pg' 1 Updated by DMA 11-01-19 5 B Hgmrn AMA.. LLC SCHEMATIC PERFORATION DETAIL Beluga River Unit Well: BRU 241-34 Last Completed: 9/21/1986 PTD: 172-016 API: 50-283-20038-00 Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Phase Date Status W50 3,056' 3,057' 3,056' 3,057' 1' 4 0 7/26/1972 Sqz A 3,066' 3,167' 3,066' 3,167' 64'* 12 0 9/15/1986 R'perf B 3,244' 3,340' 3,244' 3,340' 51'* 12 0 9/15/1986 R'perf C 3,362' 3,503' 3,362' 3,503' 67'* 12 0 9/15/1986 R'perf D 3,518' 3,545' 3,518' 3,545' 12'* 12 0 9/15/1986 R'perf D 3,614' 3,738' 3,614' 3,738' 611* 4 0 7/30/1972 Open E 3,797 3,968' 3,797' 3,968' 42'* 4 0 7/29/1972 I Open E 4,072' 4,138' 4,072' 4,138' 66' 4 0 7/29/1972 Open F 4,499' 4,503' 4,499' 4,503' 4' 4 0 7/29/1972 Open G 4,732' 5,048' 4,732' 5,048' 74'* 8 0 9/14/1986 Open H 5,137' 5,375' 5,137' 5,375' 110'* 9 0 9/14/1986 R'perf H 5,490' 5,742' 5,490' 5,742' 35'* 4 0 7 23 1972 Plugged, DST N2 *Partialiv Perforated Interval P8' 2 Updated by DMA 11-01-19 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 241-34 50-283-20038-00-00 172-016 8/6/19 10/17/19 Daily Operations: 08/06/2019-Tuesday Pollard E-line crew and Yellow jacket tool hand arrive on location. MI RU PESI E-line unit. WHP 150. Make up 13/8" x 12" rope socket 1-11/16" x 5' wgt bar, 1-11/16" x 6.7' Gamma and 2.25" gauge ring. Stab on well. PT stack 250/3,500 psi. Bleed down. Open well and RIH. Drift tubing to 3,220' clean. POOH. Make up Avylon WRP plug with Yellow jacket tool services. 2.2" OD. RIH. Log from 3,150 to 2,800'. Good image of packer and x nipple. Set Top of WRP at 3,028'. POOH to surface. Make up Dump bailer and extensions. Load sand. RIH and Tag top of plug at 3,028', break glass with charge. PU slowly allowing sand to dump. PU 50' RIH and tag top of sand at 3,015'. POOH to surface. Final WHP 162 psi. Rig down Pollard E-line services. Crew on plane to Kenai. 08/14/2019- Wednesday Travel from Kenai to Beluga on Twin Otter. PTW, JSA. Move CTU 13 from H pad to F pad. Lay pit liner. Spot equipment. Swap Goose neck rollers, Injector blocks, and pack offs from 2.375" to 1.75". Spot supply and return tanks. Load supply tank with 375 bbls. Rig up hard line. Install flange x 1502 on IA and rig to return line. Attempt to remove wellhead bolts. 3 of 5 bolts broke free. 2 bolts remain seized . Spray bolts with Kroil. SDFN. Plan in AM is to remove remaining wellhead bolts. RU BOPE and test 250/3,000 psi. 08/15/2019-Thursday PTW, JSA. Cold cut remaining 2 wellhead bolts. Install BOPE. Rig up from flow cross to backside choke line with 1502. Plug in BOPE hydraulic hose and function test. Test BOPE 250/3,000 psi. 24 hr BOPE test witness notification sent 8/14/19 @ 0816. Witness waived by Jim Regg 8/14/19 @ 11:22 am. BOPE test complete. No failures to indicate. Make up 2.125" CC and 2.125" Hydro disconnect with 9/16" ball. Make up Weatherford one sent cement retainer. 2.3" OD x 5.5'. cement retainer is .5" Ball drop . Line up with produced water down Short string. Taking returns up 9-5/8" IA valve below grating to return tank. Open well. WHP 280 psi. Start bleeding IA and pumping down SS at 4 bbls/min. After 30 bbis pumped well went on vac. 9-5/8" annulus volume is 195-208 bbls. Pumped 233 bbls of produced water. Surface safety valves shut due to low pressure. Attempted to open long string (long string was flowing while pumping short string). Long string died off. Indicating large leak at the dual packer at 2,997' and Holes in long string at 3,376' and ,3470'. Call town to discuss. Rig back CTU injector head from well. Install night cap on BOPE. Location walk around complete. SDFN. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 241-34 50-283-20038-00-00 1 172-016 8/6/19 10/17/19 Daily Operations: 08/16/2019 - Friday Wait for Pollard E -line to arrive. Production operators shoot fluid levels. Long string showing 1,300'/1,800'/1,650'. Short string showing 980'/880'/685'. Slick line arrive at Beluga. PTW /JSA. Mobe equipment to location. Rig up and PT lubricator to 250/2,000 psi. Surface pressures. OA 237, IA 240, Long string 219, short string 229 psi. RIH on short string with 2.25" LIB to 952'KB tag fluid level. POOH. Hole in short string at 845'. Move slick line unit to long string. RIH with 2.25" LIB to 3150' fluid level. Check 3 times to confirm. Continue in hole to see if we can pass holes in tubing at 3,376' and 3,470'. Passed one time to 3,650'. Picked up and couldn't get past 3,380' . Tagging top of first hole. POOH. Ledge of LIB looks like its catching a lip. Move to short string. RIH with 2.25" LIB to 3018' Tag top of sand that was dumped on WRP plug. Work heater string wellhead cap. Remove with 48' pipe wrench and a come along. RU Pollard Pump in sub and SLB 1502 iron. IA pressure 240. Bleed IA pressure on 9-5/8" casing to return tank while pumping 3.5 bbls/min down 2.375" heater string. pump 88 bbls well on vac IA 0 psi. Dump 2x 5 gallon buckets of Green Diamond 20/50 sand into heater string. Install night cap. Displace with 10 bbls produced water. RIH on short string with 2.25" gauge ring to 952'. Fluid level never changed. Sliding sleeve at 2,998' may be closed. Lay down Pollard Slick line. SDFN. All 3 strings shut in. Final Pressures OA 25, IA 25, Long 13, short 17.5 psi. 08/17/2019 -Saturday PJSM, PTW. Pollard slick line. SLB COIL, SLB cementers. Cruz Construction. RU slick line on SS. Pick up lubricator stab on P sub. Make up tools. Initial pressures. Long 57 psi, short 57 psi, Heater 57 psi, IA 67 psi, OA 67 psi. RIH with B 042 shifting tool with positive keys to 684'. Stack down at X nipple. Tool would not fall through. POOH. Add knuckle joint above shifting tool. Attempt to RIH. Not able to pass 684'. Tool sheared and fell in hole to 3,015'. Fluid level still at 952'. Flight with correct sleeve shifting tool on weather hold. Rig up SLB 1502 iron to slick line pump in sub. RIH w/ 2-7/8" BO 142 Shifting tool to 2,998' Tap Down Tool feel through to 3,018' Pick up cannot re locate. Sleeve shifted open. NO change in pressure. POOH to surface. RIH w/ 2.25" LIB to 2,200'. Tag Fliud level. Previous tag 952'. Good indication that sleeve has shifted. Rig down slick line unit. Online down SS with SLB pump. Pump down SS @ 5 bbls/min. Taking returns up 9-5/8" IA. Bottoms up volume is 195-208. Pumped 255 bbls no returns to surface. No increase in pressure.. Final pressures Long 57 psi, short 57 psi, Heater 57 psi, IA 67psi, OA 67 psi. Rig down SLB cementers and SLB coil. Cementers fly out on chopper. 08/29/2019 - Thursday Crews at Otter hanger waiting on weather. Travel to Beluga. Move coil package from N pad to F pad. Lay pit liner. Spot equipment. Spot return tanks. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 241-34 50-283-20038-00-00 172-016 8/6/19 10/17/19 Daily Operations: 08/30/2019 - Friday Pre job safety meeting. PTW, JSA. Continue rigging up CTU 13 with 1.75" pipe. Run 1502 iron to OA tree valve. Load 400 bbls in supply tank. Remove tree flange on short string. Install triple string x over to 4.06" 10M flange. Make up riser and BOPE stack. 4.06" Quad BOPE. Make up BOPE hydraulic hoses. Made up BOPE to short string. Function test BOPE. Start BOPE test. 24 hr BOPE test witness notification sent 8/28/19 @ 1:44 PM. Witness waived by Jim Regg on 8/29/19 @ 0825 AM. Test all rams and valves 250/3000 psi. Good BOPE test. Pick injector head. Stab 2x 10' lubricators. Cut 20' of pipe. Dress coil. Make up Yellow Jacket fishing string. 2.25" OD x.77' External slip coil connector, 2.0" OD x .54' x over, 1.68" OD x 1' DFCV, 1.68" OD x 5' Dual Acting jars, 2.25" OD x 1.41' (2.5" GS spear) flow activated. BHA length 10.05'. (MHA down to disconnect was pressure tested 250/3,000 psi). Coil connector pulled to 25K. Stab on well with injector head. Pressure test lubricator 250/3,000 psi. Bleed down. Open well. 193 psi. IA 265 psi, OA 265 psi. RIH. Estimated top of sand 3,018'. Bottoms up from top of Avalon plug 9 bbls. Clean running in hole weight -400 lbs. Pick up weight at 3,005' 9,000 lbs. Tagged with coil 5k down at 3021'. Pick up clean. Park at 3000'. Lined up down coil with produced water. Pump bottoms up prior to cleaning sand. Crack choke to bleed wellhead. 171 psi on WH. 1.7 BPM @ 3,569 psi Coil pressure. Wash up and down from 3,000'-3,029'. Pumped 4 bottoms up. 280 bbls in return tank. Shut down pump. RIH to latch G spear. Stack down at 4k down. pick up. 18k. Jars fired. Pull out 5'. Shut down and park to let elements expand. Clean pick up weight at 8,000 lbs. 2987 Dropped 2k weight. Possibly shifted sliding sleeve closed. POOH to surface. Tagged up at surface. Close master and swab. Pop off well. Avalon WRP recovered. Break down BHA. Well died while pumping sand off plug. 0 psi SITP on short string. Set down injector head. Night cap installed on BOPE. Location secure. SDFN. 08/31/2019 -Saturday PJSM, PTW with SLB coil and Cruz construction. Coil crews Remove BOPE stack from short string to allow access for E line to short and long string. Pollard E -line arrive at Otter hanger and travel to Beluga. PES] rig up skid unit, make up BHA. CCL, setting sleeve and 2-7/8" CIBP. Stab on well. PT lubricator 250/3,000 psi. Open well. WHP 100 psi. RIH Log strip from 3050' to 2900'. Find sliding sleeve and packer and tie in. Drop down and pull up to 3,002.2' CCL depth. Set CIBP top at 3,015'. Pick up hole and Tag plug. Good set. POOH to surface. Swap over to long string. Make up 2-7/8" CIBP and setting sleeve. Stab on well. PT stack 250/3,000 psi. Open well RIH WHP 55 psi. (Long string has holes in tubing at 3,376' and 3,462.2') Pull pass from 3,600'-3,400' Drop back down. Park CCL at 3,462.2' Set CIBP at 3,475'. POOH to surface. Rig down PESI. Slick line day crew en route to location. RU Pollard Slick line on short string. Make up BHA. Rope socket, stem, stem, spangs, Otis XD shifting tool. Tool setup to shift down to open. RIH find sleeve at 2,996'. Sleeve is closed. (closed from coil WRP removal). Spang down for 20 minutes. Drop through and tag top of CIBP at 3,012' SLM. PU through XD sleeve and attempt to run back in. No engagement of sleeve. Sleeve is open. POOH to surface. Fluid level was at 2,475'. Rig down SL. SLB coil crews rigging up BOPE stack on SS. Location secure. SDFN. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 241-34 50-283-20038-00-00 172-01610/17/19 Daily Operations: 09/01/2019 -Sunday PJSM. PTW. Report is for Short String work. Pick injector head. Stab 10' lubricator. Make up 2.125" OD dimple connector. Pull test 25k. Make up X over, 2x 1.75" stinger 46" each, 6" ball drop nozzle (cement nozzle). Stab on well. PT stack 250/3000 psi. Open well. IA 90 psi, OA 90 psi. SS 45 psi. RIH with 1.75" CT to 2980'. Weight check 5k. Slack back off to 2980'. Bleed down IA (9 5/8" casing) to return tank. Cement plan . Loaded on truck original 18 bbls of squeeze slurry (blended). 2nd truck is 35 bbls of 15.8 class G cement. Pump 25 bbls of lease water down CT. Cementers pulling on mix fluid. Fluid pack with cement pump and fresh water 5 bbls ahead. Close in cement line and PT 250/5000 psi. Cement Wet at 1040 AM. Online down coil with 15.8 ppg cement. 1.6 BPM. Pressure increasing to 4000 drop rate to .6 bbls/min. 57 bbls of cement pumped. Followed with 5 bbls of fresh water. Swap to coil pump for displacement. Coil volume 33.8 bbls. -5 bbls of post flush from cement pump. Chase with coil pump at 28.8 bbls. POOH from 2,980'. At surface. Close in short string and IA. 0 psi on all strings. Wash up and down through lubricator. Estimated 300' of coil on reel has light cement residue on it. Good sign we have cement above packer at 2998'. Blow down stack. Pop off well. Break down tools. Rack back injector head. Cementers cleaning up pump and Rigging down. Location secure. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 241-34 50-283-20038-00-00 172-016 L8/6/19 1 10/17/19 Daily Operations: 09/02/2019 - Monday PTW, JSA. Pick injector head. Stab 2 x10' lubricators. with 1.75" CT make up Quadco MHA. External Dimple connector, 2.13" OD x.48', x over 2.13" OD x.79', DFCV 1.7" OD x 1.29', TTS Jars 1.70" OD x 5.14', TTS disconnect 1.70" OD x 1.43', Circ Sub 1.7" OD x.85', Titan Motor 1.7" OD x 11.14', 3 bladed junk mill 2.30" OD x.8'. Total BHA length 21.92' Coil connector pull tested 25k, MHA PT 250/4000 psi. Stab on well. PT stack 250/3,000 psi. Bleed down to 0. Open well. RIH SS=O psi, LS=O psi, IA=O psi, OA= Opsi. set down 5k at 2,173'. Pick up clean. Online down coil at 1.1 bbls/min. Mill cement stringers from 2173'-2184'. Stall motor twice at 2,184'. TOC is 2184'. 9-5/8" with 1 string of 2-7/8" tubing is 15 ft/bbl volume. 57 bbls of cement was pumped through short string sliding sleeve. 57 bbls x 15 ft/bbl gives a cement column above packer of 855'- Packer depth of 2998= 2143' calculated cement top in 9-5/8" casing. CT tag in SS within 40' of calculated cement top. Milled cement to 2,307' to confirm solid cement column wasn'tjust cement stringers. Confident good cement top. POOH to surface. Swap BOPE stack from SS to LS. PT stack 250/3,000 psi for 5 minutes. Good PT. Open well. LS, SS, IA, OA all 0 psi. RIH tag top of CIBP at 3480'. CIBP was set with E-line at 3,475'. Start Milling CIBP. 3,481.6' Milled to 3,483.2' through plug. Pushing plug down hole. Plug stuck in sliding sleeve at 3,580'. Attempt to mill. After multiple stalls plug has fell through sliding sleeve. Work plug down to the next sliding sleeve at 4,007'. Attempt to work CIBP through sleeve at 4,007' for 1.5 hours. No luck. After motor stalls Pick up 5-10K over pulls. POOH to surface to inspect mill and motor. Break down motor and mill. Install new motor. PT BHA 250/3,000 psi. Install 3 bladed junk mill. Stab on well. PT stack 250/3,000 psi. RIH. Tag Fish/ Obstruction at XD sliding sleeve at 4,023' CTMD. Attempt to start a pattern and mill. Heavy stalls. Definitely metal to metal. Multiple attempts made to start a milling pattern. Possibly spinning remainder of CIBP. Work coil and pump rates at different speeds and rates. Attempt to hit down with jars, Not able to pass through XD sleeve. POOH to surface. No luck getting through XD sliding sleeve at 4007'. While POOH to surface noticed WHP increasing. 30 psi to 120 psi. Open choke. Fluid and Gas at surface. Possibly opened sliding sleeve and swabbed in a gas column. Bleed down to zero psi. Closed choke. Pressure back to 120 psi. Tagged up at surface with coil. Bleed WHP 120 psi off to return tank while monitoring. Close choke. Pressure did not climb . Close well. Blow down lubricator. Pop off well. Inspect mill. Only wear on mill are on the outside edges. Break down BHA. Stack down lubricator. Set injector on deck. Install night cap on BOPE. SDFN. 09/03/2019-Tuesday ARRIVE AT AIRPORT - ON WEATHER HOLD. ARRIVE AT BELUGA. PERMITS, JSA, JOB SCOPE. SPOT EQUIPMENT, BEGIN RIG UP TO LONG STRING ON WELL. RIH W/ 2.25" LIB TO 3,942' KB - POOH - NO SIGNIFICANT IMPRESSION. RIH W/ 2-1/2" GS W/ 2-7/8" AD2 STOP SIT DOWN AT 1,042' KB WT CAN'T FALL PIN SHEARED, POOH. RIH W/ SAME PINNED WITH 3/16" SHEAR PIN TO 3,015' KB WT- POOH - AD2 STOP SET. STAND BY FOR SCHLUMBERGER TO PUMP 30 BBL TO KILL WELL. RIH W/ 2-1/2" GS W/ 2-7/8" W. PACKOFF PLUG W/ KOBE TO 3,016' KB. SET PLUG - POOH. RIH W/ 2-1/2" GS W/ 2-7/8" AA STOP TO KB. SET STOP - POOH. Line up SLB pump down LS tubing. Bullhead and pump 15 bbls. Pressure up to 600 psi. All strings read 600 psi. Pressure between LS, SS, IA, OA track. Possible leak in LS close to surface. RU pollard E-line. Make up CBL logging tool. RIH and Log from 3,000'-2,068'. Found cement top 2,068'. Questionable cement quality from 2,068' to 2,300'. 2,300' to 3,000' good cement. OOH with E-line. Rig back. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permii Number Start Date End Date BRU 241-34 50-283-20038-00-00 172-016 8/6/19 10/17/19 Daily Operations: 09/04/2019 - Wednesday PTW JSA with pollard SL. Rig down Pollard E -line. RU Slick line unit. RIH w / equalizing prong To 3,015' KB wt, Well goes on vac, POOH. RIH W/ 2-1/2" GS TO 3,013'KB, LATCH AA STOP - POOH. RIH W/ 2-1/2" GS TO 3,015'KB, LATCH PACKOFF PLUG - LET ELEMENT RELAX - POOH. RIH W/ 2-1/2" GS TO 3015'KB, LATCH AD -2 STOP - POOH. Fluid level 3,000'. RIH W/ 2-7/8" BO SHIFTING TOOL (W/ SELF RELEASE KEYS IN THE DOWN POSITION TO VERIFY SLEEVE IS OPEN) TO 4,012' KB, SIT DOWN WT - CANNOT FALL TO SLEEVE DEPTH - POOH. BEGIN RIG DOWN. TURN IN PERMITS - SIGN OUT OF FACILITY - MOB EQUIPMENT TO SHIRLEYVILLE. PU CTU injector head. Stab 10' lubricator. Make up 2x 1.75" stinger and 1.75" jets swirl nozzle. Stab on well. PT stack 250/3,000 psi. Cooling down N2. Open well RIH. WHP 130 psi. CT depth 1,500'. Online with N2 down CT at 1,000 scf/min. Tag 4,015' CTMD. CIBP milled and stuck at depth. Fluid returns and N2 to surface. Work CT from 4,015' up to 2,650'. Repeat interval through blow down. Unloaded 27 bbls of fluid. Well is blowing N2. Not lifting any more fluid. POOH to surface. Shut down N2. Tag up. Close master and swab. Rig down CTU. Rig down SLB CTU 13 and take equipment to barge landing. 10/17/2019 - Thursday RIH W/ 2.25" GR to 3,300' kb. Tubing is clear. Set 2-7/8" AD2 stop and 2-7/8" DD packoff plug @ 2,985' and 2,982' respectfully. Rig Down, Park equipment. 14-4'L ,� s MD I1 Scale 49 2380 2,965 li 3,01411 3,064Alt-N,3,113 31Rp 1 L; _ 5477' �ConocoPhillips } { Gas Producer HA Dual Comp. +AnnularFlow 4 Sect. 34, T13N, R10W, NE 1/4 x� P'k- ASP @ Beluga: 2,624,279, 316,519 BRU 241-34 API# 50-283-20038-00 Annulus Fluid: Produced Gas (Annular Flow) Max Hole Angle: 1.5° @ 958' Spud Date 6/17/72 RKB to Ground: 21.5' Last Completion 9/21/86 RKB to SL: 109.7' Schematic Rev. 5/18/06 1 Hole By: Bearden 26" A Surface Csg. 20" 405' 94. # H-41 Buttress 1 c 350sx "G" in 10x13 Annulus Intermediate - 13 3/8" 2,380' 68. # K-55 Buttress 2,997'_ Pkr Brown Dual, HS -17-2C, 50k# Prod. Casing 103/4 113' 51. If P-110 8rd _Packer, Safety It, Brown Straight pull 32k# B B Prod, Casing Prod. Casing 95/8 95/8 5,238' 6,500' 43.5 If 43.5 # N -80/P-110 P-110 8rd Buttress /C 2.313" Prod. Tbg (Htr) 2 3/8" 1,829' 4.6 # N-80 Buttress 4.00" C Prod. Tbg. 2 2 7/8" 3,543' 6.5 # N-80 EUE-8rd / Sqz'd 365 sx cmt Prod. Tbg. 1 2 7/8" 5,429' 6.5 # N-80 EUE-8rd D Str. tbl. Top Pkr Pa,: er,_Bruwn HB -1 w( XO's, 50k# JEWEL RY& FISH 4.00"� 2z 26" 800sx"G". 17 1/2" 1620sx "G". Bump plug. 12 1/4" 585sx @shoe, 475sx @ 3512' 12 1/4" collar. Bump plug 2500psi 1 c 350sx "G" in 10x13 Annulus 2 x 2,998' SS -XD Sliding Sleeve, Otis "XD" Open 7/29/98 3.20' 2.313" 3.719" 2 y . 3,037' "X" Nipple, Otis 1.20' 2.313" 3.25" Bail Fill or Perf TBG between X 1 b - 777' "X" Nipple, Otis 1.20' 2.313" 3.25" 1 q 5,102' SS -XD 1 c 2,965' Safety It, Brown "CC" 1.40' 2.437" 3.625" Packer, Brown HB -1 w/ XO's, 50k# Nipple, Otis 1 d ^_ 2,997'_ Pkr Brown Dual, HS -17-2C, 50k# 7.15' 2.375" G 1 t 5,396' "XN" 55 1 e 3,548' _Packer, Safety It, Brown Straight pull 32k# 0.90' 2.441" 3.50" 1 f 3,580' SS -XD Sliding Sleeve, Otls'7[D" Closed 9/10/94 3.20' 2.313" 3.719" E _ 1_2. 3,583'V Packer, Brown HB -1 w/ XO's, 50k# 9.22' 4.00" Zone IR Stn. 1 h 3,975' _Pkr Safety Jt, Brown Straight pull 32k# 0.90' 2.441" 3.50" Sqz'd 365 sx cmt F 1 I 4,007' SS -XD Sliding Sleeve, Otis "XD" Open 9/20/94 3.20' 2.313" 3.719" 1 j___ 4,010' Pkr Pa,: er,_Bruwn HB -1 w( XO's, 50k# 9.70' 4.00"� Orig 4 SPF, Reperfd 8 SPF 1 k 4,051' _ "X" Nipple, Otis 1.20' 2.313" 3.25'r' 09/86 F 1 L 4,648' Safety It, Brown "CC" 1.40' 2.437" 3.625" 4 61' F 1 m 4,682' SS -XD Sliding Sleeve, Otis "XD" Open 9/20/94 3.20' 2.313" 3.719" Bail Fill or Perf TBG between X 1 p 5,070' Safety Jt, Brown "CC" 1.40' 2.437" 3.625" 3541TRKB 2.3" Gauge ring 1 q 5,102' SS -XD Sliding Sleeve, Otis "XD" Open 9/20/94 3.20' 2.313" 3.719" 2/14/03 1 r 5,105' Pkr NV--- ______ 1 s 5,145' 'x" Packer, Brown HB -1 w/ XO's, 50k# Nipple, Otis 9.00' 1.20' 4.00" 5/17/06 5366' RKB 1.5" Gauge ring G 1 t 5,396' "XN" Nipple, Otis 1.26' 2.205" 3.25" 1 u 5,428' Shear Sub, Brown 2.441" 3.75" Pressure Datum: Sterling 3450' S5: 3,560'MD Beluga 4000' SS: 4,110'MD PERFORATIONS FILL & PLUGS Net Zone IR Stn. Status Date SPF FI, G WSO 3,056' 3,057' Sqz'd 365 sx cmt 07/72 4 A 3,1166' 3,167' B 3,244' 3,340' Ong 4 SPF, Reperttl 8 SPF Orig 4 SPF, Reperfd 8 SPF 09/86 09/86 12 64' 12 51' C 3,362' 3,503' Orig 4 SPF, Reperfd 8 SPF 09/86. 12 67 H D 3,518' 3,545' Orio 4 SPF, Reperfd 8 SPF 09/86 12 12' D 3,614' 3,738' Open, String 1 - Top Interval 07/72 4 61' E 3179L_._ju968' O Lnn S7r 1 _Toyinterval 07/72 4 42' H E 4,072' 4,138' Open, String_1 - Upper mid interval _ ^ 07 7z 4 66' F___ 4,499' 4,503'_ -_Open, String 1 - Upper. mid interval 07/72 4 4' Bail Fill or Perf TBG between X H PLUG 5,477' Halliburton cast iron BP H 5,490' 5,742' Plugged. DST #2 H y PBTD 6,455' Float Collar at 6455' 07/72 V 07/72 4 35' 07/72 C TAGS Slr 2 5/3/91 3541TRKB 2.3" Gauge ring � 9/20/94 5445'RKB CTU FCO 75117/06 O 7/30/98 3541'RKS 2.31" PXN Plug 2/14/03 5425'RKB 2" D.D. Bailer 1- 3582' RKB 1.5" Gauge ring 5/17/06 5366' RKB 1.5" Gauge ring PBTD 6455 /r� = Jul -98 Annular flow for Str 2 started after sliding sleeve at 2998 & MIT on 10-3/4" showed on 55 psi drop in 1 hour. a!� Schwartz_ From: Sent. To: cc: Subject. Guy, Ted Kramer <tkramer@hilcorp.com—�'_,�� Monday, August 26, 2019 10:09 AM Schwartz, GUY L (CED) Rixse, Melvin G (CED) RE: [EXTERNAL] RE. BRU 241-34 - Update 8-20-19, PTD 172-016 1 re -wrote the procedure incorporating your notes below. The BRU 241-34 work plan is as follows: 1•) "IRU Coil Tubing and test st BOP (notify AOGCC and BL 2•) C/O long strip M 48 hours in advance to Coil. Nitro g to 3 590' (Note: may continue to give them the 3• RU gen may be used.). RIH to see how dee Opportunity to RUE -line to long strip . 4•) RU to short g PU/RIH W/ CIBP to 3,590' P we can get for future, POOH ort string. and set, POOH W/ 5•) RU Coil g PU/RIH with CIBP Tubing to SS. PU sin to 3,015' and set. POOH. 6•) RU Cementers and pressure est et retainer and RIH tlines.o 2,_9 (+ _ 7•) Pump cement job ( +/_ 53 bels /) Set same. WOC. class g cement). B•) RU Coil to Un sting from retainer. PU SS. Drill out tubing to just below the 50 Clean CIBP . RU Nitrogen. Bio up coil tubing. 9•) RU Coil to LS p w tubing d Packer (3,005' , POOH. U mill an dry. POOH. ) Perform negative mm on chart, d motor and RIH drillingtest. Contin 10.) Continue out Cement to Continue to drill out drilling out cement2'900,• Pressure Nitrogen. POO and CIBP at 3, test tubing 11. RU H. RD" Coil tubing. 590 (+/- • p g to 1,000 psi for 30 E -line on LS ) Push to bottom. Drop PT lubricator to 3 000 p ball, blow top packer (2,997'). POOH. psi. PU RIH w tubing dry with 12.) PU 2" / CBL to 3,585'. Log to 1,800' or to 3,340' peffguns, RIH on Long string and re- 3,362- ns, RI . Perforate the P of cement above the 13.) Fluid pack void above A'B�C.and 14-,TumFluid p Packer, upper D sands ( 3,066 – 3,167' over to production to bleed down3'244 – Once his and test. t work is completed, the leak from the IA to OA will Sincerely, be addressed. Ted Kramer Sr. Operations Engineer Hilcorp-Alaska LLC 3ffilce – 907-777-8420 :ell – 985-867-0665 1 ost e I )p lent Schwartz, Guy L (CED) From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, August 21, 2019 11:30 AM To: Schwartz, Guy L (CED) Subject: BRU 241-34 - Update 8-20-19, PTD 172-016 Guy, I wanted to give you an update on the above well. We did dump sand on the packer to see if we could get some sort of a platform to place the cement on. That proved unsuccessful as our subsequent pump in test was identical to the first one. Based on this development, our plan forward has changed. Hilcorp believes that the flow path for the cement will most likely go below the packer. Therefore, the amount of cement to be pumped has been increased to the volume of the space below the top packer (4 on the schematic) and above the second packer (7 on the schematic) plus the 150 feet above the top packer. The rational for doing this is that the flow path of the cement cannot be controlled so if the void space below the top packer is filled, then the 150'above the top packer should still be achievable. If the cement bridges off, and all cement ended up above the packer, then we would have approx. 900 feet of cement above the packer. That is acceptable to us. We are still below the hole in the short string and the bottom of the heater string. Plan to drill out is still the same. Drill out the short string first to below the top packer, perform a negative test. If good, then drill out SS CIBP and push outthe bottom of the string if possible. RU to Long string and drill out CIBP and push to bottom. We recognize that we will have to drill out and re -perforate the the A, B,C, and D sand intervals contained in that area. This will be accomplished through the long and short strings. The work plan is as follows: (C"Ap )5r 1.) MIRU Coil Tubing and test BOP - 2.) C/O long string to 3,590'. (Note: may continue to RIH to see how deep we can get for future. POOH W/ Coil. 3.) RU E -line to long string. PU/ RIH W/ CIBP to 3,590' and set. POOH. 4.) RU to short string. PU/RIH with CIBP to 3,015' and set. POOH. 5.) RU Coil Tubing to SS. PU single set retainer and RIH to 2,980' (+/-). Set same. 6.) RU Cementers and pressure test lines. 7.) Pump cement job 1 +/- 53 bbls class g cement). Unsting from retainer. PU 50'. Clean up coil tubing. POOH. WOC. ore {Eeu c Sty ? `"'f r�+z j�� ,2tt+ si4 ? �je- s�c<r'c, 1 8.) RU Coil to SS. Drill out tubing to just below the packer( 3,005'). Perform negative test. Continue to drill out CIBP. RUNitrogen. Blowtubingdry. POOH. <� /3G„ -u,, 9.) RU Coil to LS. PU mill and motor anf RIH drilling out cement and CIBP at 3,590 (+/-). Push to bottom. Drop ball, blow tubing dry with Nitrogen. POOH. RDMO Coil tubing. 10.) RU E -line. PT lubricator to 3,00 psi. PU 2" perf guns, RIH on Long string and re -perforate the A,B,C,and upper D sands. l Timing — We have barged over the extra cement yesterday. If AOGCC is in agreement with this plan, we will start setting the plugs tomorrow and be cementing by this weekend. Please call me with questions or concerns. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp-Alaska LLC Office — 907-777-8420. Cell — 985-867-0665 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader ofthis e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Schwartz, Guy L (CED) From: Ted Kramer <tkramer@hilcorp.com> Sent: Friday, November 8, 2019 9:05 AM To: Schwartz, Guy L (CED) Subject: RE: [EXTERNAL] BRU 241-34 update (PTD 172-016) Guy, The plug in the long string isolated the reservoir. We are holding 68 psi on the long string. 80 psi on the IA and 75 psi on the OA. Pressures are constant. The reservoir is isolated. We put money In the 2020 budget to P&A the well. Ted Kramer Sr. Operations Engineer Hilcorp-Alaska LLC Office — 907-777-8420 Cell — 985-867-0665 From: Schwartz, Guy L (CED) [mailto:guy.schwartz@alaska.gov] Sent: Friday, November 8, 2019 8:41 AM To: Ted Kramer <tkramer@hilcorp.com> Subject: [EXTERNAL] BRU 241-34 update (PTD 172-016) Ted, Can you provide an update on this well? I know you were going to set a plug in the LS.. Did this hold and isolate the reservoir? Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz of (907-793-1226) or (Guv.schwartz@alaska.aovl. 3N z41-34 (l')� 17ZalLa Regg, James B (CED) From: Regg, James B (CED) Sent: Friday, September 6, 2019 12:04 PM e(�L y To: 'Cole Bartlewski - (C)' lsi(! `r G%l Cc: Schwartz, Guy L (CED) Subject: RE: [EXTERNAL] RE: Schlumberger CTU 13 8/30/19 Attachments: Hilcorp MOC for Workovers.pdf I checked our files and there is no record notifying us of a change to the BOPE test pressure. Moving forward, the management of change form should be updated and available for any changes to an approved workover procedure. AOGCC has accepted the lower pressures performed during the 8/30/19 test. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907-793-1236 or jim.regg@alaska.gov. -----Original Message ----- From: Cole Bartlewski - (C) <cbartlewski@hilcorp.com> Sent: Wednesday, September 4, 2019 5:03 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: Re: [EXTERNAL] RE: Schlumberger CTU 13 8/30/19 I thought I remembered seeing an email from Ted Kramer with his explanation to Mr. Schwartz about this issue. I will have to go back and look through emails. Sent from my iPhone > On Sep 4, 2019, at 4:36 PM, Regg, James B (CED) <jim.regg@alaska.gov> wrote: > I understand the physical limits but the approved pressure was 3500 psi and we should have been contacted. There is a MOC form attached to every Hilcorp sundry to deal with changes to approvals. > Jim Regg > Supervisor, Inspections > AOGCC > 333 W.7th Ave, Suite 100 > Anchorage, AK 99501 > 907-793-1236 > CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907-793-1236 or jim.regg@alaska.gov. > -----Original Message----- • From: Cole Bartlewski - (C) <cbartlewski@hilcorp.com> > Sent: Wednesday, September 4, 2019 2:26 PM > To: Regg, James B (CED) <jim.regg@alaska.gov> > Subject: Re: [EXTERNAL] RE: Schlumberger CTU 13 8/30/19 > Jim. We only went to 3000 psi because the tree is a 3k tree. I cannot exceed the working pressure of the tree > Sent from my iPhone > On Sep 4, 2019, at 12:51 PM, Regg, James B (CED) <jim.regg@alaska.gov<mailto:jim.regg@alaska.gov>> wrote: > Sundry 319-330 was approved with the work procedure including a CT BOPE Test to 250/3500 psi (pg 4 of attached). Your report indicates testing to 3000psi. Send test charts for my review. > Jim Regg > Supervisor, Inspections > AOGCC > 333 W.7th Ave, Suite 100 > Anchorage, AK 99501 > 907-793-1236 > CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907-793-1236 or jim. regg@a laska.gov<ma i Ito:jim. regg@a laska.gov>. > From: Cole Bartlewski - (C) <cbartlewski@hilcorp.com<mailto:cbartlewski@hilcorp.com>> > Sent: Tuesday, September 3, 2019 11:03 AM > To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe. bay@alaska.gov<mailto:doa.aogcc.prudhoe. bay@alaska.gov>>; Brooks, Phoebe L (CED) < phoebe. brooks@alaska.gov<maiIto: phoebe. brooks@alaska.gov>>; Regg, James B (CED) <jim.regg@alaska.gov<ma ilto:jim.regg@alaska.gov>> > Cc: Donna Ambruz <dambruz@hilcorp.com<mailto:dambruz@hilcorp.com>>; Ted Kramer <tkramer@hilcorp.com<mailto:tkramer@hilcorp.com>> > Subject: Schlumberger CTU 13 8/30/19 > Attached is the BOPE test for SLB CTU 13 on BRU 241-34 8/30/19 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report *All BOPE reports are due to the agency within 5 days of testing* Submit to: hm.regg0,alaska.gov; AOGCC.InspectorscDalaska.gov: phoebe.brooks(a)alaska.gov Contractor: Schlumberger Rig No.: 13 - DATE: 8/30/19 Rig Rep,: Derrek Hovanec Rig Phone: 907-830-2288 Operator: Hilcorp Op. Phone: 907-690-2854 Rep.: Cole Bartlewski E -Mail cbartlewski@hilcorp.com Well Name: BRU 241-34 PTD # 1720160 Sundry # 319330 - Operation: Drilling: Test: Initial: Test Pressure (psi): Rams: Test Result Location Gen. P Housekeeping P - PTD On Location P ling Order Posted NA BOP STACK: Stripper Annular Preventer #1 Rams #2 Rams #3 Rams #4 Rams #5 Rams #6 Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve BOP Misc Workover: x Weekly: Quantity Size/Type Test Result Explor.: Bi -Weekly: Quantity Upper Kelly 0 Lower Kelly Test Result Well Sign P Rig NA Hazard Sec. NA Misc. NA Quantity Size/Type Test Result Explor.: Bi -Weekly: Quantity Upper Kelly 0 Lower Kelly 0 Ball Type 0 Inside BOP 0 FSV Misc 0 MUD SYSTEM: Visual Trip Tank NA Pit Level Indicators NA Flow Indicator NA Meth Gas Detector NA H2S Gas Detector NA MS Misc 0 Quantity Inside Reel valves I ACCUMULATOR SYSTEM: Time/Pressure MASP: 212 LLVES: Test Result NA NA NA NA NA Alarm NA NA NA NA NA NA Test Result P - Test Result P P P P Test Results Number of Failures: Test Time: 3_0 Hours Repair or replacement of equipment will be made within n/a days. Notify the AOGCC of repairs with written confirmation to: AOGCC.lnspectors@alaska.gov Remarks: Right rear choke isolation valve indicated FP. Greased and retested good. SNA 3l�(_�iL e�1rCS 4— Rtw+s 24 hr Notice Yes Dateffime By Start Date/Time: 8/30/2019 12:30 (time) I Witness Finish Date/Time: Form 10-424 (Revised 04/2018) .Schlumberger -private SchlumbergerCTU13_8_30_2019 1610 System Pressure (psi)_ CHOKE MANIFOLD: Pressure After Closure (psi) _ Quantity Test Result 200 psi Attained (sec) _ No. Valves 5 FP Full Pressure Attained (sec) Manual Chokes 2 P Blind Switch Covers: At Hydraulic Chokes 0 NA Nitgn. Bottles # & psi (Avg.): N/A CH Misc 0 NA ACC Misc MASP: 212 LLVES: Test Result NA NA NA NA NA Alarm NA NA NA NA NA NA Test Result P - Test Result P P P P Test Results Number of Failures: Test Time: 3_0 Hours Repair or replacement of equipment will be made within n/a days. Notify the AOGCC of repairs with written confirmation to: AOGCC.lnspectors@alaska.gov Remarks: Right rear choke isolation valve indicated FP. Greased and retested good. SNA 3l�(_�iL e�1rCS 4— Rtw+s 24 hr Notice Yes Dateffime By Start Date/Time: 8/30/2019 12:30 (time) I Witness Finish Date/Time: Form 10-424 (Revised 04/2018) .Schlumberger -private SchlumbergerCTU13_8_30_2019 1610 Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well BRU 241-34 (PTD 172-016) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first calf' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date l3e4 04(- 34- PrN (-72o1(6V Regg, James B (CED) From: Regg, James B (CED) Sent: Wednesday, September 4, 20194:36 PM #1j�Iq To: Cole Bartlewski - (C) r( Cc: Schwartz, Guy L (CED) Subject: RE: [EXTERNAL] RE: Schlumberger CTU 13 8/30/19 I understand the physical limits but the approved pressure was 3500 psi and we should have been contacted. There is a MOC form attached to every Hilcorp sundry to deal with changes to approvals. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907-793-1236 or jim.regg@alaska.gov. -----Original Message ----- From: Cole Bartlewski - (C) <cbartlewski@hilcorp.com> Sent: Wednesday, September 4, 2019 2:26 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL] RE: Schlumberger CTU 13 8/30/19 Jim. We only went to 3000 psi because the tree is a 3k tree. I cannot exceed the working pressure of the tree Sent from my iPhone On Sep 4, 2019, at 12:51 PM, Regg, James B (CED) <jim.regg@alaska.gov<mailto:jim.regg@alaska.gov>> wrote: Sundry 319-330 was approved with the work procedure including a CT BOPE Test to 250/3500 psi (pg 4 of attached). Your report indicates testing to 3000psi. Send test charts for my review. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 THE STATE °fALASKA GOVERNOR MIKE DONLEAVY Bo York Operations Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beluga River Field, Undefined Gas, BRU 241-34 Permit to Drill Number: 172-016 Sundry Number: 319-330 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 wv .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 40�� Daniel T. Seamount, Jr. Commissioner DATED this day of July, 2019. RBDMSI�' JUL 3 01019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 EC NE JUL 12 2019 DORM 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑� Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program p Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: N2 Jetting ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 172-016 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-283-20038-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 168 Will planned perforations require a spacing exception? Yes LiNo ❑� Beluga River Unit (BRU) 241-34 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA029657 Beluga River/ Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,501' 6,501' 5,445' 5,445'—212psi 5,477' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 16' 30" 44' 44' Surface 381' 20" 405' 405' 1,530psi 520psi Intermediate 2,356' 13-3/8" 2,380' 2,380' 3,450psi 1,950psi Production 90' 10-3/4" 112' 112' 8,060psi 3,670psi Production 6,267' 9-5/8" 6,389' 6,389' 6,330psi 3.810psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 2-3/8" Heater Tubing Grade: 4.6# / N-80 Tubing MD (ft): 1,829' See Attached Schematic See Attached Schematic (2) 2-7/8" 6.5# / N-80 5,429'& 3,543' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Brown HS -17-2C Dual Pkr; N/A 3,001' MD/rVD; N/A, N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Stratigraphic ❑ Development ❑D Service ❑ 14. Estimated Date for r 15. Well Status after proposed work: Commencing Operations: July 26, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑✓ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: £S Date: �9 t Commission Representativ t S GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is rvifand the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(r ffllcoro.corn Contact Phone: 777-8420 / Z ^ 1 Authorized Signature: Date: 7 I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' 0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS-4rz �JUL 3 0 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ /' ` Spacing Exception Required? Yes ❑ No Subsequent Form Required: to — q( T4 q APPROVED BY ^'7 ` ` d Approved It COMMISSIONER THE COMMISSION Date: v / Orz�/ wd L ,jG.ciif4GIG IG AT 10-403 Revised 4/2017pprOvedapPlirator liRoL12 ate of approval. � C� Yv L xc� Submit Form and Attachments in Duplicate U Hilum Alaska. LG Well Prognosis Well: BRU 241-34 Date: 7/11/2019 Well Name: BRU 241-34 API Number: 50-283-20038-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: July 26, 2019 Rig: Coil Tubing Unit Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 172-016 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (C) AFE Number: Maximum Expected BHP: — 600 psi @ 3,887' TVD (Estimated from offset wells) Max. Potential Surface Pressure: 212 psi (0.1 psi/ft gas gradient to 3,887' TVD). Brief Well Summary BRU 241-34 is a dual string flowing gas well that developed an integrity issue between the IA and OA. Diagnostics were ran using Haliburton Caliper Logs and an Acoustic Log. Log Results are reported under the Notes Regarding Wellbore Condition section. The purpose of this work/sundry is to repair the well such that it has a monitor able annulus. Notes Regarding Wellbore Condition Lone String Caliper log of the long string indicated two leaks, both of which are below the top packer (3,376' and 3,470'). Short String Caliper log of the Short string indicated a hole at 845'. Acoustic (ACX) log This log was ran in the long string with the short string SI and the Heater String SI and the IA SI and the OA open to activate the potential leak in the casing. This log indicated a hole in the production casing at 103.8 ft. The log then was ran to the top packer at 2,997'. A potential leak was found in the top packer. The log was then ran to the Next packer at 3,583'. A potential leak was found in this packer. Safety Concerns • Ensure ail crews are aware of their stop job authority. • Make Crew aware of the hazards of working with Nitrogen. E -line Work 1. RU E -line on the short string. Pressure test Lubricator to 200 psi low/ 1,500 psi High. Well Prognosis Well: BRU 241-34 cw�m nlka, r.r. Date: 7/11/2019 2. PU RIH W/Gamma Ray/ CCL to verify the location of sliding sleeve, Pup joint, and top packer. Note: The close proximity of the Sliding sleeve to the packer may prevent telling them apart. A camera may be needed to make the differentiation to verify schematic depths for the sliding sleeve. 3. PU RIH W/ plug to 3,100' (+/-). Make sure plug is not set in a collar. Set Same. POOH. Note: Setting depth may change 4. PU Bailer. Load bailer W/ Sand. RIH and place 10' of sand on top of plug. POOH. 5. MIRU Coil. RU BOP and test same to 250 psi low/ 3,500 psi high. 6. RU Cementers and pressure test lines according to Schlumberger procedure. 7. RIH W/ Coil to just above sliding sleeve @ 2,998'(+/-). Note: Exact depth to be determined with E - line. Pump 20 bbls. 3% KCL spacer fluid. 8. Circulate cement to bottom of coil. Pump a balanced plug of 10 bbls of cement slurry and additives as per Schlumberger cementing formula out the sliding sleeve and on top of the top packer. Plug is designed to be 150' in length. Note: Closely monitor pump pressures to not exceed pressure differential ratings of the plug in the tubing at (+/-) 3,100'. 9. Pull up hole and clean up coil. POOH W/same. SO and WOC. {>ee�t,«�v,Irk"p, JaQr,,�s a �a4d 10. Pickup motor and bit on 1.75" coil tubing. RIH tagging top of cement and dr N outcementre— tainer I and cement down through the sliding sleeve. 11. Proceed in hole down to the sand and wash sand off plug. Circ. bottoms up, POOH W/bit and motor. 12. RU Nitrogen, RIH W/jet nozzle and blow tubing dry. POOH. 13. PU plug retrieving tool. RIH to plug and retrieve same. RDMO Coil Tubing. 14. MIRU E -line on the short string. Pressure test Lubricator to 200 psi low/ 1,500 psi High. 15. PU, RIH W/ Straddle Packer assembly and straddle hole in the Short string @ 845'. RDMO E -line. ® s 1 VL io-�1O3 1;04- xe-t-ePa,re� Attachments: 1. Actual and Proposed Well Schematics 2. Coil BOPE Schematic 3. CT Flow Diagram 4. Wellhead Diagram 5. Standard Nitrogen Operations Procedure 6. Blank RWO Change Form aGGG Hilrnra Alaska. LLC RKB to MSL=109.7' RKB to GL=21.5' 20" a 1 11 1 JT 1 JA 2 HA 13-3/8" TOC @ 2,792' 5 6 7 8 9 10 11 20 21 P1 P9_5/2 TD=6,501' TVD 6,501' PBTD=6,501' ED = 6,455' END = 6,455' Max Angle = 1.5 deg @ 958' Beluga River Unit Well: BRU 241-34 Last Com SCHEMATIC PTD: 72-016 eted: 9/21/1986 API: 50-283-20038-00 CASING DETAIL Size Type WT Grade Conn ID Btm 20" Surface 94# H-40 Butt 19.124" 405' 13-3/8" Intermediate 68# K-55 Butt 12.415" 2,380- 10-3/4" Production Casing 51# P-110 8rd 9.85" 71-37- 9-5/8" Production Casing 43.5# N -80/P-110 8rd 8.755" 5,238' 9-5/8" Production Casing 43.5# P-110 Butt 8.755" 6,500- 2-3/8" Heater String 4.6# N-80 Butt 1.995" 1,829' it Min I.D. I Heater string: 1.751" Short string: 2.205" Long string: 2.205" A B C D D E E F F F 6 G H H TUBING DETAIL'. 6.5# N-80 6.5# N-80 JEWELRY DETAIL Long String ID. Depth MD (ft.) ID (in.) Description 1 22 2.41 FMCTubing hanger 2 777 2.313 Otis'X' Nipple 3 2,965 2.437 Brown 'CC" Safety joint 4 2,997 2.375 Brown Dual Packer, HS -17-2C, 50k# 5 1 3,548 1 2.441 Brown Straight Pull Safety joint 32k# 6 3,580 2.313 Otis 'XD'Sliding Sleeve, Closed 9/10/94 7 3,583 4 Brown HB -1 Packer w/ XO's, 50k# 8 3,975 2.441 Brown Straight Pull Safety joint 32k# 9 4,007 2.313 Otis'XD' Sliding Sleeve, Closed 9/20/94 10 4,010 4 Brown HB -1 Packer w/ XO's, 50k# 11 4,051 2.313 Otis'X' Nipple 12 4,648 2.437 Brown 'CC" Safety joint 13 4,682 2.313 Otis'XD' Sliding Sleeve Open 9/20/94 14 4,685 4 Brown HB -1 Packer w/ XO's, 50k# 35 4,726 2.313 Otis'X' Nipple 16 5,070 2.437 Brown 'CC" Safety joint 17 5,102 2.313 Otis'XD'Sliding Sleeve Open 9/20/94 38 5,105 4 Brown HB -1 Packer w/ XO's, 50k# 19 5,145 2.313 1 Otix'X' Nipple 20 5,396 2.205 Otis'XN' Nipple 21 5,428 2.441 Brown Shear Sub Short Strina ID. Depth MD (ft.) ID (in.) Description 1A 685 2.313 Otis'X' Nipple 1B 2,998 7 2.313 Otis 'XD'Sliding Sleeve, Open 7/29/98 1C 3,037 2.313 Otis'X' Nipple 1D 3,541 2.205" Otis'XN' Nipple H Heater St ID. I Depth MD (ft.) F ID Halliburton Pg.1 Created By: JJ 6/28/2016 H corp Alaska. LLC SCHEMATIC PERFORATION DETAIL Beluga River Unit Well: BRU 241-34 Last Completed: 9/21/1986 PTD: 172-016 API: 50-283-20038-00 Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Phase Date Status WSO 3,056 3,057' 3,056' 3,057' 1' 4 0 7/26/1972 Sqz A 3,066' 3,167' 3,066' 3,167' 64'* 12 0 9/15/1986 R'perf B 3,244' 3,340' 3,244' 3,340' 511* 12 0 9/15/1986 R'perf C 3,362' 3,503' 3,362' 3,503' 67'* 12 0 9/15/1986 R'perf D 3,518' 3,545' 3,518' 3,545' 121* 12 0 9/15/1986 R'perf D 3,614' 3,738' 3,614' 3,738' 61'* 4 0 7/30/1972 Open E 3,797' 3,968' 3,797' 3,968' 42'* 4 0 7/29/1972 Open E 4,072' 4,138' 4,072' 4,138' 66' 4 0 7/29/1972 1 Open F 4,499' 4,503' 4,499' 4,503 4' 4 0 7/29/1972 Open G 4,732' 5,048' 4,732' 5,048' 74'*8 0 9/14/1986 Open H 5,137' 5,375' 5,137' 5,375' 110'* 9 0 9/14/1986 R'perf H 5,490' 5,742' 5,490' 5,742' 35'* 4 0 7/23/1972 Plugged, DST #2 *Partially Perforated Interval 11 Pg. 2 Created By: 116/28/2016 uPROPOSED SCHEMATIC Hila p Alaska. LLC RKB to MSL =109.7' RKB to 6L=21.5' Beluga River Unit Well: BRU 241-34 Last Completed: 9/21/1986 PTD: 172-016 API: 50-283-20038-00 pg• 1 Updated By: DMA 07-12-19 KSCHEMATIC cora Alaska, LLC PERFORATION DETAII Beluga River Unit Well: BRU 241-34 Last Completed: 9/21/1986 PTD: 172-016 API: 50-283-20038-00 Sands Top (MD) Btm (M D) Top (TVD) Btm (TVD) Amt SPF Phase Date Status WSO 3,056' 3,057' 3,056' 3,057' 1' 4 0 7/26/1972 Sqz A 3,066' 3,167' 3,066' 3,167' 64'* 12 0 9/15/1986 R'perf B 3,244' 3,340' 3,244' 3,340' 51'* 12 0 9/15/1986 R'perf C 3,362' 3,503' 3,362' 3,503' 67'* 12 0 9/15/1986 R'perf D 3,518' 3,545' 3,518' 3,545' 12'* 12 0 9/15/1986 R'perf D 3,614' 3,738' 3,614' 3,738' 61'* 4 0 7/30/1972 Open E 3,797' 3,968' 1 3,797' 3,968' 42'* 4 0 7/29/1972 Open E 4,072' 4,138' 4,072' 4,138' 66' 4 0 7/29/1972 Open F 4,499' 4,503' 4,499' 4,503' 4' 4 0 7/29/1972 OPen G 4,732' 5,048' 4,732' 5,048' 74'* 8 0 9/14/1986 Open H 1 5,137' 5,375' 5,137' 51.375' 1101* 9 0 9/14/1986 R'perf H 5,490' 5,742' 5,490' 5,742' 35'* 4 0 7/23/1972 Plu ed, DST #2 *Partially Perforated Interval PS•2 Created By:A 6/28/2016 Kill R WH P: 2" 1502 x2 11 Flanged M (Manual 2-1/16 1OK 10K Flange (Manu Coil Tubing BOP Coiled Tubing FIR580 Injector Head & Gooseneck Weight = 12,850 lbs 4.1116" 10K Conven0onal Stripper 5K CO62 Lubricator SK CO62 x 4-1116" 10K Flange 4.1/16" 10K Combi BOP Trp Set: Blind/Shear Second Set. PiperSlip 4-1/16" 10K Flow Cross Manual 2x2 Valve 1: 2" 1502 x 21/16" 10K Range Manual 2x2 Valve2: 2-1116" 10K x 2-1/16" 1OK Flange Manual 2x2 Valve 3:2-1116" 10K x2-1/16" 1OK Range Manual 2x2 Valve 4: 2" 1502 x2-1116" 10K Flange 4-1/16" 10K x Wellhead Adapter Flange Wellhead Open—Top Tank w/ Diffuser s up Annulus COILED TUBING UNIT N2 JETTING FLOW SCHEMATIC Beluga River Unit BRU 241-34 133/8x 103/4x 27/8x 27/8x23/8 String #3 Valve, Swabs, OCT -20, 2 9/16 3M triple segmen' FE, HWO, T-21 11 Valve, Masters, OCT -20, 2 9/16 3M triple segmented FE, HWO, T-21 Valve, Masters, OCT -20, 2 9/16 3M triple segmented FE, HWO, T-21 Beluga River 241-34 Current 06/26/2019 Tree cap, 2 9/16 3M Triple segmented x 2 7/8 EUE 8rd lift Valve, Swabs, OCT -20, 2 9/16 3M triple segment FE, HWO, T-21 Valve, Masters, OCT -20, 2 9/16 3M triple segmented FE, HWO, T-21 Valve, Masters, OCT -20, 2 9/16 3M triple segmented FE, HWO, T-21 Tubing head, FMC -TC -00, 13 5/8 3M x 113M, w/ 2- 2 1/16 5M EFO, BG bottom prep Casing head, CIW-W F, 13 5/8 3M x 13 3/8 SOW, w/ 2- 21/16 5M EFO 2 3/8" Tubing hanger, Triple, FMC - TC -3C, 11 x 2 7/8 EUE 8rd lift and susp, W/ 21/2' type H BPV profiles, AA trim Void test good 250/3000psi 06/26/2019 Void test good to 2000psi—it is packed off with plastic injection sealant in order to maintain slip seal 06/26/2019 STANDARD WELL PROCEDURE HacorpAlaska, LIA. NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vl Page 1 of 1 ff Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well BRU 241-34 (PTD 172-016) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials —HA K Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date W-1 . VUIOLIWIJ� �I UJJJVVJ Date Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, January 22, 2019 8:41 AM To: 'Taylor Nasse'; 'Trudi Hallett' Cc: Regg, James B (DOA) Oim.regg@alaska.gov) Subject: RE: [EXTERNAL] RE: BRU 241-34 (PTD 172-016) Taylor, Only one thing forgot to mention... At some point the wells total rate will fall below what is needed for keeping the heater string as a production line (i.e. and a variance for annular flow) . I am not sure what that rate is but I would like Hilcorp to justify the current rate and come up with a cutoff total rate. I realize this rate is tied to the short string only before it is split at surface. The sundry approval did not specify an end date but you should be able to calculate a well rate that will not require the extra string. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwortz@alaska aov(. From: Schwartz, Guy L (DOA) Sent: Tuesday, January 22, 2019 8:32 AM To: Taylor Nasse <tnasse@hilcorp.com>; Trudi Hallett <thallett@hilcorp.com> Subject: RE: [EXTERNAL] RE: BRU 241-34 (PTD 172-016) Taylor, Thanks for the pictures. placement of the valves. No more info needed... Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office They do help. I was making sure each string had a functioning SSV and trying to understand CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended From: Trudi Hallett <thallett@hilcorp.com> Sent: Thursday, January 17, 2019 9:12 AM To: Schwartz, Guy L (DOA) <Ruy.schwartz@alaska.aov> Cc: Taylor Nasse <tnasse@hilcorp.com> Subject: BRU 241-34 (PTD 172-016) Good Morning, Guy— Please find the attached documents referencing the Beluga River well BRU-241-34 (PTD 172-016) in order to address your questions regarding the 2011 approval to allow annular flow via the sliding sleeve in the short string (string #2). The current wellbore schematic has the flow paths illustrated in red arrows. For reference, I attached the documentation from the approval in 2011 and the well's P&ID illustrating where the Surface Safety Valves are located for all the streams. This well is currently online flowing over 5 MMCFD, the short string making just over 3 MMCFD and the long string (string #1) contributing 2 MMCFD both @ 230 psi flowing tbg pressure. If you have any questions, please do not hesitate to contact me or Taylor. Have a great day! TrL&Aii Trudi Hallett Rc.wrroir Engineer Kenai Asset Tcam I lilcorp Alaska, LLC HIIcOTp A Company Built on Energy thatlett@hilcorp.com 0: 907.777.8323 C: 907.301.6657 XeanseNe-ml 0W Bop —� S-241-34-1 qui, 5-2q1— A6 w. G16'W 0.6 w. 1116'6' GO MAW 1300 P510 0 120T MPNP 1102 PSIG Ot10F Iwctlla+UMl69 Y-ts01 IAI1 NM1 --�i '-®- LTJ L�cJ -lam'"j/I AIPA A XX z s(Q1w� A .❑ 0 7Z-616 R% EE MLL BIDCR `AXPR WN MU F PAD 241— A NOTES Is OGCIINENT HAS BEEN 'As ..'r AND, N,,,XAI PER CCR NOR CERW], SN 1 N xtv TYP z Ixs1MMExr TAO NUIeEIis ,4W oEP! QAITIED WE i0 IACK N IxsiRUMENT TARS IH ME F W AISTARMEi TAVXREAS ONMCRIMAI. 0TAxO/OPNUNGGARENTIONAL JUJ.S I&A., (MP-RAID-N95BX REV J. NNCIOENIIFICATIM LETTERS ON SONE MENTS HAW BEEN $415E0 PER 1 ANSI/ISA-SST. A REWGA INSTRUMENTS STAN T REFERENCE PAHLNIDER:S) x XW II r I NEXT TO EWFB[FN AOOW xE%i CI f25PECE-T MB FIN ORDER N FINSTIVAIE RE -TAGGING E NI �.I S ALLIXSHERE L GPS VENIS ARE flOVIEO 10 ,p gp I AdO�XFJS. B CEPIGIS A SNIIM. o]NGINOIN. 1 A L ). ALL 1NEIMOM[IERs MIME IxERNGM[1LA MELS R. RAMO PAGING SYSTEM Is XtS WITIATEO. 0. HEFT TNPCC AIp INSUTAIE Y PWYIIXFM AHEI GNE FGGL UPs1RENN ANO OONNs1RE W PIT PNO flWi VPLK. ji Mrt �� p 10. FIELD INSVI.A E NL EXTERIOR AWK MADE PIPING. ENE El LIM-NIG PRESSURE RATINGF FW TRE YEL. PRF 11. W£ 1TDW IS FUT T IM PSI. FLO'MINE IS M. FqT AT IM P51. a YaY f Y6' ryYAMXY qn4 iN A y roWM6FWn A0 NY I LWM IY091GMlyN M Ie I MRO is N. r0 IBIM p TItlP iRCOE r Y 91FL1ER rt - IWIINMI R p NIN I0"1" INSIDE VALYf SIELIER 9 JPMYMY Y AAK 1.`'QaMY E Y Q Y f f fY' 1 OUR RERVA--� - IIpTREDSNMY MxY YwXAm `� SN61ER RADII SELLODING R% EE MLL BIDCR `AXPR WN MU F PAD 241— • • 2 Ifor[E 0[F ALAmn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Jerry Dethlefs Well Integrity Engineer ,. 0 )6 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Beluga River Field, Undefined Gas Pool, BRU 241 -34 Sundry Number: 311 -250 Dear Mr. Dethlefs: rA,,, MED AlrG 2 6 ZO11 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 holi. ; or weekend. Sin °r -I i JO ' . Norm.. n X'day Com ' _ : ioner DATED this of August, 2011. Encl. • • P.O. Dethlefs P.O. Box 100360 Anchorage, AK 99510 -0360 Conoco Phillips Phone 907 - 264 -1464 Fax 918- 662 -8638 Alaska, Inc. August 10, 2011 Winton Aubert Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 ' , ` Anchorage, AK 99501 tv, r 's� . . eers.mission Subject: Beluga BRU 241 -34 Flow Exception Dear Mr. Aubert: As per Sundry 398 -192 for Beluga well BRU 241 -34, dated July 22, 1998, ConocoPhillips requests to modify the terms of the Sundry. The previous approval is for annular production of gas from the well during "peak winter production demands ". ConocoPhillips requests the terms be changed to allow annular production during "normal operations ". - Please consider this request to change annular production of gas from limited peak production events to normal operations. Should you require more information do not hesitate to contact me at 907 - 265 -1464. Regards, Jerry Dethlefs CPAI Well Integrity Director Cc: Art Copoulos Ty Senden WGk ' STATE OF ALASKA ' = ( ( 0 / og 124 20 t 1 ALASKA* AND GAS CONSERVATION COMMISSIC APPLICATION FOR SUNDRY APPROVALS 1-r i1! 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool J"` Repair well r Change Approved Program 17 , Suspend r Rug Perforations r Perforate F Rill Tubing f" Time Extension F Operational Shutdown - Re -enter Susp. Well J" Stimulate J" Alter casing F Other: F 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development i✓ . Exploratory F 172 -016 , 3. Address: Stratgraphic J° Service J" 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 283 - 20038 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes F- No g; BRU 241 -34 . 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA029657 ■ Beluga River Field / 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): 6501 - 6501 . 5445' 5445' 5477' Casing Length Size MD TVD Burst Collapse Conductor 16' 30" 44' 44' Surface 381' 20" 405' 405' Intermediate 2356' 13.375" 2380' 2380' Production 90' 10.75" 112' 112' 6267' 9.625" ,-6-3-8-9' 1 /' 6389' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3066-5375' 3066-5375' 2.. 2.875" N - 5429 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) 5 packers © 2997' MD, 3583' MD, 4010' MD, 4685' MD, 5105' MD Otis X nipple © 777' MD 12. Attachments: Description Summary of Proposal f;► 13. Well Class after proposed work: Detailed Operations Program F- BOP Sketch r Exploratory J" Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/10/2011 Oil F Gas f✓ WDSPL r Suspended F 16. Verbal Approval: Date: WINJ IJ" GINJ r WAG F Abandoned (— Commission Representative: GSTOR 1 F" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jerry Dethlefs © 265 -1464 Printed Name Jerry Dethlefs Title: Well Integrity Director Signature Del. z -�� ( Phone: 265 -1464 Date � �G'/ Commission Use Only I Sundry Number 'd Conditions of approval: Notify Commission so that a representative may witness ,. 7 .b ^., 0 , . : 't Plug Integrity F BOP Test r Mechanical Integrity Test F- Location Clearance F I:, Other: ,.. .; ;+ . ':,0; ,;f,tr,.. Subsequent Form Required: dQAR t4t "0' 4/ it APPROVED BY 8 0, /' f f Approved by: of OM ISSIONER THE COMMISSION Date: Form 10 -403 Revised 1/2010 ,1 � : i'ln Dupli o Ni A I JiBDM S AU 2 6 4 :' 1 • • ConocoPhillips Alaska, Inc. Beluga Well BRU 241 -34 (PTD 172016) SUNDRY NOTICE 10 -403 VARIANCE REQUEST August 10, 2011 Subject: Beluga BRU 241 -34 Flow Exception As per Sundry 398 -192 for Beluga well BRU 241 -34, dated July 22, 1998 (attached), ConocoPhillips requests to modify the terms of the Sundry. The previous approval is for annular production of gas from the well during "peak winter production demands ". ConocoPhillips requests the terms be changed to allow annular production during "normal operations ". — The concept of "peak demand" has evolved in the BRU; "peak production" is now "normal operations ". The Beluga field has produced gas at near maximum rates on a fairly continuous basis in the recent past, whereas historically the field was more subject to large scale swings in deliverability. The basis of this request is that the mechanical condition of the well is sound. A number of Mechanical Integrity Tests (MIT) have been performed to demonstrate competent well barriers are in place (attached). B th production tubing strings and the production casing successfully passed MITs to 1000 psi. The intermediate casing was also tested to 1000 psi and appeared to leak off slowly at the shoe; however, it should provide a barrier, if needed, based on the maximum pressure expected from the well (less than 800 psi). As stated in previous documentation to the AOGCC (Donajkowski letter to Johnston dated June 14, 1998) annular production exits the well via the old heater string, and surface safety devices are present and are not bypassed. After the MIT was performed the sliding sleeve in the short string was opened to allow annular production from the well. Please consider this request to change annular production of gas from limited peak production events to normal operations. If you require more information please contact Jerry Dethlefs at 907 - 265 -1464. II CPAI Well Integrity Director • • STATE OF ALASKA - CO ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ❑ Suspend 0 Operation Shutdown ❑ Re -enter suspended well ❑ Alter casing ❑ Repair 0 Plugging ❑ Time extension ❑ Stimulate ❑ Change approved program ❑ Pull tubing ❑ Variance ® Perforate ❑ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development IS] G.L. =88', K.B. =110' Exploratory ❑ 3. Address Stratigraphic ❑ 7. Unit or Property name PO Box 100360, Anchorage, AK 99510 - 0360 Service 0 Beluga River Unit 4. Location of well at surface 8. Well number 897' FNL, 1397' FEL, T13N, R1OW, Section 34 241 - 34 String 2 At top of productive interval 9. Permit number Same as above 72 - 0016 At effective depth 10. API number Same as above 50 283 - 20038 - 00 At total depth 11. Field/Pool Same as above Beluga River 12. Present well condition summary Total Depth: measured 6501 feet Plugs (measured) 5477' true vertical 6501 feet Effective depth: measured 5445 feet Junk (measured) true vertical 5445 feet Casing Length Size Cemented Measured depth True vertical depth Structural 16' 30" 44' 44' Conductor 381' 20" 800 SKS 405' 405' Surface 2356' 13 -3/8" 1705 SKS 2380' 2380' Intermediate Production 90' 10 -3/4" 112' 112' 6267' 9 - 5/8" 1060 SKS ` ti/ 6389' 6389' Perforation depth: measured RECEIVE D See Attached Well Schematic true vertical l'Jl Straight hole - same as measured depth \ JUL 16 1998 Tubing (size, grade, and measured depth See attached well schematic 0 Alaska Oil & Gas Cons. Commtsslon Packers and SSSV (type and measured depth) Anchorage See attached well schematic 13. Attachments Description summary of proposal ® Detailed operation program 0 BOP sketch ❑ 14. Estimated date for commencing operation 15. Status of well classification as: July 1998 16. If proposal was verbally approved Oil ❑ Gas 0 Suspended ❑ Name of approver Date approved Service 17. 1 hereby c: f ify that the f i regoing ' ; true and . rrect to the best of my knowledge. Signed J ., - Title Beluga Staff Manager Date , FOR COMMISSION USE ONLY ❑ Conditions of app oval: Notify • . ission so representati ve may witness + Approval No Plug integrity ❑ BOP Test ❑ Location clearance I Mechanical Integrity Test "g Subsequent form require 10- lidy- o`►s Oo , Approved by the order of the Commission Original Signed R C ommissio n eP p p e ' e 1 Form 10-403 Rev 5/03/89 Uavid W. Johnsto .1./ SUBMIT IN TRIPLICATE ARCO Alaska, Inc. ' Post Office Box ..s.3360 Anchorage Alaska 99510 -0360 Telephone 907 276 1215 " June 14, 1998 Mr. D. W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: BRU 241 -34 Flow Exception Dear Mr. Johnston: ARCO proposes opening a sliding sleeve above the upper packer in BRU 241 -34 and simultaneously producing the well up the tubing and production casing annulus. Article 3 of the Alaska Administrative Code 25.200 stipulates that unless otherwise specifically approved by the commission, "all wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer which effectively isolates the tubing- casing annulus from fluids being produced ". ARCO believes that production above the packer in BRU 241 -34 presents no safety or environmental risk and requests an exception to this requirement. Two wells in the Beluga River Field (BRU 214 -26 and BRU 224 -23) were granted flow exceptions in February of last year. To date, BRU 214 -26 has undergone the necessary modifications and been flow tested with annular production. A rate gain of 4 MMscf /d was achieved and annular flow has been utilized sparingly to meet peak winter production demands. During normal operations, the well continues to be produced only up the production tubing. Production modifications to BRU 224 -23 have been deferred as the potential rate benefits are not as significant. Results similar to those achieved with BRU 214 -26 are expected from BRU 241 -34. As summarized below, the risks associated with annular production in the Beluga River Field are considered minimal: • The heat string is no longer being utilized. While necessary in the past to prevent the formation of hydrates, reservoir pressures have declined to the extent that downhole hydrate formation is not a problem in any Beluga River wells. Nolt / t,c41 U up -642 A49-443C S RECEIVED JUL 7 6 1998 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B- 6003 -C • Page 2 • No existing safety devices will be defeated or bypassed. All wells are equipped with surface safety valves for well control and all production will continue to be routed through surface safety equipment. • Beluga River wells produce a benign fluid consisting of approximately 99.1% methane, 0.6% nitrogen, and 0.3% CO2. No condensates and very little water is produced in conjunction with the gas. As such, there are no known instances of tubing leaks or downhole corrosion in the Beluga River Field. • Well 241 -34 is believed to have competent tubing and casing. As a precaution, an MIT of the 9 -5/8" casing will be conducted prior to performing the necessary wellwork. Should the well fail an MIT, the wellwork will be postponed pending further evaluation. In addition, the 9 -5/8" x 13 -3/8" annulus will be monitored should the integrity of the 9 -5/8" casing be compromised in the future. Tubing and annular pressures are monitored and reported daily. • The interval to be produced through the annulus is not a known sand producer and the risk of eroding the production casing or the long string of tubing is considered minimal. As a precaution, all wells are tested annually with an acoustic monitoring device to ensure they are produced at a sand free rate. Please refer to the attached well schematic and sundry form for additional information. If you have any questions regarding this request, please contact Brian Seitz at (907) 265 -6961. Sinc r , Ken L. Donajkow i Beluga sset ma ! er attachments RECE IVE D JUL 16 1998 Oil & A s m � ARCO Alaska, Inc. Is a Subsidiary of AtlanticRlcbfieldCompany • • ConocoPhillips Alaska, Inc. Mechanical Integrity Test OPERATOR: ConocoPhillips Alaska, Inc. FIELD / UNIT / PAD: BRU 241 - 34 DATE: See below OPERATOR REP: Cameron Merritt Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 241 -34 Type Inj. N TVD Tubing 0 1010 1070 1150 Interval o P.T.D. 1720160 Type test P Test psi 1000 Casing 450 450 450 450 P/F P Notes: 7/21/11 MIT -Short String with tubing plug @ 3037' OA 280 290 290 290 Well 241 -34 Type Inj. N TVD 2,997' Tubing 0 0 0 0 Interval o P.T.D. 1720160 Type test P _ Test psi 1000 Casing 450 1,000 999 1,005 P/F P Notes: 7/22/11 CMIT TxIA to top packer @ 2997' with plugs OA 350 290 290 290 in SS and LS tubing Well 241 -34 Type Inj. N TVD Tubing 0 0 0 0 Interval o P.T.D. 1720160 Type test P Test psi 1000 Casing 260 260 260 260 P/F F Notes: 7/23/11 MIT -OA 10 -3/4" x 13 -3/8" annulus OA 350 1,000 955 910 Test failed on leakoff, likely through shoe Well 241 -34 Type Inj. N TVD 2,997' Tubing 600 950 1,100 1,210 Interval p P.T.D. 1720160 Type test P Test psi 1000 Casing 0 0 0 0 P/F P Notes: 7/24/11 MIT -Long String with tubing plug @ 3600' OA 450 450 _ 450 450 @ 3600' and (thermal increase in pressure Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) BRU 241 -34 MIT Form.xls • • } { BRU 241 -34 API# 50- 283 - 20038 -00 lr } { 2w ConocoPhillips } { Gas Producer Annulus Fluid: Produced Gas (Annular Flow) HA Dual Comp, t Annular Flow Max Hole Angle: 1.5° @ 958' Spud Date 6/17/72 lc Sect. 34, T13N, R1OW, NE 1/4 RKB to Ground: 21.5' Last Completion 9/21/86 NMI 11 2x ASP @ Beluga: 2,624,279; 316,519 RKB to SL: 109.7' Schematic Rev. 6/28/04 ld i E s z CASING & TUBING Hole by TDT } { 2y A Description OD Btm. Weight Grade Thread Size Cement A Surface Csg. 20" 405' 94. # H -40 Buttress 26" 800sx "G ". Intermediate 13 3/8" 2,380' 68. # K -55 Buttress 17 1/2" 1620sx "G ". Bump plug. Prod. Casing 10 3/4 113' 51. # P -110 8rd 12 1/4" 585sx @shoe, 475sx @ 3512' B Prod. Casing 9 5/8 5, 43.5 # N- 80 /P -i10 8rd 12 1/4" collar. Bump plug 2500psi B Prod. Casing 9 5/8 ,500' 43.5 # P -110 Buttress 350sx "G" in 10x13 Annulus C Prod, Tbg (Htr) 2 3/8" ' -- 9' 4.6 # N -80 Buttres, C Prod. Tbg. 2 2 7/8" 3,543' 6.5 # N -80 EUE -8rd Prod. Tbq. 1 2 7/8" 5,429' 6.5 # N -80 EUE -8rd collar } { 2z 1 Str. Lbl. Top JEWELRY& FISH Length ID OD le,f H A 1,828' "XN" Nipple, Ou5 0.85' 1.751" 2.719" 1g i 2 w 685' "X" Nipple, Otis 1.20' 2.313" 3.25" D 2 x 2,998' SS -XD Sliding Sleeve, Otis "XD" en 7/29/98 3.20' 2.313" 3.719" D 2 y 3,037' "X" Nipple, Otis '-- 1.20' 2.313" 3.25" 2 z 3,541' "XN" Nipple, Otis 1.20' 2.205" 3.25" All a 22' FMC Tubing Hanger 2.60' 2.41" 4.18" _ 1 b 777' "X" Nipple, Otis 1.20' 2.313" 3.25" �_ 1 c 2,965' Safety Jt, Brown "CC" 1.40' 2.437" 3.625" 1 d 2,997' Pkr Packer, Brown Dual, HS- 17 -2C, 50k# 7.15' 2.375" wow 1h,I 1 1 1 e 3,548' Safety it, Brown Straight pull 32k# 0.90' 2.441" 3.50" lj :I 1 f 3,580' SS -XD Sliding Sleeve, Otis "XD" Closed 9/10/94 3.20' 2.313" 3.719" 1k } { 1 g 3,583' Pkr Packer, Brown HB -1 w/ XO's, 50k# 9.22' 4.00" 1 h 3,975' Safety Jt, Brown Straight pull 321# 0.90' 2.441" 3.50" F� 1 I 4,007' SS -XD Sliding Sleeve, Otis "XD" , 0'pe, 9/20/94 3.20' 2.313" 3.719" F 1 j 4,010' Pkr Packer, Brown HB -1 w/ XO's, # 9.70' 4.00" 1 k 4,051' "X" Nipple, Otis 1.20' 2.313" 3.25" 1 L 4,648' Safety it, Brown "CC" 1.40' 2.437" 3.625" 1 m 4,682' SS -XD Sliding Sleeve, Otis "XD" 'Open 9/20/94 3.20' 2.313" 3.719" 1 n 4,685' Pkr Packer, Brown HB -1 w/ XO's, 50k# 9.73' 4.00" 1 0 4,726' "X" Nipple, Otis 1.20' 2.313" 3.25" 1 p 5,070' Safety Jt, Brown "CC" 1.40' 2.437" 3.625" 1 q 5,102' SS -XD Sliding Sleeve, Otis "XD" Open 9/20/94 3.20' 2.313" 3.719" 1L,m 11 1 1 r 5,105' Pkr Packer, Brown HB -1 w/ XO's, 50k# 9.00' 4.00" in A Y7 1 s 5,145' "X" Nipple, Otis 1.20' 2.313" 3.25" 10 } { 1 t 5,396' "XN" Nipple, Otis 1.26' 2.205" 3.25" 1 u 5,428' Shear Sub, Brown 2.441" 3.75" = Pressure Datum: Sterling 3450' SS: 3,560'MD Beluga 4000' SS: 4,110'MD PERFORATIONS, FILL & PLUGS Net Zone To Btm. Status Date SPF Ft. WSO 3,056' 3,057' Sqz'd 365 sx cmt 07/72 4 1p,q 1 _ 1 A 3,066' 3,1b/' Ong 4 SPI-, Repertd 8 SPI 09/86 12 b4' it B 3,244' 3,340' Orig 4 SPF, Reperfd 8 SPF 09/86 12 51' -1--1 C 3,362' 3,503' Orig 4 SPF, Reperfd 8 SPF 09/86 12 67' is } { D 3,518' 3,545' Orig 4 SPF, Reperfd 8 SPF 09/86 12 12' D 3,614' 3,738' Open, String 1 - Top interval 07/72 4 61' E 3,797' 3,968' Open, String 1 - Top interval 07/72 4 42' H E 4,072' 4,138' Open, String 1 - Upper mid interval 07/72 4 66' tt,u } F 4,499' 4,503' Open, String 1 - Upper mid interval 07/72 4 4' G 4,732' 5,048' Orig 4 SPF 09/86 8 74' 5477' H 5,137' 5,375' Orig 4 SPF, Reperfd 4 SPF 09/86 9 110' H PLUG 5,477' Halliburton cast iron BP 07/72 H 5,490' 5,742' Plugged. DST #2 07/72 4 35' ]>- PBTD 6,455' Float Collar at 6455' 07/72 oG TAGS Str 2 7/30/98 3541'RKB 2.31" PXN Plug Str 1 2/14/03 5425'RKB 2" D.D. Bailer O 5/3/91 3541'RKB 2.3" Gauge ring 9/20/94 5445'RKB CTU FCO i - of FBTD 6455 t ., r r ;'' = Jul -98 Annular flow for Str 2 started after sliding sleeve at 2998 & MIT on 10-3/4" showed on 55 psi drop in 1 hour. • erry Dethlefs P.O. Box 100360 Anchorage, 99510 -0360 ConocoPh i I I i ps Phone 907 - 266 4 -1464 Fax 918- 662 -8638 Alaska, Inc. August 2, 2011 Winton Aubert p re:7 „,, , Alaska Oil & Gas Commission '' :.. 333 West 7 Avenue, Suite 100 Anchorage, AID 99501 Subject: Beluga BRU 241 -34 Flow Exception Dear Mr. Aubert: As per Sundry 398 -192 for Beluga well BRU 241 -34, dated July 22, 1998 (attached), ConocoPhillips requests to modify the terms of the Sundry. The previous approval is for annular production of gas from the well during "peak winter production demands ". ConocoPhillips requests the terms be changed to allow annular production during "normal operations ". The concept of "peak demand" has evolved in the BRU; "peak production" is now "normal operations ". The Beluga field has produced gas at near maximum rates on a fairly continuous basis in the recent past, whereas historically the field was more subject to large scale swings in deliverability. The basis of this request is that the mechanical condition of the well is sound. A number of Mechanical Integrity Tests (MIT) were performed to demonstrate competent well barriers are in place (attached). Both production tubing strings and the production casing successfully passed MITs. The intermediate casing was also tested and appeared to leak off slowly at the shoe; however, it should provide a barrier, if needed, based on the maximum pressure expected from the well. As stated in the previous documentation to the AOGCC (Donajkowski letter to Johnston dated June 14, 1998) annular production exits the well via the old heater string, and surface safety devices are present and are not bypassed. After the MIT was performed the sliding sleeve in the short string was opened to allow annular production from the well. Please consider this request to change annular production of gas from limited peak production events to normal operations. Let me know if you require more information or a different format for obtaining approval. I am looking forward to your reply; please do not hesitate to contact me at 907- 265 -1464. Regards, Jerry Dethlefs CPAI Well Integrity Director Cc: Art Copoulos Ty Senden ^ • ARCO Alaska, Inc. • A Post Office Box .00360 Anchorage Alaska 99510 -0360 r Telephone 907 276 1215 June 14, 1998 Mr. D. W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: BRU 241 -34 Flow Exception Dear Mr. Johnston: ARCO proposes opening a sliding sleeve above the upper packer in BRU 241 -34 and simultaneously producing the well up the tubing and production casing annulus. Article 3 of the Alaska Administrative Code 25.200 stipulates that unless otherwise specifically approved by the commission, "all wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer which effectively isolates the tubing- casing annulus from fluids being produced ". ARCO believes that production above the packer in BRU 241 -34 presents no safety or environmental risk and requests an exception to this requirement. Two wells in the Beluga River Field (BRU 214 -26 and BRU 224 -23) were granted flow exceptions in February of last year. To date, BRU 214 -26 has undergone the necessary modifications and been flow tested with annular production. A rate gain of 4 MMscf /d was achieved and annular flow has been utilized sparingly to meet peak winter production demands. During normal operations, the well continues to be produced only up the production tubing. Production modifications to BRU 224 -23 have been deferred as the potential rate benefits are not as significant. Results similar to those achieved with BRU 214 -26 are expected from BRU 241 -34. As summarized below, the risks associated with annular production in the Beluga River Field are considered minimal: • The heat string is no longer being utilized. While necessary in the past to prevent the formation of hydrates, reservoir pressures have declined to the extent that downhole hydrate formation is not a problem in any Beluga River wells. Nom-: Wow w &-e 1I4°- s - RECEIVED JUL 7 6 1998 Alaska 0i1 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B- 6003 -C Page 2 • No existing safety devices will be defeated or bypassed. All wells are equipped with surface safety valves for well control and all production will continue to be routed through surface safety equipment. • Beluga River wells produce a benign fluid consisting of approximately 99.1% methane, 0.6% nitrogen, and 0.3% CO2. No condensates and very little water is produced in conjunction with the gas. As such, there are no known instances of tubing leaks or downhole corrosion in the Beluga River Field. • Well 241 -34 is believed to have competent tubing and casing. As a precaution, an MIT of the 9 -5/8" casing will be conducted prior to performing the necessary wellwork. Should the well fail an MIT, the wellwork will be postponed pending further evaluation. In addition, the 9 -5/8" x 13 -3/8" annulus will be monitored should the integrity of the 9 -5/8" casing be compromised in the future. Tubing and annular pressures are monitored and reported daily. • The interval to be produced through the annulus is not a known sand producer and the risk of eroding the production casing or the long string of tubing is considered minimal. As a precaution, all wells are tested annually with an acoustic monitoring device to ensure they are produced at a sand free rate. Please refer to the attached well schematic and sundry form for additional information. If you have any questions regarding this request, please contact Brian Seitz at (907) 265 -6961. Sinc r , Ken L. Donajkow i Beluga sset m - l attachments RECEIVED JUL 161998 Asia Oil & Ancho r ge minion ARCO Alaska, Inc. is a Subsidiary of AtlanticRfchfieldCompany • • STATE OF ALASKA . - C0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ❑ Suspend 0 Operation Shutdown ❑ Re -enter suspended well 0 Alter casing ❑ Repair 0 Plugging 0 Time extension ❑ Stimulate ❑ Change approved program ❑ Pull tubing ❑ Variance ® Perforate ❑ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development ® G.L. =88', K.B. =110' Exploratory ❑ 3. Address Strati ra hic g p ❑ 7. Unit or Property name PO Box 100360, Anchorage, AK 99510 -0360 Service ❑ Beluga River Unit 4. Location of well at surface 8. Well number 897' FNL, 1397' FEL, T13N, R1OW, Section 34 241 -34 String 2 At top of productive interval 9. Permit number Same as above 72 -0016 At effective depth 10. API number Same as above 50- 283 - 20038 -00 At total depth 11. Field/Pool Same as above Beluga River 12. Present well condition summary Total Depth: measured 6501 feet Plugs (measured) 5477' true vertical 6501 feet Effective depth: measured 5445 feet Junk (measured) true vertical 5445 feet Casing Length Size Cemented Measured depth True vertical depth Structural 16' 30" 44' 44' Conductor 381' 20" 800 SKS 405' 405' Surface 2356' 13 -3/8" 1705 SKS 2380' 2380' Intermediate Production 90' 10 -3/4" 112' 112' 6267' 9 -5/8" 1060 SKS N \/ 6389' 6389' Perforation depth: measured RECEIVED See Attached Well Schematic true vertical V Straight hole - same as measured depth J U L 16 1998 Tubing (size, grade, and measured depth See attached well schematic Alaska 011 & Gas Cons. Commission Packers and SSSV Anchorage (type and measured depth) 0 See attached well schematic 13. Attachments Description summary of proposal ® Detailed operation program ❑ BOP sketch ❑ 14. Estimated date for commencing operation 15. Status of well classification as: July 1998 16. If proposal was verbally approved Oil ❑ Gas e Suspended ❑ Name of approver Date approved Service 17. I hereby c,1r; fy that the f. regoigg true and orrect to the best of my knowledge. Signed / ` ' ~ Title Beluga Staff Manager Date / 2, / FOR COMMISSION USE ONLY Conditions of app .val: Notify • . i ss i on so representative may witness { Approval Nos... a' � Plug integrity ❑ BOP Test ❑ Location clearance ❑ i Mechanical Integrity Test igi Subsequent form require 10- lid el- Co e d � o Approved by the order of the Commission Original Sinned Ry Commissionef pp e'N / e Form 10 -403 Rev 5/03/89 vavid W. Johnston 1 / - SUBMIT IN TRIPLICATE • • ConocoPhillips Alaska, Inc. Mechanical Integrity Test OPERATOR: ConocoPhillips Alaska, Inc. FIELD / UNIT / PAD: BRU 241 -34 DATE: See below OPERATOR REP: Cameron Merritt Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 241 -34 Type Inj. N TVD Tubing 0 1010 1070 1150 Interval 0 P.T.D. 1720160 Type test P Test psi 1000 Casing 450 450 450 450 P/F P Notes: 7/21/11 MIT -Short String with tubing plug @ 3037' OA 280 290 290 290 Well 241 -34 Type Inj. N TVD 2,997' Tubing 0 0 0 0 Interval 0 P.T.D. 1720160 Type test P Test psi 1000 Casing 450 1,000 999 1,005 P/F P Notes: 7/22/11 CMIT TxIA to top packer @ 2997' with plugs OA 350 _ 290 290 _ 290 in SS and LS tubing Well 241 -34 Type Inj. N TVD Tubing 0 0 0 0 Interval 0 P.T.D. 1720160 Type test P Test psi 1000 Casing 260 260 260 260 P/F F Notes: 7/23/11 MIT -OA 10 - 3/4" x 13 -3/8" annulus OA 350 1,000 955 910 Test failed on leakoff, likely through shoe Well 241 -34 Type Inj. N TVD 2,997' Tubing 600 950 1,100 1,210 Interval 0 P.T.D. 1720160 Type test P Test psi 1000 Casing 0 0 0 0 P/F P Notes: 7/24/11 MIT -Long String with tubing plug © 3600' OA 450 450 450 450 3600' and (thermal increase in pressure Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) BRU 241 -34 MIT Form.xls • • .. z i j 1t } { } 2w { ConocoPhillips BRU 241 -34 API# 50- 283- 20038 -00 - } {{ Gas Producer Annulus Fluid: Produced Gas (Annular Flow) HA Dual Comp. # Annular Flow Max Hole Angle: 1.5° @ 958' Spud Date 6/17/72 lc Sect. 34, T13N, R1OW, NE 1/4 RKB to Ground: 21.5' Last Completion 9/21/86 1 1 2x ASP @ Beluga: 2,624,279; 316,519 RKB to SL: 109.7' Schematic Rev. 6/28/04 ld i sc z CASING & TUBING Hole by TDT } { 2y A Description OD Btm. Weight Grade Thread Size Cement A Surface Csg. 20" 405' 94. # H -40 Buttress 26" 800sx "G ". Intermediate 13 3/8" 2,380' 68. # K -55 Buttress 17 1/2" 1620sx "G ". Bump plug. _ Prod. Casing 10 3/4 113' 51. # P410 8rd 12 1/4" 585sx @shoe, 475sx @ 3512' B Prod. Casing 9 5/8 5,238' 43.5 # N -80/P -110 8rd 12 1/4" collar. Bump plug 2500psi B Prod. Casing 9 5/8 6,500' 43.5 # P -110 Buttress 350sx "G" in 10x13 Annulus C Prod. Tbg (Htr) 2 3/8" 1,829' 4.6 # N -80 Buttress C Prod. Tbg. 2 2 7/8" 3,543' 6.5 # N -80 EUE -8rd Prod. Tbg. 1 2 7/8" 5,429' 6.5 # N -80 EUE -8rd collar _ } { 2z ] Str. Lbl. Top JEWELRY& FISH Length ID OD le,f H A 1,828' "XN" Nipple, Otis 0.85' 1.751" 2.719" lg - INC 2 w 685' "X" Nipple, Otis 1.20' 2.313" 3.25" D� 2 x 2,998' SS - XD Sliding Sleeve, Otis "XD" Open 7/29/98 3.20' 2.313" 3.719" DJ 2 y 3,037' "X" Nipple, Otis 1.20' 2.313" 3.25" 2 z 3,541' "XN" Nipple, Otis 1.20' 2.205" 3.25" E All a 22' FMC Tubing Hanger 2.60' 2.41" 4.18" 1 b 777' "X" Nipple, Otis 1.20' 2.313" 3.25" _ 1 c 2,965' Safety Jt, Brown "CC" 1.40' 2.437" 3.625" = _ 1 d 2,997' Pkr Packer, Brown Dual, HS- 17 -2C, 50k# 7.15' 2.375" lh,I B 1 e 3,548' Safety Jt, Brown Straight pull 32k# 0.90' 2.441" 3.50" lj $ 7r 1 f 3,580' SS -XD Sliding Sleeve, Otis "XD" Closed 9/10/94 3.20' 2.313" 3.719" 1k } { E 1 9 3 Pkr Packer, Brown HB -1 w/ XO's, 50k# 9.22' 4.00" 1 h 3,975' Safety Jt, Brown Straight pull 32k# 0.90' 2.441" 3.50" 1 I 4,007' SS -XD Sliding Sleeve, Otis "XD" Open 9/20/94 3.20' 2.313" 3.719" 1 j 4,010' Pkr Packer, Brown HB -1 w/ XO's, 50k# 9.70' 4.00" 1 k 4,051' "X" Nipple, Otis 1.20' 2.313" 3.25" 1 L 4,648' Safety Jt, Brown "CC" 1.40' 2.437" 3.625" 1 m 4,682' SS -XD Sliding Sleeve, Otis "XD" Open 9/20/94 3.20' 2.313" 3.719" 1 n 4 Pkr Packer, Brown HB -1 w/ XO's, 50k# 9.73' 4.00" E 1 0 4,726' "X" Nipple, Otis 1.20' 2.313" 3.25" 1 p 5,070' Safety Jt, Brown "CC" 1.40' 2.437" 3.625" 1 q 5,102' SS -XD Sliding Sleeve, Otis "XD" Open 9/20/94 3.20' 2.313" 3.719" 1L,m 1 1 1 r 5,105' Pkr Packer, Brown HB -1 w/ XO's, 50k# 9.00' 4.00" In 111111111 1 s 5,145' "X" Nipple, Otis 1.20' 2.313" 3.25" to } { 1 t 5,396' "XN" Nipple, Otis 1.26' 2.205" 3.25" _ 1 u 5,428' Shear Sub, Brown 2.441" 3.75" Pressure Datum: Sterling 3450' SS: 3,560'MD Beluga 4000' SS: 4,110'MD _ _ PERFORATIONS, FILL & PLUGS Net Zone Top Btm. Status Date SPF Ft. WSO 3,056' 3,057' Sqz'd 365 sx cmt 07/72 4 1p,q TT A i,Ubb' i,lb /' Ong 4 SPF, Reperttl 8 SPF 09/86 12 64' 1r _F . B 3,244' 3,340' Orig 4 SPF, Reperfd 8 SPF 09/86 12 51' C 3,362' 3,503' Orig 4 SPF, Reperfd 8 SPF 09/86 12 67' 1s } { H D 3,518' 3,545' Orig 4 SPF, Reperfd 8 SPF 09/86 12 12' D 3,614' 3,738' Open, String 1 - Top interval 07/72 4 61' E 3,797' 3,968' Open, String 1 - Top interval 07/72 4 42' _ H E 4,072' 4,138' Open, String 1 - Upper mid interval 07/72 4 66' 1t,u } { F 4,499' 4,503' Open, String 1 - Upper mid interval 07/72 4 4' G 4 5,048' Orig 4 SPF 09/86 8 74' 5477' , H 5,137' 5,375' Orig 4 SPF, Reperfd 4 SPF 09/86 9 110' PLUG 5,477' Halliburton cast iron BP 07/72 H 5,490' 5,742' Plugged. DST #2 07/72 4 35' E>. PBTD 6,455' Float Collar at 6455' 07/72 ct TAGS Str 2 7/30/98 3541'RKB 2.31" PXN Plug Str 1 2/14/03 5425'RKB 2" D.D. Bailer o 5/3/91 3541'RKB 2.3" Gauge ring 9/20/94 5445'RKB CTU FCO i- In PBTD 6455 ,.a FC ',TD 6501 , :,,_ Jul-98 Annular flow for Str 2 started after sliding sleeve at 2998 & MIT on 10 -3/4" showed on 55 psi drop in 1 hour. • Maunder, Thomas E (DOA) From: NSK Well integrity Proj [N1878~conocopl Sent: Thursday, Aprif 10, 2008 6:25 AM To: Maunder, Thomas E (DOA) Subject: RE: BRU 241-34 (172-016) Tom, The we11 is producing up three strings. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Wednesday, Apri109, 2008 4:08 PM To: Maunder, Thomas E (DOA) Cc: BRU Supv Subject: RE: BRU 241-34 (172-016) Tom, As 1 understand it, it produces up the original tubing and also up the heater string. But { wi{I check on it and get back with you. KP -Please confirm which strings are being produced. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Maunder, Thomas E (DOA) [maiito:tom.maunder@ataska.gov] Sent: Wednesday, Apri109, 2008 12:57 PM To: NSK Weil Integrity Proj Subject: BRU 241-34 (172-016) MJ, We have received the 404 for the 1998 sundry 398-192. As I read the sundry and the work report, the well now produces up 3 tubing strings, 2 x 2-7/8" and 1 x 2-3/8" (the original heater string). Please let me know if 1 am correct? Tom Maunder, PE AOGCC • ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri16, 2008 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~:.., APk E" ~ ~ii?8 Alaska Oil & G~;s C~±~s. Can~missior~ fiflCii{ti- itj8 Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well BRU 241-34 (String 2) PTD 172-016. A recent audit of the well file discovered the work associated with approved Sundry number 398-192 had been completed back in July 1998. However, no record of the subsequent 10-404 could be located in the well files or at the Alaska Oil and Gas Conservation Commission ("the Commission"). It is unknown whether a 10-404 was submitted after the work was initially completed. The purpose of this 10-404 is to close out Sundry 398-192 and update the Commission / with the status of the well. Please call me or Perry Klein at 659-7043 if you have any questions. Sincerely, ''~ i~~~~/~ y%7 G` ~ MJ L veland Well Integrity Project Supervisor Enclosure ~~ RE.CEI~ 7~ }~ ~ y STATE OF ALASKA • APR 0 ~ ~ 1'~' `' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAS & ~~ Corgi. `'r'~ '~~~~I~?:~~~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q Annular Flow . Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^~ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhlllips Alaska, InC. Development 0 Exploratory ^ 172-016 ' 3. Address: Strati ra hic Service g p ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-283-20038-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 110' BRU 241-34 String 2 8. Property Designation: 10. Field/Pool(s): FEDA029657 Beluga River ' 11. Present Well Condition Summary: Total Depth measured 6501' feet true vertical 6501' feet Plugs (measured) 5477 Effective Depth measured 5445 feet Junk (measured) true vertical 5445 feet Casing Length Size MD TVD Burst Collapse Structural Structural 16' 30" 44 44' Conductor 381' 20" 405 405' Surface 2356' 13-3/8" 2380 2380' Production 90' 10-3/4" 112' 112' 6267 9-5/8" 6389 6389' Perforation depth: Measured depth: strg 2: 3066-3167', 3244-3340', 3362-3503',3518-3545' true vertical depth: strg 2: 3066-3167', 3244-3340', 3362-3503',3518-3545' Tubing (size, grade, and measured depth) 2_7/g~~ N-80, 3543' MD. Packers i£ SSSV (type & measured depth) Strg 2: Brown HS -17-2C Dual Pkr 3001' no SSSV - Otis N Nipple 685' 12. Stimulation or cement squeeze summary: Intervals treated (measured) NIA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A NIA NIA N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development^ ' Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 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: 398-192 Contact MJ Loveland/ferry Klein Printed Name MJ Loveland'" Title WI Project Supervisor ~, // Phone: 659-7043 Date ~ ' Signature ~ ~ ~~~~,~ / ORIGII~AL~ ~ ~y. Form 10-404 Revised 04/2004 ~~ ~~~' ~~~ ~ ~ 2 ~ / (.t~ Submit Original L~~i./8- BRU 241-34 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary July-98 Completed MITIA on 10-3/4" production string to 1300 psi -Passed -see attached data sheet July-98 Opened Otis XD sliding Sleeve @ 2998' July-98 Commenced Producing string 2 fluids up tubin and up annulus then thru the heater string Mar 27 08 12:39p CPAI BE~UG~ 2633912 p.2 --, ARCI} Alaska Inc. JVell Service Report 11Ueil field Days Date 2414 Beluga River i 7-1598 Contractor Operation at Report Time ARCO Aimee Golden Complete Mechanical Integrity Test on 10-3/4"Production Casing Remarks: 0600 Safety Meeting 0730 MIRU Gasp pump skid to pmduction casing CIosed diesel line inlet and outlet Initial PC = 4 psig Initial SC = 0 psig li"I'P = 780 psig ~t~ 2. Pamped diesel into production casing annulus and pressured up to 1350 psi 1241 PC =1289 psig SC = 0 psig 1254 PC =1257 psig SC = 0 psig 1304 PC =1247 psig SC = 0 psig 1314 PC =1241 psig SC = 0 psig 1325 PC =1237 psig SC = 0 psig 1335 PC =1235 psig SC = 0 psig 1341 PC =1234 psig SC = 0 psig 1430 Test good. Rig dawn. Signed by; Aimee L. ~olde~l !""~ ARCQ Alaska Inc. ~ . _ 3ellu a River Unit B RU 241-34 API#: 283-20038-00 Well Type: Gas Producer Spud Date: 5/72 Original RKB (Depth Ref): 109.7' Annulus Fluid: Diesel Last Compi: 9/86 Ground Level: 88.2' Top of Sterling: 3011' Schematic Rev: 9/94 Maximum Hole Angle: 0 ASP: 2624278,31651 NE 1/4 34,T13N, R10W An le at Perforations: 0 Dual w/ heater strip i A AA Je weirv .Depth Length t~uioment l.Q. ~~ 1 22' 2.60'_ FMC Tubing Hanger 2.41" 4.188" $ 2 77T 1.20' Otis "X"Nipple 2.313" 3.250" 3 2965' 1.40' Brown "CC" Safety Jt. 2.43" 3.625" 2 4 2997 7.15' Brown HS-17-2C Dual Pkr (50M#) 2.375" - 5 3548' .90' Brown Safety Jt. Straight pull (32M#) 2.441" 3.500" 6 3580' 3.20' Otis" XD" Sliding Sleeve 2.313" 3.719" 7 3583' 9.22' Brown HB-1 Pkr, w/XOs (50,000#) 4.00" - 8 3975' .90' Brown Safety Jt. Straight pull (32M#) 2.441" 3.500" $ 9 4007 3.20' Otis "XD" Sliding Sleeve 2.313" 3.719" C sleeve 10 4010' 9.70' Brown HB-1 Pkr, w/XOS (50M#) 4.00" - 3 D 1 4051'. 1:20' Otis "X"Nipple 2.313" 3.250" 4 ~7pc~ed 12 4648' 1.40' Brown "CC" Safety Jt. 2.437" 3.625" 13 4682' 3.20' Otis "XD" Sliding Sleeve 2.131" 3.719" E 14 4685' 9.73' Brown H8-1 Pkr. w/XOS (50M#) 4.00" - 15 4726' 1.20' Otis" X" Nipple 2.313" 3.250" F 16 5070' 1.40' Brown "CC" Safety Jt. 2.437" 3.625" 17 5102' 3.20' Otis "XD" Sliding Sleeve 2.313" 3.719" 5 18 5105' 9.00' Brown HB-1 Pkr. w/XOs (50M#) ' 4,00" - 6 19 5145' 1.20' Otis "X" Nipple 2.313" 3,250" 20 5396' 1.26' Otis "XN" Nipple 2.205" 3.250" 7 21 5428' Brown Shear Sub 2.441" 3.750" A 22' 2.60' FMC Tubing Hanger 2.410" .4.188" B 685' 1.20' Otis "X" Nipple 2.313" 3.250" C 2998' 3.20' Otis "XD" Sliding Sleeve 2.313" 3.719" 13 D 3001' 6.63' Brown HS-17-2C Dual Pkr. 2.375" - 9 E 3037 1.20' Otis "X" Nipple 2.313" 3.250" F 3541' .1.20' Otis "XN" Nipple 2.205" 3.250" 10 AA 22' 2.60' Tubing Hanger 2.410" .4.188" - 1 i BB 1828' .85' Casinq and Tubin Otis. "XN" Nipple (1.751 " no go) a 1.751" 2.719" _ D?S~pt~ sS.II.@ Weight .~dg Thread 1412 B ottom 12 Surface 20 ' ~ , 94# H-40 BTC G L 405' Intermediate 13 3/8" 68# K-55 BTC GL 2380' 13 Prod. Casing 10 3/4" 51# P-110 8RD G4 112' 14 95/8" 43.5# P-110,N-$0 8RD/Butt 112' 6500' Prod. Tuning 2 7/8" (1) 6.5# N-80 EUE-8RD 5429' 15 Prod. Tubing 2 7/8" (2) 6.~# N-80 EUE-8RD 3543' Heater tbg 23/8" (3) 4.6# N-80 Butt 1829' 16 Perto ations j~gt p roducttan 17 ~,g DIL Qg, t~h De nsity Foat e, Inter val S tatus 18 A 3066'-316T 2 SPF 65' Open B 3244'-3340' 12 SPF 51' ~ Open 19 C 3362'-3503' 42 SPF 6T Open D upper 3518'-3545' 12 SPF 12' String 2 Open 20 D 3614'-3738' 4 SPF 61' Open 21 E 3797-3968' 4 SPF 42' String 1 Open E bwer 4072'-4138' 4 SPF 66' Open PBTD 5477 F _4184'-4503' 4 SPF 84' ~, Open G 4732'-5048' 8 SPF 74' Ooen H 7aq Da 5137-5375' ta 8 SPF 110' Open String 2 TD 6501' 5/3191 2.3" String 1 guage ring XN at 3541' RK8 7/30194 1.5" bailer, fill at 542T, bai l to 543T RKB 9/20/94 2" bailer, fill at 5445' RKB after CTU clean 8/10/95 STATE OF ALASKA · ALASKA elf AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Alter casing [] Repair [] Change approved program [] Operation Shutdown [] Re-enter suspended well [] Plugging [] Time extension [] Stimulate [] Pull tubing [] Variance [] Perforate [] Other . Name of Operator ARCO Alaska, Inc. Address PO Box 100360, Anchorage, AK 99510-0360 Location of well at surface 897' FNL, 1397' FEL, T13N, R10W, Section 34 At top of productive interval Same as above At effective depth Same as above At total depth Same as above 5. Type of Well: Development [] Exploratory [] Stratigraphic [] Service [] 6. Datum elevation (DF or KB) G.L.=88', K.B.=110' 7. Unit or Property name Beluga River Unit Well number 241-34 Strin~l 2 9. Permit number 72-0016 10. APl number 50-283-20038-00 11. Field/Pool Beluga River 12. Present well condition summary Total Depth: measured 6501 true vertical 6501 feet Plugs (measured) feet 5477' Effective depth: measured 5445 true vertical 5445 feet Junk (measured) feet Casing Length Size Structural 16' 30" Conductor 381' 20" Surface 2356' 13-3/8" Intermediate Production 90' 10-3/4" Cemented 800 SKS 1705 SKS 6267' 9-5/8" 1060 SKS . V Perforation depth: measured . See Attached Well Schematic true vertical Straight hole - same as measured depth Tubing (size, grade, and measured depth See attached well schematic Packers and SSSV (type and measured depth) See attached well schematic Measured depth Trueverticaldepth 44' 44' 4O5' 405' 2380' 2380' 112' 112' 6389' 6389' RECEIVED JUL 16 1998 Naska 0il & Gas Cons. Commluton Anchorage 13. Attachments Description summary of proposal [] Detailed operation program [] BOP sketch [] 14. Estimated date for commencing operation July 1998 16. If proposal was verbally approved Name of approver 1Si:n::ere~regoi@/~ true and~rj ~ ~,.......~~ect Date approved 15. Status of well classification as: Oil [] Gas [] Suspended [] Service to the best of my knowledge. Title Beluga Staff Manager Date Location clearance [] I Approval No~,~l~, Subsequent form require 10- ' pp~ (~ FOR COMMISSION USE ONLY Conditions of a oval: Notify nission so representative may witness Plug integrity [] BOP Test [] Mechanical Integrity Test ~ Approved by the order of the Commission Form 10-403 Rev 5/03/89 Original Si.c/ned Oavid W. J0hnst0 ] Commissioner SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Post Office Box .,~0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 June 14, 1998 Mr. D. W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: BRU 241-34 Flow Exception Dear Mr. Johnston: ARCO proposes opening a sliding sleeve above the upper packer in BRU 241-34 and simultaneously producing the well up the tubing and production casing annulus. Article 3 of the Alaska Administrative Code 25.200 stipulates that unless otherwise specifically approved by the commission, "all wells capable of unassisted flow must be completed with downhole production equipment consisting of suitable tubing and a packer which effectively isolates the tubing-casing annulus from fluids being produced". ARCO believes that production above the packer in BRU 241-34 presents no safety or environmental risk and requests an exception to this requirement. Two wells in the Beluga River Field (BRU 214-26 and BRU 224-23) were granted flow exceptions in February of last year. To date, BRU 214-26 has undergone the necesSary modifications and been flow tested with annular production. A rate gain of 4 MMscf/d was achieved and annular flow has been utilized sparingly to meet peak winter production demands. During normal operations, the well continues to be produced only up the production tubing. Production modifications to BRU 224-23 have been deferred as the potential rate benefits are not as significant. Results similar to those achieved with BRU 214-26 are expected from BRU 241-34. As summarized below, the risks associated with annular production in the Beluga River Field are considered minimal: The heat string is no longer being utilized. While necessary in the past to prevent the formation of hydrates, reservoir pressures have declined to the extent that downhole hydrate formation is not a problem in any Beluga River wells. JuL 6 ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company Alaska 0i! & Gas Cons. Commission Anchorage AR3B-6003-C Page 2 No existing safety devices will be defeated or bypassed. All wells are equipped with surface safety valves for well control and all production will continue to be routed through surface safety equipment. Beluga ~River wells produce a benign fluid consisting of approximately 99.1% methane, 0.6% nitrogen, and 0.3% CO2. No condensates and very little water is produced in conjunction with the gas. As such, there are no known instances of tubing leaks or downhole corrosion in the Beluga River Field. Well 241-34 is believed to have competent tubing and casing. As a precaution, an MIT of the 9-5/8" casing will be conducted prior to performing the necessary wellwork. Should the well fail an MIT, the wellwork will be postponed pending further evaluation. In addition, the 9-5/8" x 13-3/8" annulus will be monitored should the integrity of the 9-5/8" casing be compromised in the future. Tubing and annular pressures are monitored and reported daily. The interval to be produced through the annulus is not a known sand producer and the risk of eroding the production casing or the long string of tubing is considered minimal. As a precaution, all wells are tested annually with an acoustic monitoring device to ensure they are produced at a sand free rate. Please refer to the attached well schematic and sundry form for additional information. If you have any questions regarding this request, please contact Brian Seitz at (907) 265-6961. Ken L.~Donajkows,~ Beluga Asset maO~er attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED Naska 011 & 6as Co~s. cemm~o~ Anchorage ARCO Alaska, Inc. BRU 241-34 Spud Date: 5/72 Last Compl: 9/86 Schematic Rev: 9/94 ~ NE 1/4 34,T13N, R10W 1 A AA ~ ~D '1 --F 'I '1 '1 '1 ] ] ] ] '1 ] 5477' 2 5 6 7 8 9 10 11 12 13 14 15 16 17i 18 19 20 21 3eluqa River Unit APl#: 283-20038-00 Original RKB (Depth Ref): Ground Level: Maximum Hole Angle: Angle at Pedorations: Jewelry DeDth Lenoth 1 22' 2.60' 2 777' 1.2o' 3 2965' 1.40' 4 2997' 7.15' 5 3548' .90' 6 3580' 3.20' 7 3583' 9.22' 8 3975' .90' 9 4007' 3.20' 1 o 4Ol o' 9.70' 1 4o51' 1.2o' 2 4648' 1.40' 13 4682' 3.20' 14 4685' 9.73' 15 4726' 1.20' 16 5070' 1.4o' 17 51o2' 3.20' 18 51o5' 9.00' 19 5145' 1.2o' 20 5396' 1.26' 21 5428' A 22' 2.60' B 685' 1.20o C 2998' 3.20' D 3001' 6.63' E 3037' 1.20' F 3541' 1.20' AA 22' 2.60' BB 1828' .85' TD 6501' 109.7' 88.2' 0 0 Well Type: Gas Producer Annulus Fluid: Diesel Top of Sterling: 301 1' ASP: 2624278,31651 Dual w/heater string FMC Tubing Hanger Otis "X" Nipple Brown "CC" Safety Jt. Brown HS-17-2C Dual Pkr (50M#) Brown Safety Jt. Straight pull (32M#) Otis" XD" Sliding Sleeve Brown HB-1 Pkr. w/XO,s (50,000#) Brown Safety Jt. Straight pull (32M#) Otis "XD" Sliding Sleeve Brown HB-1 Pkr. w/XO,s (50M#) Otis "X" Nipple Brown "CC" Safety Jt. Otis "XD" Sliding Sleeve Brown HB-1 Pkr. w/XO,s (50M#) Otis" X" Nipple Brown "CC" Safety Jt. Otis "XD" Sliding Sleeve Brown HB-1 Pkr. w/XO,s (50M#) Otis "X" Nipple Otis "XN" Nipple Brown Shear Sub FMC Tubing Hanger Otis "X" Nipple Otis "XD" Sliding Sleeve Brown HS-17-2C Dual Pkr. Otis "X" Nipple Otis "XN" Nipple Tubing Hanger Otis "XN" Nipple (1.751" no go) Casing an~ Tubing Descri0ti0n Size Surface Intermediate 13 3/8" Prod. Casing 10 3/4" Prod. Tubing 2 7/8" (1) Prod. Tubing 2 7/8" (2) Heater tbg Perforations zone DIL De_bib Density A 3066'-3167' 12 SPF B 3244'-3340' 12 SPF C 3362'-3503' 12 SPF D upper 3518'-3545' 12 SPF Weight Grade 20 94# 68# K-55 51# P-110 g 5/8" 43.5# 6.5# N-80 6.5# N-80 2 3/8" (3) 4.6# D 3614'-3738' 4 SPF E 3797'-3968' 4 SPF E lower 4072'-4138' 4 SPF F 4184'-4503' 4 SPF G 4732'-5048' 8 SPF H 5137'-5375' 8 SPF Ta0 DSt8 Strino 2 -- 5/3/91 2.3" guage ring XN at 3541' RKB I.D. O.D. 2.41" 4.188" 2.313" 3.250" 2.43" 3.625" 2.375" - 2.441" 3.500" 2.313" 3.719" 4.00" - 2.441" 3.500" 2.313" 3.719" 4.00" - 2.313" 3.250" 2.437" 3.625" 2.131" 3.719" 4.00" - 2.313" 3.250" 2.437" 3.625" 2.313" 3.719" 4.00" 2.313" 3.250" 2.205" 3.250" 2.441" 3.750" 2.410" 4.188" 2.313" 3.250" 2.313" 3.719" 2.375" 2.313" 3.250" 2.205" 3.250" 2.410" 4.188" 1.751" 2.719" Thread TOD H-40 BTC BTC GL 8RD GL P-110,N-80 8RD/Butt EUE-SRD EUE-SRD N-80 Butt Net Footaoe. Interval -- 65' 51' ~ 67' 12' String 2 GL 405' 2380' 112' 112' 6500' 5429' 3543' 1829' Status Open Open Open Open 61' Open 42' Strinq 1 Open 66' ) Open 84' Open 74' Open 110' Open String I 7/30/94 1.5" bailer, fill at 5427', bail to 5437' RKB 9/20/94 2" bailer, fill at 5445' RKB after CTU clean 8/10/95 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 D A Grove, BRU/Kup Staff Mgr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Grove: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994, Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and,~ if the latter, the reasons you believe a written submission would be insufficient. David W Johnston . Chairman \~.~.....~ jo/rpc~z-energy .)Drip, ted on recycled Chevron Chevron U.S.A. Inc. 6001 Bollinger Canyon Road, San Ramon, California Mail Address: P.O. Box 5043, San Ramon, CA 94583-0943 ,J. E Coltart Manager NomOpera~ed Joim Vemu~es Production Department Western Flegion June 9, 1987 Mr. L. C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Smith: Please find attached the workover completion report for well BRU 241-34, Beluga River Unit. The report was inadvertently overlooked due to our Anchorage office closure and transfer of operations during October 1986. JGB:skw Attachment Very truly yours, cc: ARCO Alaska Inc. Mr. J. C. Havard P. O. Box 100360 Anchorage, AK 99510 UNOCAL Oil and Gas Division Mr. G. A. Graham P. O. Box 6247 Anchorage, AK 99502 Marathon Oil Company Mr. D. L. Jones P. O. Box 102380 Anchorage, AK 99510 .i STATE OF ALASKA \~i-~ '. ) ALAS~"O-I L AND GAS CONSERVATION COi~ISSlON WELL COMPLETI'ON OR RECOMPLETION REPORTAND.LOG 1. Status of Well Classification of Service Well OIL [] GAS [~ SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number 72-0016 Chevron U.S.A. Inc.- 3. Address 8. APl Number P. 0. Box 107839, Anchorage, AK 99510 50-283-20038 4. Location of well at surface 899'S & 1399'W of NE Corner Sec. 34, 13N, lOW, SB&M At Top Producing Interval Same At Total Depth Same 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. G.L. = 88' K.B. = 110' J A-029657 12. Date Spudded ] 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 6-17-72 ! 7-14-72 9-26-86 17. Total Depth (M D+TVD) ! 1'8. Plug Back Depth (MD+TVD) I 6501' MD(MD=TVq) 5477' MD 22. Type Electric or Other Logs Run GR/££L GR/CNL 23. 9. Unit or Lease Name Beluga River Unit 10. Well Number BRU 241-34 11. Field and Pool Beluga River, Beluga and Sterl lng 19. Directional Survey YES [] NO ~] 15. Water Depth, if offshore 16. No. of ComPletions NA feet MSL Dual 20. Depth where SSSV set I 21. Thickness of Permafrost NA feet MD I NA CT/CET MFC (60 Arm Caliper) CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. 13 3/8" 9 5/8" 10 3/4" GRADE 51 TOP P-110 SETTING DEPTH MD BOTTOM (Top 90' HOLE SIZE CEMENTING RECORD 10 3/4") 30" COND Surf 44' 20" Surf 405' 800 SKS Surf 2380' 1705 SKS 43.5 P-110&NSO ' 112' 6500' 1060 SKS CSG is 24. Perforations open to Production (MD+TVD of Top and of Prod fottom and 25. TUBING RECORD AMOUNT PULLED interval, size and number) 4732' - 5048' 5137' - 5375' 3545' - 3244' 3I'67' - 3066' (3614' - 4503' 4 SPF 1/2" Holes 4 SPF 1/2" Hol.es 8 SPF 1/21' Holes 8 SPF 1/2" Holes 4 SPF 1/2" Holes: Not currently being produced - isolated.. w/packers) SIZE 2 /18" DEPTH SET (MD) 5~29: PACKER SET (MD) 3T~87 , 40 i 5,4689, 2 7/8" 3543' 3001' 26. Heater String (~f TBG: 2 3/8" TBG @ 1829' 27. IDate First Prodiction Flow Tubing I Casing Pressure ~'r-""~.st536 I 0 PRODUCTION TEST WATER-BBL IMethod of Operation (Flowing, gas lift, etc.) -Flowino PRODUCTION FOR IOTL-BBL I GAS-MCF I TESTPERIOD I~ I I CALCULATED ~IOIL-BBL IGAS-MCF 24-HOUR RATE -~1 0 113_. 542 28. CORE DATA WATER-BBL 0 ICHOKESlZE tGAS'OILRATIO OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Submit in duplicat~ Form 10~,07 Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MAF~KERS FORMATION TESTS . . . . ,, . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ,.. INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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 :-- ~ STATE OF ALASKA ALA~_ ..... OIL AND GAS CONSERVATION CON,,,. .,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Alter Casing [] Other I~ 2. Name of Operator Chevron U.S,^, Inc. 3. Address ... P 0, Box 107839, Anchorage, AK 99510 4. Location of well at surface _ 899'S& 1399'N of NE Corner Sec. 34, 13N,10W, SB&M Plugging [] Perforate [] Pull tubing 1~ 5. Datum elevation (DF or KB)~~ G.L. = 88' K.B. = llO'F 6. Unit or Property name Beluga River Unit 7. Well number BRU 241-34 At top of productive interval - Same At effective depth Same At total depth Same 8. Approval number 72-0016 9. APl number 5o- 283-20038 10. Pool .,.Sterling & Beluga 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 6501 feet 6501 feet Plugs (measured) 5477 feet Junk (measured) 5477 feet Casing Structural " Conductor Surface Production Perforation depth: Length Size Cemented Measured depth ~16 ' 30" ~ 44' ~'381' 20" 800 SKS 405' 2356' 13 3/8" 1705 SKS 2380' 90' 10 3/4" 112' · 6267' 9 5/8" 1060 SKS 6500' 5137' - 5375' 4732' - 5048' 3167' true vertical Same Tubing (size, grade and measured depth) 2 7/·8" N80 @ 5429', 2 7/8" N80 @ 3543', 2 3/8" N80 @ 1829' Packers and SSSV (type and measured depth) 3001', 3587', 4015', 4689', 5'109' (Packers) Top 90' of~ Production Casing is 10 3/4" 51# P-110 CSG. measured ' 3545' - 3244' Wue Vertical depth 44' 405' 2380' 112' 6500' - 3066' (3614' - ·4503.' not currently being produced). 12'. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to oPeration Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 13,542 0 0 Tubing Pressure 1536 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~-~,~~~ Title '~-'~'/~,~~ Form 10-404 Rev. 12-1-85 WORKOVER COMPLETION REPORT BELUGA RIVER FIELD, RLRSKA Unit Name- Beluga River Unit Lease No: A-029657 Wel 1 No.- BRU 241-34 Surface Location: 899'S & 1399' W of NE Corner Sec. 34, T13N, RiOW, SB&M Drilling Rig- Brinkerhoff Signal Inc. Rig Grace #158 Rig Acceptance' August 27, 1986 Rig Released: September 28, 1986 Elevation- G.L. : 88' K.B. = 110' Total Depth: 6501' MD (MD = TVD) Plug Back Depth: 5477' MD Casing: 30" Conductor at 44' 20" Surface Cemented at 405' 13 3/8" Cemented at 2380' 10 3/4" Top 90' of Production Casing 9 5/8" Cemented at 6500' Tubing: 2 3/8" Tubing Heater String @ 1829' 2 7/8" Tubing @ 5429' 2 7/8" Tubing @ 3543' Packers- 3001' (Dual), 3587' 4015' 4689' 5109' Perforations- 3167' - 3066' 8JSPF 1/2" Holes 3545' - 3244' 8JSPF 1/2" Holes 4732' - 5048' 4jSPF 1/2" Holes 5137' - 5375' 4JSPF 1/2" Hol es 3614' - 4503' 4JSPF 1/2" Holes (Not currently being produced ) Logs Run' Schlumberger GR/CCL GR/CNL GR/CET MFC (60 Arm Caliper) WELL: BRU 241-34 08-27-86 24 HR SUMMARY: RIG-UP MD: 6,501' PBTD: 5477'. CSG: 9 5/8" ~ 6500' 08-28-86 24 HR SUMMARY: RIG-UP 08-29-86 24 HR SUMMARY: RIG-UP 08-30-86 24 HR SUMMARY: RIG-UP 08-31-86 MW: 9.5 24 HR SUMMARY: CIRC DOWN #1 & UP #3 TO CIRC ZONE BETWEEN PKRS ~ 2856' & 3181' W/9.5 BRINE. CIRC OUT 9.7 BRINE TILL STABLE 9.5 PPG RETURNS. R/U ON STRING #2. BAILED SAND & SLUDGE. AEC 'IX' PLUG. STRING ON VACUUM. R/U ON #1. RIH AND CLOSED SLEEVE @ 3177'. POOH. GAS TO SURFACE IN STRING #2, HAVE 600 PSI. 09-01-86 MW: 9.5 24 HR SUMMARY: M/U PIPE CUTTER. RIH (STRING #1) TO 3566.5' AND CUT. KILLED ZONE 3181'-3572' W/9.5 PPG BRINE. ENTIRE WELL STATIC. SET BPV'S IN ALL FOUR STRINGS. N/D XMAS TREE. 09-02-86 MW: 9.5 24 HR SUMMARY: N/U CLASS III 5000 PSI BOPE. L/D 64 JTS 2 3/8" 8RD N-80 EUE HEATER STRING. 09-03-86 MW: 9.5 24 HR SUMMARY: DUAL 2 7/8" TBG. L/D 92 JTS OF 2 3/8" TBG STRING #3. PULL & L/D 09-04-8.6 MW: 9.5 24 HR SUMMARY: L/D DUAL 2 7/8" TBG (STGS #1 & #2). AEC TRIPLE PKR ('ro~ s'r~ ,~ ~o'r s^~T'~ ,~'r ~ ~', TO~ ST~ ~ ~0~ ~US~ 0 2864' DUAL PKR ~ 3181'. POOH W/FISH ~ 2864'. L/D 8 OT~ 5 PUP ~TS o~ ~ ~ (TO~ ~ ST~ ~4~'). ~00../~S. ~ ~4~'-~C PKR & TAIL OF ~1 STB (TOF ~1 STG C~OFF 3566' ORIGINAL ~2 STG FISH RE~INS SITTING ON TOP OF PKR ~3 ~ 3572'. EST TOF 3236'. M/U RETRIEV~LE BP & RTTS PKR AND RIH. 09-05-86 MW: 9.5 24 HR SUMMARY: SET BP @ 2970'. TEST 9 5/8" CSG ABOVE 2970' W/2000 PSI. BLED TO 1955 PSI IN 30 MIN. 09-06-86 MW: 9.5 24 HR SUMMARY:: TEST BOPE. 09-07-86 MW: 9.5 24 HR SUMMARY: TEST BOPE PULL BP ~ 2970'. RIH FISHING TOOLS (OVERSHOT). GRAB #2 TBG S~G FISH @ 3232'. L/D 10 JTS 2 7/8' TBG, i PUP JT, & JEWELERY. 09-08-86 MW: 9.5 24 HR SUMMARY: RIH TO TOF 2 7/8" TBG CUTOFF @ 3566'. TBG TO CC SAFETY JT TOF @ 3997'. REC PKR & 09-09-86 MW: 9.5 24 HR SUMMARY: CLEAN INSIDE TBG OUT TO 4021' W/W.L. BAILER. ENGAGE FISH & PULL PKR @ 4008'. 09-10-86 MW- 9.5 24 HR SUMMARY: L/D FISH: PKR & 18 JTS 2 7/8" TBG. TOF @ 4590'. ENGAGE & WORK FISH. 09-11-86 MW- 9.6 24 HR SUMMARY: CIRC GAS CUT MUD. POH. 7/8" TBG & JEWELERY. RIH TO TOF @ 5077'. L/D FISH: PKR, 14 JTS 2 09-12-86 MW: 9.6 24 HR SUMMARY: CIRC GAS CUT MUD ABOVE FISH @ 5077'. ENGAGE & RETRIEVED FISH. L/D FISH: PKR, 5 JTS 2 7/8" TBG, & JEWELERY. 09-13-86 MW: 9.6 24 HR SUMMARY: L/D FISHING TOOLS. TAG FILL @ 5350'. CLEANOUT TO 5405' WITH 8 1/2" BIT. RAN GR/CNL, GR/CET, MFC 5415' - 2800'. 09-14-86 MW: 9.6 24 HR SUMMARY: CLEANOUT 5405' - 5473' PERF'D 4732'-5048' AND 5137'-5375' W/4JSPF 1/2" HOLES 22GM CHAR~ES 180DEG PHASING TUBING CONVEYED PERF GUNS. 09-15-86 MW: 9.6 24 HR SUMMARY: TEST CLASS III BOPE TO 3000 PSI. SET RET BP ~ 3572'. REPERF'D 3545'-3244' AND 3167'-3066 W/8JSPF 1/2" HOLES. 09-16-86 Mw: 9.6 MD: 6,501' 9 5/8" @ 6500; 24 HR SUMMARY: RETRIEVE BP. ~' START RUNNING LONG STRING OF 2 7/8" TBG. 09-17-86 MW: 9.6 ' 24 HR SUMMARY: FINISHED RUNNING 283 JTS (L.S. = 171, S.S. = 112 JTS) OF 2 7/8" 6.5# N-80 TBG. LONG STRING JEWELERY' BROWN MODEL HS-17-2C DUAL PKR @ 3001', BROWN HB-1 PKR'S @3587', 4015', 4689', 5109' OTIS 'XD' SLIDING SLEEVES (OPEN DOWN) @ 3580', 4007', 4682', 510~. OTIS 'X' NIPPLES (2.313") @ 777', 4052', 4725', 5145'. OTIS 2.313" (W/2.205" NO-GO) @ 5396'. BROWN SHEAR SUB (TBG TAIL) @ 5429'. SHORT STRING JEWELRY: BROWN DUAL HS-17-2C PKR ~ 3001' OTIS 'X' NIPPLES. (2.313") @ 684' & 3037". OTIS 2.313" (W/2.205" NO-GO) @3541'. MULE SHOED TBG TAIL @ 3543'. ALL DEPTHS ARE FROM ORIGINAL KB OF 110' ABOVE SEALEVEL. ' ~ "~ : ~ 09-18-86 MW: 9.5 24 FIR SUMMARY:: RAN HEATER STRING: MULE SHOE PUP JOINT, OTIS 1.875" ID 'XN' NIPPLE W/1.751" NO-GO, EUE 8RD X BUTT XO, 58 JTS (1801') OF 2 3/8" 4.6# N-80 BUTTRESS TBG. LAND TBG TAIL @ 1829', 'XN' NIPPLE @ 1827'. N/U FMC 3000# TRIPLE STRING WELLHEAD. 09-19-86 MW: 7.1 24 HR SUMMARY: R/U AND DISPLACE WELL TO DIESEL. ATTEMPT TO TEST 9 5/8" CSG X TBG ANNULUS ABOVE DUAL PKR. SHORT STRING INTEGRITY QUESTIONABLE. POOH. LEFT WIRELINE FISH OF 'N' TEST TOOL, ,)DC PULLING TOOL, MANUAL JARS, HYD JARS, 10' X i 1/2" SINKER BAR, ROP SOCKET PLUGS 10' OF WIRE IN WELL. LEAVE TEMPORARY WHILE DIAGNOSING PKR & SHORT STRING INTEGRITY. DETERMINED THAT SHORT STRING IS UN- STUNG BUT THAT DUAL PKR IS SUCCESSFULLY SET. TESTED PKR TO 1500 PSI F/30 MIN. 09-20-86 MW: 7.1 24 HR SUMMARY; CONT TESTING FOR PKR PROBLEM. DIRECT COMMUNICATION BETWEEN SNORT STRING & ANNULUS. RIH W/FISHING TOOLS {SHORT STRING). REC FISH. INSTALL DOUBLE CHECK VALUES IN ALL THREE STRINGS. TEST BOPE. TEST SHORT STRING T/1500 PSI - GOOD TEST. 09-21-86 24 FIR SUMMARY: TEST BOPE (JOE RUSSELL OF BLM AS WITNESS). M/U TREE. FLOW {STARTED @ 2130 HRS) ZONE #1. PERFS F/5137'-5375', PKR @ 5109'. RAT HOLE VOL = 52.7 BBL. O9-22-86 24 HR SUMMARY- CONT. FLOWING ZONE @ 5137' - 5375' TO CLEAN UP. 09-23-86 24 HR SUMMARY : COMPLETE CLEAN UP OF ZONE #1 {5137' - 5375'). FINAL RATE 2.553 MMCFPD on 20/64 CHOKE W/1280 PSI. PRODUCED TOTAL OF 56 BBL FLUID (RATHOLE : 52.7) OF WHICH AN EST. 7-8 BBL WAS COMPLETION BRINE. FLOWED ZONE #2 (4732' - 5048') IN COMBO W/ZONE #1. REC 17.25 BBL DIESEL (#2 RATHOLE 27.4 BBL). FINAL COMBINED RATE 2.842 )v~ICFPD on 24/64 CHOKE W/1400 PSI. FLOWED ZONES #1 & #3 (4072' - 4503') TO CLEAN UP RATHOLE IN #3 (VOL -- 38.3 BBL). REC 38 BBL DIESEL 27.9 BBL). REC 21 BBL DIESEL. FINAL COMBINED RATE 3.389 MMCFPD ON 18/64 CHOKE W/1360 PSI. 09-24-86 24 HR SUMMARY: FLOWED ZONE #2 (4732' - 5048') FOR FINAL CLEAN UP. FINAL RATE 2.55 MMCFPD ON 23/64 CHOKE W/1200 PSI. REC 5.5 BBL DIESEL (NO WATER OR SAND). FLOWED ZONE #3 (4072' - 4503') WITH FINAL RATE 4.43 MMCFPD ON 28/64 CHOKE W/1320 PSI. REC. 2.25 BBL DIESEL (NO WATER OR SAND). 09-25-86 24 HR SUMMARY: FLOWED ZONE #4 (3614 - 3943') FOR FINAL CLEAN UP. FINAL RATE 4.33 MMCFPD on 12/64 CHOKE W/1275 PSI. REC 3 BBL FLUID, ?ii~? ~?~ CUM RECOVERY 24 BBL (RATHOLE : 27.9 BBL). FLOWED ZONE #5 (3066' - 3548'), FINAL RATE 5.34 MMCFPD on 28/64 CHOKE W/1315 PSI. ZONE PRODUCED ONLY DRY GAS WITH NO SAND. INSTALL BPV IN ALL STRINGS. i~:'~i']~ SECURE WELL AND RELEASED RIG ~ 2400 HR g/26/86. PRES OPERATIONS: R/D -4- 09-26-86 24 HR SUMMARY: RIG-DOWN 09-27-86 24 HR SUMMARY: RIG-DOWN O9-28-86 24 HR SUMMARY' RIG-DOWN. LAST REPORT. Chevron Chevron U.S.A. Inc. 6OOl Bollinger Canyon Road, San Ramon, California Mail Address: P.O. Box 5043, San Ramon, CA 94583-0943 Production Department Western Region January 16, 1987 Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, AK 99501 'Attention' Mr. Chat Chatterton Gert tl emen: Enclosed, per your request, are the following: 1. BRU 211-3 2. BRU 212-18 3. BRU 241-34 Drill Stem Test Compl etlon Report Sundry Noti ce Any further questions may be addressed to Mr. Jess Brookley (415) 842-0321. - - Sincerely, J~ohn F. Coltart Manager, Non-Operated Joint Ventures MA:skw Enclosures RECEIVED FEB 0 2 1987 Alaska Oil & Gas Cons. Commission ,,,~.Rnchofa.ge ~'~i~ STATE OF ALASKA ~ ALA~ ,.)IL AND GAS CONSERVATION CON JlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] operation Shutdown [] Re-enter suspended well ~ Alter casing "-' Time extension ?' Change apProVed program [] Plugging [] Stimulate ~ Pull tubing ~ Amend order ~ Perforate X Other 2. Name of Operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of well at surface '- 899' S & 1399' W of NE Corner, Sec. 34, T13N, 10W, SB&M 5. Datum elevation (DF or KB) G,L,=88' K,B,= 110 6. Unit or Property name Beluga River Unit 7. Well number BRU 241-34 feet At top of productive interval Same At effective depth Same At total depth Same 8. Permit number 72-0016 9. APl number 50-- 283-20038 10. Pool Sterling & Beluga 11. Present well condition summary Total depth: measured true vertical 6501 feet Plugs (measured) 6501 feet Effective depth: measured true vertical 5477 feet Junk (measured) 5477 feet Casing Length Structural 16 ' Conductor 381 ' Surface 2356' In~r-med~a,te * 90 ' Production 6267' L~rre~ * Size Cemented Measured depth 30" 44' 20" 800 sks 405' 13 3/8" 1705 sks 2380' 10 3/4" 112' 9 5/8" 1060 sks 6389' Top 90' of productioncasing is 10 3/4" 51# P-110 Csg. Perforation depth: measured See Attached True Vertica, I. depth 44' 405' 2380' 112' 6389' true vertical See Attached Tubing (size, grade and measured depth) RECEIVED 1987 Packers and SSSV (type and measured depth) Alaska Oil & Gas Cons. Commission 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP.sketch '-- 13. Estimated date for.commencing operation Date approved n Su ~eri, nten 9' ~"8~'.' Appr ~val No. by order of the commission Date · 14. If proposal was verbally approved. Name of approver I 15'lhereby~~g'istrueandc°rrectt°thebest°fmykn°wledge Signed Title Acting Area Operation Superintende~)tate · __ · Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test I-I Location clearanceI Approved by Commissioner Form 10-403 Rev 12-1-85 Submit in triplicate PRO 316-1 PROPOSAL FOR WELL OPERATIONS WELL: FIELD: __ LOCATION: ELEVATION: PRESENT STATUS: BRU 241 - 34 Beluga River At surface: 899'S & 1399'W of NE Corner Section 34, T13N, R10W, SB&M At Top Prod. Interval: Same At PBTD: Same At TD: Same G. L. = 88' K.B. = 110' TD (MD): 6501' PBTD (MD): 5477' (Bridge Plug) Casing: 30" ~ 44' 20" Cemented ~ 405' 13-3/8" Cemented ~ 2380' 9-5/8" Cemented ~ 6389' 112'-SFC with 10-3/4" Pll0' Perforations: 5375'- 5345' 5331' - 5326' 5271'- 5255' 5233'- 5213' 5201' - 5186' 5161' - 5137' 5048' - 5032' 5024' - 5016' 4972' - 4968' 4911' - 4907' 4878' - 4875' 4858' - 4856' 4835' - 4831' 4784' - 4780' 4770' - 4766' 4757' - 4732' 4503' - 4499' 4489' - 4464' 4398'- 4394' 4386' - 4382' 4222' - 4215' 4186' - 4184' 4358'- 4337' 4276' - 4259' 4138' - 4072' 3968' - 3963' 3943'- 3939' 3900' - 3896' 3870'- 3866' 3836' - 3818' 3804'- 3797' 3738' - 3718' 3693'- 3681' 3663' - 3657' 3643'- 3623' 3617'- 3614' 3545' - 3537' 3522' - 3518' 3503' - 3493' 3462'- 3450 3425' - 3416' 3411' - 3405' 3340'- 3334' 3318' - 3312' 3392' - 3362' 3283' - 3244' 3167' - 3148' 3131' - 3126' 3111' - 3101' 3096' - 3066' 3057' - 3056' Squeezed 3024' - 3023' WSO Tubing: See the attached detaiL Junk: The No. 2 string is parted below the second packer at 3180'. The exact fish detail is unknown. NOTE: BLOWOUT CONSIDERATIONS: The Brown HS-17 3C packer at 2856' appears to be leaking. String No. 1 also appears to be leaking through either sleeves or the plug set in the "S" nipple at 4048'. . Gas: This well is capable of producing over 20,000 MCFD. Care must be taken at all times not to swab the well and to keep the hole full on trips. . Lost Circulation: None anticipated, but lost circulation material (salt pills) should be readily available at all times. 3, Precautions: Any kicks should be handled by normal procedures. Rig crews should be made aware of these methods, and care must be exeercised at all times. e Maximum Anticipated Formation Pressure: 2428 PSI (from build up data January 1977). Programmed weight of 9.6 PPG will provide 80 PSI minimum overbalance. Formation Equivalent In.terv.a! Pressure, PSI Mud Weight, PPG 3167' - 3066' 1446 9.1 3548' - 3244' 1404 8.3 3943' - 3614' 1646 8.8 4503' - 4072' 1504 7.1 5048' - 4732' 1941 7.9 5375' - 5137" 2428 9.1 5. Maximum A~tieipated Surface Pressure: 2274 PSI = Formation Pressure at TVD - .03 (Gas Gradient) *TVD 2428 = (.03 *5237) 6. Blowout Prevention Equipment: Minimum of Class III - 3000 PSI. BRU 241 - 34 WORKOVER PROGRAM . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. Prior to moving in the workover rig, install Cosasco BPV's in all four tubing strings. Move in and rig up the workover rig. Remove the back pressure valves from the ~1 and #4 tubing strings. RU C. A. White, and make sure all ~XA" sleeves in string #1 above 4048' are closed. Open the "XA" sleeve at 2811', and kill the annulus by circulating down the long string and taking returns through both the annulus and #4 string (heat string). RU C. A. White. Open the "XA" sleeve in string #1 at 3177'. Remove the · plug from the ~XA" sleeve in string #2 at 3167'. Open the "XA" sleeve in string ~2 at 3167'. Circulate the #1 and ~2 strings dead by circulating down string #1 and up string ~2. RU C. A. White. Remove the BPV from string #3. Remove the plug from the "D" nipple in string #3 at 2874'. Circulate the ~1 and #3 strings dead by circulating down string #1 and up string #3. RU C. A. White. Open the "XA" sleeve in string #1 at 3569'. Circulate the ~ 1 string dead by circulating down string # 1 and up string # 2. RU Schlumberger, and jet cut string #1 at 3566'. Install BPV's in all four tubing strings. Nipple down the tree. Nipple up the class III - 5000 PSI BOP stack; and test the rams, manifold, and valves to 5000 PSI. Test the annular to 3500 PSI. The BLM and AOGCC may witness the test, and must have 24 hours prior notice. Install offset 2-3/8" rams in BOP's. Pull out of the hole with the 2-3/8" heat string and production equipment. 'Change offset 2-3/8" pipe rams around. Pull out of the hole with the 2-3/8" #3 string and production equipment. RU dual slips, elevators, and tongs. Install dual rams in BOP's. BUR 241 - 34 WORKOVER PROGRAM Page 2 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. Release the triple packer at 2856' by shear release (approximately 40,000# over). Attempt to release the dual packer at 3181' by shear release. The safety joints at 3143' and 3155' are set for 50,000# shear release. Pull out of the hole, and lay down the tubing and production equipment. Pick up and trip in the hole with a guide, extension, overshot dressed with grapples, bumper sub, jars, pump out sub, drill collars, and drill pipe. Wash to the top of the fish estimated at 3236', and work over fish (estimated to consist of 10.75' 2-7/8" pup joint, 2-7/8" "XA" sleeve, 10.5' 2-7/8" pup joint, 2-7/8" "D" nipple, 10 joints 2-7/8" tubing, and wireline re-entry guide). Pull out of the hole and lay down the fish. Trip in the hole with a 9-5/" retrievable bridge plug and retrievable packer on drill pipe, and set the RBP at 2975' + Dump two sacks of sand on top of the RBP. Test the 9-5/8" casing above the RBP to 2000 PSI for 30 minutes. Locate leaks if there are any. A squeeze procedure will follow if there are any leaks. Pull out of the hole with the packer. If there are squeezes, after all squeezes and clean out runs are made, make a 9-5/8" casing scraper run to the top of the RBP. ND the BOPE and tubing spool NU the 13-5/8" x 11" 3000 PSI tubing spool and test to 1500 PSI. NU the BOPE and test to 3000 PSI. Trip in the hole with the retrieving tool, and POH with the RBP. PU and TIH with the fishing string to the top of the #1 tubing string at 3565'. Work over the top of the fish. RU C. A. White. Attempt to remove the plug from the "S" nipple at 4048'. If successful, attempt to remove the plug from the"D" nipple at 5109'. Release the packers with shear release. POH and lay down the tubing and production equipment. Pick up and TIH with'an 8-1/2" bit and the drill string. Clean out to PBTD, and circulate the well clean. Pull out of the hole. RU Schlumberger, and run CNL, CET, and Casing Inspection logs as directed by Anchorage Engineering. It will be decided at this time whether to test the bottom two zones and whether to reperforate the top two intervals° Additional procedures will follow as required. ~ F {~ ~ ~ V ~ D 1987 Alaska Oil & Gas Cons. Commission Anchorage BUR 241 - 34 WORKOVER PROGRAM Page 3 31. 36. 37. Trip in the hole with the 8-1/2" bit and easing scraper to PBTD. Circulate the well clean. Lay down the drill string. 32. RU dual slips, elevators, and tongs Install dual 2-7/8" pipe rams. 33. Run dual 2-7/8" production tubing and equipment per the attached proposed tubing detail Internally test the tubing below the table to 5000 psi. 34. Space out as required with a full joint on top, and install BPV's in both strings. Land the tubing in the parent hanger. 35. Install 2-3/8" pipe rams. Run the 2-3/8" heat string and equipment per the attached detail. Internally test the tubing below the table to 5000 PSI. Install the BPV, and land the 2-3/8" tubing. ND the BOPE, and NU the tree. Test the tree to 3000 PSI. Remove the BPV's. 38. 39. 40. 41. Reverse circulate diesel down the annulus until clean returns are obtained at the surface as follows: A. Up the heat string. B. Up the short string. C. Up the long string. Hydraulically set the packers. Pressure up and shear out the ball. Test the annulus/packer to 1500 PSI for 30 minutes. Open up the long string to the production seperator as directed by Anchorage Engineering, and flow the well until it cleans up. Open up the short string to the production seperator, and flow the well until it cleans up. Test the heat string side per the Area Production Foreman. Install BPV's in all three strings Release the rig, and rig down the rig. Remove the BPV's, and return the well to production. V. W. Angell WORKOVER FLUIDS PROGRAM BRU 241 - 34 BELUGA RIVER FIELD FLUIDS SYSTEM: PROPERTIE_S Type Weight (PPG) Viscosity (SEC/QT) Fluid Loss (CC/30 MIN) Plastic Vis. (CPS) Kill Circulating Litesal/Liteplug Litesal/Liteplug 10.0 9.3 - 9.6 65 - 70 35 - 50 5 - 7 NC 8 -10 8 -10 Yield Pt. (LBS/100 Ft2 2O - 30 8 - 12 Gels (LBS/t00 Ft2 8/12 3/3 9 8 pH . Solids (% by Volume) 17 7 KCL (% by Volume) 3 3 Use primariy a brine water system with the above pills for either kill plug setting or lost returns. Partial returns was a problem during both the workover in 1974 and the recent killing operation to repair the wellhead leaks. Spot lost return pills as required during workover operations. Spot a viscous pill above the cut tubing at 3566' prior to pulling out of the hole with string #1. z :'s~oo p.r× ~ I d'~',~'M'X/ 7' i i U I RECEIVED r:~ ~ 0,2 :[987 Alaska 011 & ~a~ Con~, Commi~ion An~hor~g~ ~ 2820.93* ~Z--~ZS '~' S~ 3.52· ). ~ 8 ~S. 2~' K~ Bid N-90 ~G. st4o'*~ ~ o L ~. ~" E~ 6=d N-gQ ~G. 3%.95e ' 3~54.7~* ~2--B~ ~ PU~ S~ JT. J.S3e ~ 2 ~0 PC? ~. E~ 8zd N-e0 ~G. X0.O4' ' 3~80'3~* ~ -- B~ ~-L7 2C PA~R 7~Me 7.44e 3206.~9" / ~ NOT~: NO. Z STIING OF TUIING PARTED IfLOW SICONO PACKER ANO ~ I -- B~ HI S~ PA~R 7.45o · .38%4 * ~o' ' 1997.37' [ JT. 2~' E[~ 8*d H-80 ~G. 30.47' · ~ ~4o~t'-~e-404~ 52'~ 1 3T. 2~ E~ etd N-80 ~G. 31.73' -- S059 73'~ . L ~. ~" E~ 8~d N-e0 ~. --SOBS 63'~ 2~" P~ ~. ~ etd N-GO ~G J · 3.52' 7.45' X.$8' ~97. ~' , ~0.::'8' l, .40' 2 .$0' 7.05' 30.93' 1.~8' · S 13.20' 29.42' ~,, 40' 3.$2' 7.06' 1.30* 3Q.68' .B&o ~23.g8' : ~1 ,9,1 o: ' '..-',' ,,,*-,,' GA ~l ~/~ ~: ~aso'-~' . '. ~ T.D. SSOI' .. RIVER 241- 54 CASING i TUBING DETAILS SECTION 34,T. I3N. R. IOW. ' SfA~.A~O ~.tL CnvP&~V CF . · I I i · ' i Form' 3160_5 (November 1983) (Formerly 9--331) U N !~-=-9 STATES svB,,zT z~ ~z~W-~.~- (Other instructions DEPARTMEK F THE INTERIOR BUREAU OF LAND ~ANAGE~ENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~se this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) OIL [] CAR WELL WELL OTHER 2. NAME OF OPERATOR Chevron U.S.A. Inc. 3. ADDRESS OF OPERATOR P. O. Box 107839, Anchorage, AK 99510 1. LOCATION OF WELL (Report location clearly and tn accordance with any State requirements.' See also space 17 below.) At surface 899'S & 1399' W of NE Corner Section 34 t·orm approve~. Budget Bureau No. I004-013S Expires August 31, 1985 DESIGNATION AND eBaIAL A-029657 6. IF INDIAN, ALLOTTES OB TItIBE NAME 7. UNIT AGREEMENT · BRU 241-3.4.. ,.~ Beluga River, Beluga and Sterltn~ Il. SEe., T., l., M., bh ILK. l~ 8ec.34, T13N,RgW, SB&M 14. PERMIT NO. j 15. ELEVATIONS (Show whether DF, ItT, GE, etc.) 12. COUNTY OR P~ItlSHJ 13. STATE -- 50-283-20038 J G.L. = 88' K.B. = 110' Kenai BoroughJ Alaska ~:- Check Appropr'ate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO : TEST WATER SHUT-CFr FRACTURE TREAT SHOOT OR ACIDI~E REPAIR WELL PULL 0R ALTER CASINO M U L~'IPLE CO.M PLETE CltANGE PLAN~ RUBRr, QuBNT ltml~)ltT O1: FRACTURI TREATMENT ALTERING CABINQ (0ther) t NoTE: Report results of multiple completion on Well /Other) __ ~----J Completion or Recotnpletion Report and Log form.) v~:,~('~n.~: rnoros£v ca CO.~IPLETEO OP£~Arm.~,': (Clearly state all per~inen[ details, and give pertinent dates, including e~timated date of starting any proposed work. If well is directiona/ly drilled, give subsurface loc~tiuos and meam~red and true vortical depths for all markers and ~ones pertl- nen~ to this work.) * See attached program. We anticipate starting work immediately. RECEIVED FEB 0 2 198]' Alaska Oil & Gas Cons. Commission 18. I hereby cert is true and correct Acting Area TITLE Operations Superintendent (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL. IF ANY: TITLE DATE *See Instructions on Reverse Side TLtle 18 U.S.C. Section !001, makes it a crime for any person knowingly and willfully to make to any department ur agency of the United State.~ any false, fictitious or fraudulent statements or representations as to ~n¥ matter wtthin its jurisdiction. Form .,(Nox. e.~b er 1983) '" (Formerly 9-331) UNIT/~D STATES S~BMIT m DEPARTMEN/~!F THE INTERIOR.. -er.(Otherside) BUREAU Oi .~hlD MANAGEMF:NT SUNDRY NOTICES AND REPORTS ON WELLS ldo not use this form For proposals to drill or to deepen or plug back to a diS, rent.reservoir. Us~ "APPLICATION FOR PERMIT--" for such proposes.) 1. WEhL WELL OTHER 2. NAM~ Or OPERATOB Chevron U.S.A. Inc. 3. ADDRESS O~ OPRRATOB P.O. Box.107839, Anchorage, AK 99510 __ t. ;.OCATWN OF XVgCL (Report location clearly and tn accordance with a~-~tate, requirements.* See also space 17 below.) At surface 899's & 139' W of NE Corner Sec. 34, T13N, RI0!, SB&M lt. PERMIT NO. AP1 50-283-20038 15. g~ZVATtONS (Show whether DF, ~'r, o~, etc.) G.L. = 88' K.B. = 110' 5. LBAli DRmlONATION AND IRItIAL A-029657 ~. IF [MOl&W, ALLO?TBB OB TRill NAME Beluga River Unit 8. B'AIM ~B, LRAaR NAMe 9. WILL MO. BRU 241-34 10. ~IBLD AND POOL, OR WILDCAT Beluaa River, Sterling &_Belug~ 11, IBe.,~., I., If., OU BLt. AL'~D IUIVBY OB ARJIA Sec. 34, T13N, R10W, SB&M 12. ~OON~Y oB P~USeHI 13. BTATR Kenai Borough[' Alaska Ch~k Approprmate Box To Indictor Nature of Notice, Report, or Other Da~ NOTICR OF INTENTION TO: FRACTURE TREAT M U LTIPI, E CUM Pr.gTE SHOOT OR ACIDIZm ABANDON* REPAIR WELL CHANGE PLAN8 eVBIIQUBNT Illl~Ol~ O1': WATBa SHUT.r# ~ BBPAmmO WBLL FBACTt'RB TBIATMgNT ALTERING CARING SHOOTING OR ACIDIZI~G ABAN~NMINT* (Other) ~NOTR: Report results of multiple eompletlon on W~ll (Othor)__ Completion or .R. ocompletion Re~ort and tog form.) .- f~. DKS('B. Iili'; I'[t,H'O.'iED OR COSIPLETED OPERATIO%.~: (Clearly state ail p~'rtinPnt details, and give pertiuent dates, tncludlnw ~mttmated date of it~l'l~lng any proposed work. If well is directionally drilled, give subsurface loc~tiuns and measured and true v,,rtical depths for all markers and ~onem lmrti- nenc to this work.) * See attached. 18. I hereby certify ~he f~rue and correct 8IGHED/~'/~~. gl- RECEIVEO FE9 0 2 1987 A!~,'~ ~;! .g ~a~ Cons. Commission ,'..-: ~.!{?-~a.9 Acting Area TITLE ,',, ..... ~----' Supcrlntandent DATl~ (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, LF AHY: TITLE DATE *.~e Instructions on Reve~ Side Title 18 U'.S.C. Section !00l, makes it a crime for any person knowingly and willfully to make to any department ur agency of the United States arxy false, fictitxous or fraudulent statements or representations as to any matter within its jurisdiction. CHEVRON U.S.A. INC. WESTERN REGION ALASKA AREA WELLW~ PROCEDURE SUMMARY TYPE WELL' ~-~: TYPE,lOB' ORIGINAL SUMMARY E] SUPPLEMENTAL SUMMARY ~ NO. ,, ,/ PERFORATIONS · NOTES' I, T¢'P ~ DETAILS ATT~-CHED ~ v%<-pF Distribution: ' WELL' CONTINUED): CHEVRON U.S.A. INC. WESTERN REGION ALASKA AREA WELLWgt~ PRgC'EDURE ~UMM~RY or Distribution: RECEIVED: o,,~. s,,,,,',,,,,,,,,,, ~,,~,. <~, FEB 0 2 1981 Field Off,ce ,,,,,,,,,r <,~ Alaska Oil & G~ Cons. Commission [,,~r. Tlch,,i¢iefl {I ) ,~ Anchorage ~proved by Dote / _ _/ =-:- I 1 ~,~,~e~- .o~-~,~. 'ri- . ._ ~-y~' ~~ : . . . - # 5/$7'. , ' _ · 7~ ~ ~_.c,¥ - /~ STATE OF ALASKA ,~'-. ALASKA ~_ AND GAS CONSERVATION C( !ISSION ' ' 'Wt LL OOMPLETION OR RECOMPLETION REPORT AND LOG wr--kk ¥¥111r'kk · IVI! Vii lllVVlll- a--i · ·,~,-. --~- ~ .... -1. Status of Well r .. Classification of Service Well ,~ QIL [] GAS [~ SUSPENDED [] ABANDONED [] S'ERVICE [] 2. Name of Operator 7. Permit Number - Chevron U.S.A. Inc. 72-0016 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 5°-283-20038 4. Location of well at surface 9. Unit or Lease Name 899' S & 1399' W of NE Corner, Sec. 34, T13N, R10W, SB&M Beluga River Unit At Top Producing Interval 10. Well Number Same BRU 241-34 At Total Depth 11. Field and Pool same Beluga River, Beluga 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. G.L.=88' K.B.=I 0' .A-029657 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 6/17/72 7/14/72 9/25/86 NA feet MSLI 2 17. Total Depth {MD+TVD) 18. Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6501'; 6501' 5477'; 5477' YES [] NO [] NA feet MDI NA 22. Type Electric or Other Logs Run CNL/CET/CSG INSP LOG 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOUESIZE CEMENTING RECORD AMOUNT PULLED 30" -. " 28' 44' ·" Driveni ,.20" 94#.:' H-40' 24' 405' 26" 800 Sks "13 3/8" 68# ..... ~ K_-55 ' ~.24'-' 2380..'~- 17 1/2" 1060 Sks · 9 5/8" 43.5#IN-o6,b-i1522 ~'8'9' 12 1/4" 1060 Sks · topgO'is 103/4 51#P-1 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) ............ 2-7/8" 5429' 3583. 4011. 2 3/8" 1830' See Attached ~,6. "· '''~' ACID, FRACTURE, CEMENT SQUEEZE, ETC. · DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. See Attached ' . ... , PRODU~TiO.N TEST ~ Method of Operation (Flowing, gas lift, etc.) Date Fir,s,t,:Production. WSI PNDG : F1 ing ' -· ": · Installation SFC FACIL: ow' ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GASZMCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD II~[ . "GAS:MC'F WATER-BBL OIL GRAVITY-APl (c'o'r'r) Flow Tubing ' ' Casing Pressure CALCULATED [l~ OIL-BBL Press. 24-HOUR RATE .'.' 28. NA-' .. . CORE DATA ., Brief description of lithology, porosity, 'fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. t?' , -: -.. ' .i;~ . - "" ' ":-'" ?' :':"" FORMATION TESTS NA GEOLOGIC; MARKERS NA NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge zP.~m~--~ Acting Area Operations Signed Title Superintendent Date/~')/"'~;~.- --'~'~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ".i'?- , ~ ~'", STATE OF ALASKA ~--~,~ ~ ALASKa. ~.,~ ANDGAS CONSERVATION C ..~llSSION ~,~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG · .. 1 Status of Well ' Classification of Service Well · : OIL [] GAS [~ SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number Chevron U.S.A. Inc. 72-0016 3. Address 8. APl Number P.O. Box 107839, Anchorage, AK 99510 50- 283-200:~8 4". Location of well at surface 9. Unit or Lease Name 899' S & 1399' W of NE Corner Sec. 34, TlJN, R10W, SB&M Beluga River Unit At Top Producing Interval 10. Well Number Same BRU 241-34 At Total Depth 11. Field and Pool Same Beluga River, Beluga and 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Sterling G.L.-88" K.B.=110'[ A-029657 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Sdsp. orAband. 115. Water Depth, ifoffshore 116. No. of Completions , 6/17/72 7/14/72 9/25/86 NA feet MSL 2 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6501'; 6501' 5477'; 5477' YES[] NO [] NA feet MD[ NA 22. Type Electric or Other Logs Run CNL/CET/CSG INSP LOG 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,. 30" 28' 44' Driven 20" 94# H-'40 24' 405' 26" 800 Sks 13 3/8' 68# K-55 2'4' ~2380'i 17.1/2" 1705 Sks * 9 5/8' 43.5# N-80,P-113 22' 6389' 12 1/4" 1060 Sks *Top 9C is 10 3/4' 51# P-11) 24. Perforations open to Production (MD+~VD of Top and Bottom and 25. TUBING RECORD · · .~inter. val, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2 7/8" 3583' 2997' See Attached : ,~. -2 3/,8" 1830' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ~ , i,~ ~, ,.~ .,.: . ~ , ,~ " . ~ ' : ': .-,. ~ :. . · t '- .~ . ,,, 27. PRODUCTION ~EST ..... Date ?:i, rs;t.!P, ro.duction ~S.I .Pndg. I Method o..f. Operation (F. Iowing, gas lift, etc.) . Installati0n 'Sfc. Facil. ....i FloWing Date of Test Hours TeSted PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO I 9725/'86 :' 6 TEST· PERIOD ~[~ 0 980 0 28/64 NA Flow :T, ubing .. Cas. in.g Pressure CALCULATED I~ .OI.LzBBL GA~-MCF, WATER-BBL OIL GRAVITY-APl (corr) Press..l~15 ' 0 24-HOUR RATE -~ 0 ' 5340 0' NA ' ' ' '' '' ;' '~ ~ : ~ ' i;' '-' ' ' ' 28. cDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :29. ~:' ~" ">' }:' .... 30.~ '::';." ~"~?': .... '" NA GEOLOGIC MARKERS NA FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Acting Area Operations Signed .... Title ,%per,_'ntendent Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage 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". PERFORATION RECORD 5375' - 5345' 30' 120 5331' - 5326 5' 20 5271' - 5255' 16' 64 5233' - 5213' 10' 40 5201' - 5186' 15' 60 5161' - 5137' 24' 96 5048' - 5032' 16' 64 5024'- 5016' 8' 32 4972' - 4968' 4' 16 4911' - 4907' 4' 16 4878' - 4875' 3' 12 4858' - 4856' 2' 8 4835' - 4831' 4' 16 4784' - 4780' 4' 16 4770' - 4766' 4' 16 4757' - 4732' 25' 100 4503' - 4499' 4' 16 4489' - 4464' 25' 100 4398' - 4394' 4' 16 4386' - 4382' 4' 16 4358' - 4337' 21' 84 4276' - 4259' 17' 68 4222' - 4215' 7' 28 4186' - 4184' 2' 8 4138' - 4072' 66' 264 3968' - 3963' 5' 20 3943' - 3939' 4' 16 3900' - 3896' 4' 16 .3870' - 3866' 4' 16 3836' - 3818' 18' 72 3804' - 3797' 7' 28 3738' - 3718' 20' 80 3693' - 3681' 12' 48 3663' - 3657' 6' 24 3643' - 3623' 20' 80 3617' - 3614' 3' 12 Intervals from 5375'- 4732' reperforated with originally perforated with 4 ~}" JSPF. 4 ~" JSPF. Ail other intervals PRODUC~ON Inerval Date of Test Hours Tested Choke Size Flowing TBG. Press. Csg. Press. 5375'-5137' 9/23/86 30.5 20/64" · 1280 0 Production For Test Period Oil - BBLS Gas - MCF Water - BBLS Gas/Oil Ratio 0 1883 0 Calculated 24 Hour Rate Oil - BBLS Gas- McF Water - BBLS Oil Gravity 0 2553 0 NA 5048'-4732' 9/24/86 8 23/64" 1200 0 0 555 0 -NA 0 2551 0 NA 4503'-4072' 9/24/86 10 28/64" 1320 0 0 1274 0 NA 0 4428 0 NA 3943'-3614' 9/25/86 19 28/64" 1275 0 0 2597 0 NA 0 4330 0 NA PERFORATION RECORD 3545' 3522' 3503' 3462' 3425' 3411' 3392' 3340' 3318' 3283' 3167' 3131' 3111' 3096' - 3537' - 3518' - 3493' - 3450' - 3416' - 3405' - 3362' - 3334' - 3312' - 3244' - 3148' - 3126' - 3101' - 3066' 8! 4' 10' 12' 9' 6' 30' 6' 6' 39' 19' 5' 10' 30' Above intervals originally perforated with 4 ~" JSPF. 64 32 80 96 72 48 240 48 48 312 152 40 80 240 .50" .50" .50" .50" .50" .50" .50" .50" .50" .50" .50" .50" .50" .50" , ~':, , STATE OF ALASKA AL~$KA OIL AND GAS CONSERVATION CO,..MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations perfOrmed: Operation shutdown [] Alter Casing iX Other [] 2. Name of Operator Chevron U.S.A. Znc. Stimulate [] Plugging [] Perforate ~q Pull tubing X~ 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of well at surface 899' S & 1399' W of NE Cor. Sec. 34, t-3N, 10W, SB&M At top of productive interval Same At effective depth Same At total depth Same 6501 feet 6501 feet Plugs (measured) 5, Datum elevation (DF or KB) K.B.=ll0 6. Unit or Property name Beluga River Unit 7. Well number BRU 241-34 8. Approval number 9. APl number 50-- 283-20038 10. Pool Beluga and Sterling Feet 11. Present well condition summary Total depth: measured true vertical Effective depth:' measured 5477 feet Junk (measured,) true vertical 5477 feet Casing . Length Size Cemented Structural Conductor 16' 30" Driven Surface 381 ' 20" 800 Sks 2356' 13 3/8" 1705 Sks Intermediate Production 6367' *9 5/8." 1060 Sks ~0~K *Top 90' is 10 3/4" Csg. See Attached Perforation depth: measured Measured depth 44' 405' 238O' 6389' ~ue Verticaldepth 44' 405' 238O' 6389' true vertical Tubing (size, grade and measUred depth) 2 7/8" 6.5# N-80 3583' & 5429' 2 3/8" 4.6# N-80 1830' Packers and SSSV (type and measured depth) Brown: HS-17-2c 3997'; HB-1 4011', 4685', 5101' 12. Stimulation or cement squeeze summary HA Intervals treated (measured) Treatment descriPtion including volumes used and final pressure i3. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I herebY certify that the foregoing is true and correct to the best of my knowledge Signed ~ Title Acting Area Operations SuperintendentOate~-~g' Form 10-404 hevl 1~)-1-815 Submit in Duplicate PERFORATION RECORD 5375' - 5345' 30' 120 5331' - 5326 5' 20 5271' - 5255' 16' 64 5233' - 5213' 10' 40 5201'- 5186' 15' 60 5161' - 5137' 24' 96 5048' - 5032' 16' 64 5024' - 5016' 8' 32 4972' - 4968' 4' 16 4911' - 4907' 4' 16 4878' - 4875' 3' 12 4858' - 4856' 2' 8 4835' - 4831' 4' 16 4784' - 4780' 4' 16 4770' - 4766' 4' 16 4757' - 4732' 25' 100 4503' - 4499' 4' 16 4489'- 4464' 25' 100 4398' - 4394' 4' 16 4386' - 4382' 4' 16 4358' - 4337' 21' 84 4276' - 4259' 17' 68 4222' - 4215' 7' 28 4186' - 4184' 2' 8 4138' - 4072' 66' 264 3968' - 3963' 5' 20 3943' - 3939' 4' 16 3900' - 3896' 4' 16 3870' - 3866' 4' 16 3836'- 3818' 18' 72 3804' - 3797' 7' 28 3738' - 3718' 20' 80 3693' - 3681' 12' 48 3663' - 3657' 6' 24 3643' - 3623' 20' 80 3617' - 3614' 3' 12 Intervals from 5375'- 4732' reperforated with originally perforated with 4 -}" JSPF. 4 ~" JSPF. Ail other intervals PERFORATION RECORD 3545' - 3537' 8' 64 .50" 3522' - 3518' 4' 32 .50" 3503' - 3493' 10' 80 .50" 3462'- 3450' 12' 96 .50" 3425' - 3416' 9' 72 .50" 3411' - 3405' 6' 48 .50" 3392'- 3362' 30' 240 .50" 3340' - 3334' 6' 48 .50" 3318' - 3312' 6' 48 .50" 3283' - 3244' 39' 312 .50" 3167' - 3148' 19' 152 .50" 3131' - 3126' 5' 40 .50" 3111'- 3101' 10' 80 .50" 3096' - 3066' 30' 240 .50" Above intervals originally perforated with 4 3" JSPF. cc..o,.. Drilling Morning Report - Region Division Company ~UR~NI,l..rA ~ESF~ ALASKA . I~"'~°~" __ ~-~r- 7~ t o, / Depth ~/ .MD TVD ( XY77 PBTD) Proposed TO MD TVD '~ IDFS Hfs lotal Rot. Hrs. Last Casing Size ~ Set ~ ~ MD ~ ~ /IX' TVD EMW ~ Cum Rot. Hrs.: IDepth Worst Wear % Rem '~ 'On Casing ~Since Last Cal. Liner Set ~ MD TVD - TOP ~ MD TVD ~t. CO Type lEV PV YP ~ Pm Pf/Mf CL CA Ex Lime El Stab Wt. Material Gel ]Caustic Lig. Cls. Salt CaCI~ Other ~ Avg: Drilling Max. Drilling Conn. Tr,p ]Trip Chlorides [Remarks M D Angle Direction TVD Coordinates. . ~ . ~;~'~ VS DLS No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B G lotal length {H.~.~.p.: } Consists of Pump Liner Stroke SPM 'Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covarin~ 24 Hours [ndin~ ~ Midnight . GO. 1211 (eli 3-1151 Pr~med ~n USA. 'cc..o,.. Drilling Morning Report ,. Depth ~ ~[ MD '. TVD ( ~77 PBTD) ]Proposed TO MD TVD ~ IOFS , ~TotalRot. Hrs. ~ DOL 36Day, Hrs. 27 Days /¢ rs '~ .. · 'Torque , )Drag IRot. Wt. ]P/U Wt. ISlack O, Wt. 0 ~ Shoe Test Las, CasingSize ~ SetO ~ MO /0 2/r ~ (/Z' Tva EMW ~ On Casing ISince Last Cal. Liner Set 0 MD TVD- TOP 0 MD TVD ... ~ ~m ~[/M[ C[ ~ Ix Ume [I Stab Wt. Material Gel Caustic. lig. Cls. Sah CaCl~ ~Other ' ' M ~ ~n~le ~ir~ction IVD Coordinams V S ,, . ~ ,, , ~a. Siza lyre 8~r. ~o. '3ets In Out [eet' Hrs. ~OB fl~M I g G , Cum~ liner Stroke S~M ~ressur~ GPM Oet Vel. ~nn. Vel. 8it Hrs. O~erations ~o~erin~ 24 Hours [ndin~ ~ Midnight ,,. .. ,., ', ~~ D"i'Y Mud0 ICum ~u" Vii e~3 . IOoi,y T~ngib,e JCum Tangible JDaily Well ~Ole3Z G0-t211 [C0-3-851 Pr,nled in U.S.A. c,..o,.. Drilling Morning Report Company CI.IFU I~OI~ b~ (,J~$T~f(N AL A S ~A ~'"g~ w~_,, 8g~ ~1-3~ ~.0. oo~ W~-~rC?o 1['~'~ ~g~A ~la~ [D~,~ q. ~_~ /. o~ Proposed TD Depth ~ ~'( MD TVD ( ~t'77 PBTD) MD TVD ~ DOL ID FS ITo,fii Rot. Hrs. '~ 27 Days Hrs. 2~ Days/~Hrs. Shoe last Las, CasingSize ~ Se,~ ~*m~D '0~ S"~ ''~7 lV~ EMW ~ Cum Rot. Hrs.: ' Wear ._ ~Depth Worst % ~em, ~ ,.9.~ Casing lsince Last cai. Liner Set 0 MD TVD -TOP ~ MD TVD ~ Pm Pf/Mf CL CA Ex Lime El Stab Wt. Material Gel ~Caustic LiD. Cls. Salt ~aCl~ Other M D Angle Direction TVD Coordinates V S DLS . No. Size Type Set. No. Jets In Out Feet Hrs. WOB RPM T B G -- , Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight ~1 5~r Rl~t~ p~. L/~ ~Z~Y ~.o ~I~fl~AL~. p~c KoZy ~~-~~ .... . .* Daily Mud V~OIc"m ~"" ~, ~,~~,,,, Tangible tC,m Tangible Well JZ g~7 Cum Well GO-1211 (CD.3-85l Pnnted in U.S.A. cc..o,.. Drilling Morning Report Company CH~'O i~ ~ ~-$A ~'~" rE'~'~i/ Region ~Divisio, A ~ ~ ~ ['Ch. Code ~~ ~'~ JDate ~ ~- ~ ~Page Depth ~ MD TVD ( ~Y~7 PBTD) ~Proposed TO MD TVD ~ DOL 2F Days Hrs. 2.~Oays /~ . Last Casing Size e~ S,,, ~~ MF/~u ~,,~ ~,,~'2 TVO ]Shoe Test ~ On Casing ~Since Last Cal. ~ ,.. Liner Set ~ MD TVD- TOP ~ .MD TVD ~t, ~CO · [FV [PV ~YP Gel ~WL ~HT-HP IFC ISolids ]% Oil l% Sand IMBT [PH .~ Pm Pf/Mf CL CA Ex Lime El Stab m / ~t. Material Gel ~Causfic.. Lis., ~ Cls. Sak CaCl~ Other - ~ Avg. Drilling Max. Drilling ]Conn. ITri, ]Trip Chlorides Remarks ' M D Angle Direction TVD Coordinates V S D L'S ,. i NO. Si.ze Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B 6 Total Length (H.W.D.p.: ) Consists of / Pump. Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bk HHP Pump HHP Hrs. O~erations Co~erin~ 24 Hours [ndin~ ~ Midnight ,,, G0-1211 lC0-3-851 Printed ,n U.S.A. CC-.or.. Drilling, Morning Report Depth ~ ~0/ MD TVD ( ~'~7 PBTD) Proposed TD MD TVD DOL ~ ~ Days Hrs. ~ Y Days 1 ~ Hrs. Last Casing Size ) Ish°e lest g ~ s.to ~¢~ MO (~0%" ~.~ ~ ~' TVO [MW .~ Cum Rot. Hrs.: IDepth Worst Wear % Rem ~ ~n Casing ISince Last Cal. / ,., Liner Set $ MD TVD- TOP ~ MD TVD ,., Wt. CO FV PV YP ~ Pm Pr/Mr CL CA Ex Lime El Stab ~ / · hr. Material Gel Caustic Lig. Cls. Salt CaCI~ ., Other M D Angle Direction TVD Coordinates V S DLS ,. , No. Size Type SeT. No. Jets In Out Feet Hrs, WOB RPM I B O Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jm Vel. Ann. Vel. Bit HHP Pump HHP Hrs, Operations Covering 24 Hours Ending ~ Midnight , ~ Daily Mud VO0 JCum Mud ~ J' J rJ JDaily Tangible JC.m T..¢,. lOa,,, Well ~e~rz Cum Well '7~ *~3 , 60-1211 {CD-3-851 Pnmed in U.S.A. ~c..o,.. Drilling Morning Report ....~~mN ~ I~"'~°~'I~'~'~ I Proposed TD Depth ~ ~ / MD TVD ( ~ 77 PBTD) MD TVD · ~ ~ Days Hrs. ~ Days ~ Torque io,~o., t~o,.w,. ]PlU wi. JSlack Of Wt. ~ On Casing JSince Last Cal. ~ Liner Set ~ MD TVD-TOP ~ MD TVD ~ Pm Pr/Mr CE CA Ex lime El Stab ~ I Wt. Material Gel JCaustic Lig. CIs. Salt CaCl~ Or'her "' M O Angle Direction TVO Coordinates V S g L~ ..... ,.. ,. No. Size Type Ser. No. Jets in Out Feet Hrs. WOB RPM T B G I Total Length (H.W.D.P.: ) Consists of ~ '' ~ ,,, Pump Liner Stroke SPM - Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP ~ , ?s. Operations Covering 24 Hours Ending ~ Midnight ~ co~p~ ~c~A~-~ ~ ~ ~1~-t37'- ~7~'), FINAL ,, ., OaiiyMud ~00 JCumMud ~O,V'~ JOailyTangible JCumTangible GO 1211 (C0-3-85) Printed in U.S.A. CC.Morn. Drilling Morning Report IRegion Division Company ~,j,~,O/~01,~ ~J,$/~ ~'~' ~~ ~L~ ~ ~ Proposed TD Depth ~ MD TVD ( ~~ PBTD) MD TVD ~ DOL 2g Days Hrs. ~ Days /g Hrs. ' ) Last Casing Size ~ Set 0 ~~ MD t ~F ~//2' TVD EMW ~ Cum Rot. Hrs.: ~Depth Worst Wear % Rem '~ On Casing JSince Last Cal. Liner 8~t ~ MD TVD- TOP ~ M~ TVD Gel lWL ~HT-HP FC. Solids %0il %Sand ~MBT PH . ~ Pm Pf/Mf CL CA Ex brae El Stab ~ ./' Wt. Material 6el Caustic. LiD. CIs. Salt CaCI~ Other ~ ~vg. Drilling Max. Drilling Conn. Trip ITrip Chlorides Remarks M D Angle Direction TVO Coordinates V S OLS No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM I B O Total Length (H.W.D.P.: ) Consists of Pump Liner Slroke . SPM Pressure GPM OerVel. Ann. Vel. Bil HHP Pump HHP ' Hrs. Operations Covering 24 Hours Ending ~ Midnight o too $ Yo ~ ~o ~ 7 2 ~ . 11~ !19~ ~o ~Z~ 23V3 /oo/~ Drilling Rep. [Accidents 00.1211 iCD.3-851 Pnnled ~n U.S.A. Drilling Morning Report Company IRegion ]Division ~N~o~o~ ~ ich. Code ' - J Propased TD Depth ~ ~Oj MO TVD ( ~TT PBTDI ~D TVD .~ gOL " ' '~ 2 ~Days Hrs. 2 ( Days /~Hrs. To,al Rot. Hrs. , , , ,, L~s,c,~ngS~,, ?~¢ S.tO ~ ~"(lO~/~'' ~"~ ~ n~' TW E~W ~ On ~asing JSince Last C~I. Liner Set ~ MD TVD- TOP ~ MD TVD Gel JWL IHT-HP . IFC JSolids ,, %0i, J% Sand ]MBT J PH ~ Pm Pf/Mf CL CA Ex Lime Ei Stab m i , Wt: Material Gel JCs,sd~ Lig. '" Cis. Salt &aCl~ Other M D Angle Direction TVO Coordinates V S DLS No. Size Type Ser. No. Jets In Ou~ Feel Hrs. WOB RPM T B G ~ , , , ..... Total Length (H.W.D.P.: ) C~nsists of Pump Liner Stroke SPM Pressure OPM Jet Vel. Ann. Vel. Bit HHP Pump HHP , . Hrs. O~orations Coverin~ 24 Hours [ndin~ ~ Midnight ~ p~ ~ ~/0 ~o~. , Oaily Mud 0F Mud 3%¢X3J'"'tTangible ~Cum Tangible ¢ IOaily Well _ __ ICum Well . GO 1211 ICD-3-B5J Primed in g S.A. CC-Morn. Drilling Morning Report Company RegionI°i~°~ A~ A ~K~- ~" ~u lw-x~ ~.o. I~"'~°~ ~r~ ~r~7~ I~'~ e~a~ <t~' ~'~,-~-g~ I~' Io, I Proposed TD Depth ~f MO TVD ( ~777 PBTD} MO TVO ~ DOL i Y Days Hrs. ~6 Days /g Hrs. · c- DFS ITotal Rot. Hrs. ~ Torque )Drag "]Rot. WL P/UWt. Slack Off Wt. Last Casing Size ?~ Set * : ~ ~ M" //~". ,~ ~ ,, Z') TVD Shoe Test EMW .~ Cum Rot. Hrs.: ~;pth Worst wear~ % Rem. ~ On Casing ~Since Lam Cal. Liner Gel IW.L HT-HP FC mSolids %0il %Sand MBT ]PH ~ Pm Pf/Mf CL CA Ex Lime El Stab Wt. Material Gel iCaustic Lig. CIs. Salt CaCI2 )ther Avg. Drilling Max. Drilling ~Conn. Trip Trip Chlorides Remarks M O Angle Direction TVD- ' Coordinates V S DLS No. Size Type Ser. No. Jets In Out Feet Hrs. . WOB RPM T B G total Le'ngth (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. O~eratioas Coveria~ 24 Hours [ndin~ ~ Midni~h~ ,. ~ Daily Mud/~ *~ JCum Mud ~.%S*3 Daily Tangible Cum TangiUe toaim, w,,, ~i v~s m°urn we,, v~/, v,J 60-1211 (CD-3.851 Printed ,n U.S.A. cc:.o,.. Drillinq Morninq Report Region IDivision Depth .. MD TVD ( PBTD) ~Proposed TD MD TVD ~ , · ~ Days Hrs. Days Hrs. ,, ,,~ i[ast ~asin~ Size lShoe lest Set ~ MD TVD EMW .~ Cum RoL Hrs.: Depth Worsl Wear ~% Rem ~ On Casing J~ince Last Cal. Liner Set ~ MD TVD- TOP ~ MD TVD ,,, , ,, ~ Pm Pf/Mf CL CA ~x brae El Stab ' ~t. Material " ~1 ~austic " [i~. CIs. Salt ~aCl~' ~ther M D Angle Direction -TVD Coordinates V S O L S ,, g . No. Size Type Set. No. Jets In Out Feet Hrs. WOB RPM I B G 'Total Length (H.W.D.P.: ) Consists of ' ' I ~Pump ' i Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel, Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight AFn~ ~m~s: G0-1211 IC0-3-85t Pnnted in U.S.A. cc..o,.. Drilling Morning Report JRegio~ Division Depth 6~D[ MD TVD ( ~777 PBTD) [Proposed TO MD TVD ~ IDOL DFS ~To~al Rot, Hrs. '~ ' Ag Days Hrs. /? Days /~Hrs. Las. CasingSize q ~ Set. ~~ MO 0~/~''' ~.g~ ~/~' TVD ]Shoe Test EMW .~ Cum Rot. Hrs.: ]Depth Worst Wear % Rem = On Casing JSince Last Cal. Liner Set ~ MD TVD- TOP ~ MD TVD ~ Pm Pr/Mr CL CA E'x Lime El Stab m / Wt. Material Gel ~Caustic Lig. CIs. Salt CaCl~ Other M D Angle Direction TVD Coordinates V S DLS _ ,,, No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B G Total Length (H.W.D.P.: ) Consists of ,, Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight ~. ' ~ DailyMud 0 }Cum Mud ~ ~a3 Daily Tangible, Cum Tangible Daily Wel.~, Drill H,O IPot H,O ]Fuel ]Bulk Wt. [Bulk CmL ].Total Appr. ~ ~ Accidents CC.Morn. Drilling Morning Report IProposed TD Depth ~ ~/ MD TVD ( ~ Y 7 7 PBTD} MD TVD '~ On Casing ]Since Last Cal. Liner Set ~ MD TVD- TOP ~ MD TVD ~ Pm Pf/Mf / CL I~'/ ~ CA Ex Lime El Stab Wt. Material Gel ICaustic Lig. CIs. ~alt CaCl~ . Other M ~ ~n~le ~iroction 1~ ~oorOinams V S ... ... ~o. Size l~e Set. ~o. Jets In Out loIal length {~.~.~.p.: } Consists o[ ~um~ liner Stroke S~M ~ressure ~M ~et Vel. ,,,, Hrs. Opmations ~o~erin~ 24 Haurs [nOin~ ~ Midnight 2 RI& C.A. wa/~ ~t/cgz/~e~ R~ ~/$~/Fr/~ ,,, ~ '' . . Accidents Printed ,n U.S.A. cc.,.,.. ' Drilling Morning Report Region IDivision I Proposed ID Depth g~D / MD TVD ( ~72 PBTD) MD TVD DOL DFS ITotal Rot. Hrs.' 21 Days Hrs. /7 Days /~ Hrs. Torque ~Drag ~Rot. Wt. P/U Wt. Slack Off Wt. Last Casing Size ~ Set 0 g ~4 MD Xur~ ~//~' TVD EMW Cum Rot. Hrs.: ]Demh Worst Wear % Rem On Casing ]Since last Cal.' liner Pm Pr/mr / CL l~q ~ CA Ex Lime El S,ab Wt. Material Gel Caustic Lig. CIs. Salt CaCl~ Other M ~ ~n~lo Birection IV~ ~oo[dinates V S No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B G Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnigh~ B~bCN OqAL ~406L yJ-1?-2c P~p ~ 3001', 8flOwN H~-I p~O's ~rls a.~/3" f~/~.~os' no-~o) ~ ~Sr~'. 'aeo~ .r~6~ sa~ (vS~ OTIS 2.31Y" (~/~.2~r" N~-(o) ~ JS[/',' MuLg S~D ~G TAIL _ i go. ~ 0~' 8/0 __ I Drillin~ 8ep. 60-1211 IC0-3-851 Printed ~n U.S.A. cc..o,.. Drilling Morning Report Proposed TD Depth g ~0 / MD TVD ( ~ ? 7 7 PBTD) MD TVD DOL DFS 2D Days Hrs., /~, Days /g Hrs."t°ta' RoL Hrs. TVO EMW · ~ ~um ~ot. Hrs.: l~e~th Worst ~ear ~°/o ~em. On ~asin~ ISinc~ last Liner 8~t ~ MD TVD- TOP ~ MD TVD Pm Pf/Mf CL CA Ex Lime El Stab Wi'. Material Gel {Caustic Lig. CIs.' 3alt CaCl~ ~ Avg. Drilling Max. Drilling {Conn. .Trip Trip Chlorides ]Remarks M D AnCe Direction TVD Coordinates V S DLS ., , .., No. Size Type Set. No. Jets In Out Feet Hrs. WOB RPM T B G Total Length (H.W.D.P.: ) Consists of ' Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. O~erations ~ouerin~ 24 Hours [ndin~ ~ MiOni~ht .... 3 R/~ .~~R~d~D ~J +~Y~gO~~~/~ LAY ~aTA~OITI P~E~. ~ guu ,,. . DailyMud ~*Z ]CumMud ~{ r*3 IDaily Tangible ICum Tangible ~Dail, Well ~*,~V* {Pot',O {,u,, y w,. I"u,*. om,. ... I . GRACE ~/~g IRigPh°"~07) 7~g-&73~ {OrillingRep. ~.Z. UI /COX [Accidents Pnnted in U.S.A. cc..o,.. ' ~ Drilling Morning Report ' IProposedTD Depth ~ ~0 [ MD TVD ( ~ ~7 7 PBTD) MD TVD .~ DOL ~DFS Hrs Total Rot. Hrs. ~ fl ? Days Hrs. /~ Days /8 · Last Casino Size ~A/~' Sets 6~00¢ MD /~/~ "~.r~ /t~/TVD ]ShoeTest EMW ~ On Casin~ ISince last Cal. Uner Set~ MD TVD- TOP $ MD TVD 1 · ~ ~m Pf/Mf / CL /~ ~ ~' CA Ex Lime El Stab Wt. Material Gel Caustic Li9. CIs. Salt CaCb Other ~ Avg. Drilling Max. Drilling [Conn. ]Trip JIrip Chlorides }Remarks ' M D Angle Direction TVD Coordinates V S OLS , , No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B G Total Length ~ (H.W.D.P.: ) Consis[s of ........ Pump Liner Stroke SPM Pressure OPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. O~erations Couerin~ 24 Hours [ndin~ ~ Midnight . ~ DailyMud ICumMud 2~;J / ] Daily Tangible tCumTangible IDailyW;~r//~ Drill H,O IPo, H,O iFuel IBulk Wt. }Bulk Cmt. !'°'''~"~' G0-1211 ICD-3-8§1 Printed in U.S.A. Drilling Morning Report I;I;-Morn. - - Depth ~ ~0 / MD TVD ( ~ ~ ~7 PBTD) MD TVD DFS Total Rm. Hrs. DOL /~ Hrs. . / ~ Days Hrs. / ~ Days Torque JO[Sg ~RoL Wt. P/U WL SJsck Off Las[ Casing Size P~/~ 'I Set~ ~~' MO /~'~/~ ~r~ ~ /~ tTVO Shoe Tes~ EMW Cum Rm. Hrs.: Depth Wors[ Wear J% Rem On Casing JSince Las~ Cal. Liner Set ~ ~ MD TVD- TOP ~ MD TVD Gel WL IHT.HP IFC Solids %0il I% Sand JMBT ~m - Pr/Mr CL /~0 CA Ex Lime El S~ab ~. Material Gel .jcs,s i LiD. CIs. Sal~ CaCb O~her ~ Avg. Drilling Max. Drilling icon,. JTrip Trip Chlorides M D Angle Direction TVD Coordinates V S 0 LS . No. Size Type Ser. No. Jms In Ou~ Fee~ Hrs. WOB RPM T B G Tmal Length (H.W.D.P.:' ) Consists of Pump ' Liner SJroke SPM Pressure GPM Jet Vel. Ann[ Vel. Bi~ HHP Pump HHP Hfs. Operations Covering 24 Hou[s Ending ~ Midnigh~ PoH. _ Accidems Printed m U.S.A. cc...,.,,,. Drilling Morning Report Depth ~0 [ r MD TVD ( ,~"~'~7 ' PBTD) MD TVD DFS ITotal Rot. Hrs, .=-=' DOL ~/3 Days /8 Hrs. '~ / 7 Days Hrs. = Torque IOrag IROt.wt' , P/UWt. Slack Off Wt. Last Casing Size ¢ ~/$" Sets ~ ¢00 ' MD /OJ/~'' , ]Shoe Test ~ar~ ~.//~ TVD EMW ~ Cum ~ot. Hrs.: ~Bepth Worst Wear 1% flem. '~ On Casing ISince Last Cal. Liner Set ~ MD TVD- TOP $ MD TVD Wt. ~. ~ ~ CO ~~ ]Type ~~ 6~;~ FV PV YP ~ Pm Pf/Mf CL /~O~ CA Ex Lime El Stab Wt. Material ~al Caustic. [i~. CIs. Salt Other M ~' ~n~le Direction IV~ ~oordinams V S . No. Size Type Set. No. 'Jets In Out Feet Hrs. WOB RPM T B G '1 Pump Liner Stroke S?M Pressure GPM Jet Vel. - Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight ~ o.,,~M., lCum ~.O ~?~ Io.,,~-,%.,,. c.~ Tangible Daily Well qj m~ Cum Well Drill H,O IPot H,O -IFue, i,,,,~,. ,u.~ ~,. I~°'"'*,,r. ~ ~oo0 . G0-1211 {CD-3-851 Printed m U.S.A. cc...o,.. --- Drilling Morning Report co,~. ~o,,~ u:r~ I~'~'°" ~,¢,~ 1~'~'''°~ A/.,~ .......... Depth ~ ~ l MO TVD ( 5~7 7 }BTD) IPr°p°sed TO MD TVO t ~ Oays Hrs. [2 Days /~ Hrs. Torque IDra9 J~ot., Wt. ~P/U Wt. ISlack O" Wt, IShoe lest Last Casing Size ~ ~/* Set ~ 6 500 MD TVD EMW On Casing ISince Last Cal. Liner Set ~ MD TVD- TOP ~ MD TVD Pm Pf/Mf / CL ~/~0 CA Ex Lime El Stab Wt..Material Gel ~Caustic Lib. Cls. Salt CaCl~ .... Other M ~ ~n~lo ~imction IV~ ~oordinat~s V S .. ~o. Size l~e Set. ~o. Oets In Out [ee~ ~rs. WOB 8~M I B G , lotal length {H.~.~.~.: } ~onsists o~ . ,, Cumo [ia~r Stroke S~M Pressure G~M 3et Vel. Mn. Vel. ~it Hrs. O~erations ~o~erin~ 24 Hours [ndin~ ~ Midnight . ~ ~¢~ (~~ ~/~)~o~ 5~'~ Jo**.~ - .. - _ . 4-- - ._ ~ - _ - Daily Mud /IX r ]Cum Mud ~2*Vr IDaily Tangible jCum Tangible IDaily W}Zg Drill H,O ~Pm H,O lFue, lBulk wt' IBulk Cmt' ~ 7 ~ ~ Printed ,n U.S.A. cc..o,.. Drilling Morning Report ~BT ]Proposed TD Depth ~Ot/ MD TVD ( ,,S' ~'~ 7 D) MD TVO :~ DOL //:~" Days Hrs. '// Days /8 ' DFS Hrs lT°tal Rot. Hrs. Last Casing Size ?~/~" Set~ ~0 ' -MD /~/~¢~ ~ /~2~VD ShoeTes, EMW Cum Rot. Hrs.: Depth Worst Wear [% Rem. On Casing ]Since Last Cal. Liner Set ~ MD TVD-TOP ~ MD TVD Pm Pf/Mf CL /~ ~/~ CA Ex Lime El Stab Wt. Material Gel ICaustic Lig. CIs. Salt CaCl~ Other Avg. Drilling Max. Drilling Conn. Trip Trip Chlorides [Remarks M D Angle Direction TVD Coordinates V S D LS No. Size Type Ser. No. ' Jets In Out Feet Hrs. WOB RPM T B G Total Length (H.W.D.P.: ) Consists of Pump .Liner Stroke ~ SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight ., OailyMud y~ ICumMud ~[7[0JD""vT"n¢'" ICumfanCe OailyWe'l~//~8 ]CumWell S~/~[7 _ Drill H,O IPo[ H,O IFuel IBulk WL ]Bulk Cmt. [Total App,. Printed in USA. cc.,o,.. Drilling Morning Report ' 7 ~BT.} Proposed TD Depth ~ ~0 / MD TVD ( ~ ~7 MD TVD _ DFS Hfs Total Rot, Hrs. Last Casing Size ?~/eo Set~ ~00 MD /0~/~ ~g~//~ flVO Shoe Test EMW ~ Cum ao~. U~s.: ~Oepm Wo~t We,r m% ~em. '~ On Casing )Since Last Cal. Liner Set ~ MD TVD- TOP ~ MD TVD · ~ Pm Pf/Uf / CL /2~000. CA Ex Lime El Stab Wt. Material Gel Caustic ]Lig. CIs. Salt CaCI~ .... Other ~ Avg. Drilling Max. Drilling IConn. Trip )Trip Chlorides [Remarks M D Angle Direction TVD Coordinates V S D LS No. Size , Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B G Tom, Length (H.W.D.P.: Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight ~ Daily Mud [Cum Mud Rig. 'G. Printed in U.S.A. CC-.or.. Drilling Morning Report ~_.~: IReoion Division Depth ~ ;0 { ' MD TVO ( ~ ~' ~BTD) ]Proposed ID MD TVD DOL , DFS lTotal RoL Hrs. / ~ Days Hrs. ? Days /~ Hrs. Last Casing Size ~ ¢/~ Set ~ ~ ~ O0 MD K~ ~/r ~ r~ ~ /~2' Shoe Test TVD EMW Cum Rot. Hrs.: ]Depth Worst Wear ~% Rem. On Casing ~Since Last Cal. liner Set $ MD TVD- TOP ~ MD TVD Gel WL HT-HP FC Solids %0i, ]% Sand Pm Pf/Mf CL /7 ~0 CA Ex Lime El Stab Wt. Material Gel Caustic Lig. ; Cls. Salt ~aCI, Other Avg. Drilling Max. Drilling Conn. Trip Trip C~lorides ]Remarks M D Angle Direction TVD Coordinates V S DLS No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B G Total Length (H.W.D.p.: ) Consists of . Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight /~ .~g. .... I.Z t . · , I- t ~ ~" '' ' d ~ '- ' , DailyMud q~ ~ ICum Mud ~/~/6 Daily Tangible Cum Tangible ~Oaily GO 1211 (C0-3-85) Printed m U.S.A. cc...,.. Drilling Morning Report .. Depth ~5~ ( r MD TVD ( ~77 PBTD) TO MD TVD /~ Days Hrs., ~ Days /~ Hrs. Lasz Casing size ~/~,, SetO ~00 MD /0>/~"~¢~ ~ //~' TVD ]ShoeTest EMW On Casing ISince Last Cal. Liner Set $ MD TVD- TOP ~ MD TVD GeI IWL ~HT-HP IFC ISolids I%0i' [% Sand {MBT Pm Pf/Mf CL CA Ex Lime El Stab / I g8~O Wt. Material Gel Caustic . Lig. ~ CIs. Salt CaCI~ Other · . ,,, M D ~n~le Diroction IV~ Coo[dinales V S ....... , ~o. Size lyre Set. ~o. . Jets In Out ~eet Hrs. ~08 , Cumo liner Strok~ SPM Pressure GPM Jet Vel. ~nn. Vel. 8it Hrs. O~orations ~ouorin~ 24 ~ours [ndin~ ~ MiOni~ht / ~e¢ ~/u. ' ' '.. j ;' · 6' 7"/~' ;o-,v, ,co3-8~, Printed in U.S.A. cc..o,.. Drilling Morning Report ComPany ~_-~,,I/~ [Region D,v,s,on Well ~ ~'X~.O, JCh'C°de [Field ~~ ~;*~ JDale~-~-r~ [Page /0, ~, Depth ~ 50 / MD TVD ( ~ ~7 7 PBTD) Ipr°p°sed ID MD TVD ~ DOL DFS ]Total Rot. Hrs. · ~ // Days Hrs. 7 Days /~ Hrs. = Torque ~Drag JRot. Wt. P/UWt. [SlackOffWt. Last Cesing Size ~ ¢/8" Sete ~¢00 / MD /~?/?"~r~ ~ //~ 'TVa IShoe Test EMW .~ "Cum Rot. Hrs.: Depth Worst Wear [% Rem ~ On Casing ~Since Last Cal. Liner Set $ MD TVD- TOP ~ MD IVD , ~ Pm Pf/Mf C L/~ O/O0 0 CA Ex Ume El Stab Wt, Material Gel ICausfic Lig. Cls. Salt ~aCl~ Other ~ Avg. Drilling Max. Drilling IConn. Trip [Trip Chlorides Remarks M O Angle Direction TVD Coordinates V S DLS . . No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM I B G ._ Total Length (H,W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Ending Midnight ' - Operadons Covering 24 Hours ¢ r~ '' ,, IC.m ., /~S~Z IDaily Tangible ]Cum Tangible 'Drill H.O IPot H,O I~ue, I,u,~W,. ]Bulk Cmt. ' ~ 7 ¢ f 60-1211 iCD-3-85l · Primed ~n USA. Drilling Morning Report Depth ~50 / MD TVO ( ~ ? 7 7 PBTD) IPr°p°sed TD MD TVB DOL /0- Days Hrs. ~ Days /8 Hrs. DFS lolal Rot. Hrs. Shoe Last Casing Size ?~/~,, SetO ~00 MD /O~/~' //~ '~ ~ar~TVD EMW Cum Rot. Hrs.: ]Oemh,Worst Wear % Rem. On Casing ~Since kast Cal. Liner Set $ MD TVD- TOP ~ MD TVD Pm PI/MI CL /~ ~000 CA Ex Lime El Stab Wt. Material Gel ica,,s,,c Lig. Ds. Salt Other ~ Avg. Drilling Max. Drilling ]Co.n. Trip Trip Chlorides IRemarks M D Angle Direction TVD Coordinates V S DLS No. Size- Type Set. No. Jets In Out Feet Hrs. WOB RPM T B G lotal length ~H.~.~.P.: } Consists ot Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vet. Bit HHP Pump HHP Hrs. O~orations Co~oria~ 24 Hours [ndin~ ~ Midnight Drill H,O IPo'H,O . JFue' IBulk wt. JBulk Cmt. JTota' APPr. ?~000 ., GO 1211 Printed in U.S.A. ',c..o,.. Drilling Morning Report Well ~ 2~/-~g~.~. ICh'C°de Field ~ ~ ProposedTD Depth ~0[ MD TVD ' ( ~ ~ 7 PBTD) MD TVD .~ DOL IDFS Hfs Total Rot. Hrs. ~ ~ Days Hrs. ~ Days /~ · ' Shoe Last Casing Size ~ ¢/$ ',Set ~ ~00 / MD /07/¢ "ja ~ ~ //~ ' TVD Test EMW .... ~ Cum Rot. Hrs.: DePth Worst Wear ]% Rem. ~ On Casing lSince Last Cal. Liner Set ~ MD TVD- TOP ~ MD TVD · ~ Pm Pf/Mf / CL/~O00 CA Ex Lime El Stab Wt. Material Gel ]Caustic Lig. CIs. Salt CaCl~ Other ~ Avg. Drilling Max. Drilling ]Conn. Trip tTdp Chlorides Remarks M O Angle Direction TVD Coordinates V S DIS I No. Size Type Ser. No.. Jets In Out Feet Hrs. WOB RPM T B G total Length (H.W.D.P.: ) Consists of Pump Liner Stroke sPM .Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnigh~ X O~,vUud 2873 Prlnled in U.S.A. Drilling Morning Report CC-Morn. -- w,,, I~"' ~' I~'~'~ e ~ ~,o,~ - ~- r~ / o, / Depth ~ ~ 0 / MD TVD ( ~?~ PBTD) IPr°p°sed ID MD TVD IDFS IT°ml R°'' Hfs' ~ DOL 7 Days Hrs. ~ Days /& Hrs. ~ Torque IDrag IR°t' wT' IP/U wi' lSlack Off wi' ~ ~Shoe lest Last Casing Size g~t~ Set~ 6~00 MD /0~/~ ~.r~ ~ //2'TVD EMW ~ Cum Rot. Hrs.: Depth Worst Wear ]% Rem '~ On Casing JSince Last Cal. brier Set ~ MD TVD- TOP $ MD TVD ~ oO Wt. Material ~ Gel ~Caustic Lig. CIs. Salt CaCI~ Other ~ Avg. Drilling Max. Drilling IConn. Trip Trip Chlorides ~Remarks M D Angle Direction TVD Coordinates V S O [S ~ · No. Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM I 6 G Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP ~ . Hrs. Operations Covering 24 Hours Ending ~ Midnight ' 7n'.~, ~t~ / ~'~ mil.. ~,'~ ~~'/~~,: · - ; , r , ~.' - ' g 7/g ,,,,,,,,,u.s.A. cc.o,.. Drilling Morning Report Depth ~ ~0 I MD TVD ( ~Z ~ PBTDI ]Proposed TD MD TVD ~ Told RoL Hrs. ._'~ ~o~ 7 oa~s H,~. ~ ~ Days /8 H,~. ~ Torque Drag , ]Rot. Wt. P/U Wt. Slack Off WL Last Casing Size ~ ~/~ Set ~ ~ ~ ~0 MD /~ ~/~ ~ ~ //~' TVD ]Shoe Test EMW ~ Cum Rot. Hrs.: Depth Worst Wear % Rem '~ On Casing ]Since Last Cal. .. ~ Liner Set ~ MD TVD- TOP ~ ~ MD TVD FV PV I'"'" I Solids %0il %Sand MBT ]PH ~,~ ~ Pm Pf/Mf CL/~~ CA Ex Lime El Stab m I Wt. Material Gel Caustic.. / Lig. CIs. Salt Other ~ Avg. Drilling. Max. Drilling ]Conn. Trip Trip Chlorides Remarks MD Angle Direction TVD . Coordinates VS OLS No. Size Type Set. No. Jets In Out Feet Hrs. WOB RPM T B G Total Length (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Co~erin~ 24 Hou)s [ndin~ $ Midnight I ~ DailyMud 0 lCumMud /~~ ~ Daily Tangible Cum Tangible ]DailyWell j~~ CumWell CC-Morn. Drilling Morning Report Depth. ~ ,~0 / MD TVD ( ..5' ~7 7 PBTD) ] Proposed TD MD TVD ~ DOL IDFS Total Rot. Hrs. ~ ~ Days Hrs. ~ Days //~ Hrs. · / Shoe 'Test Last Casing Size ? $/~ Set.~ ~00 MD /~/~ ~,~ ~"//~TVO EMW ~ On Casing JSince Last Cal. Liner set ~ MD TVD- TOP ~ MD TVD Wt. Material Gel {Caustic Lig.. Cis. ;alt . 'CaCI~ Other . ~ Avg. Drilling Max. Dritlinb lCo,n. . _ ITri, }Trip Chlorides . JRemarks M D Angle Direction TVD Coordinates V S D LS -{ . . , No. Size Type ser. No. Jets In Out Feet Hrs. WOB RPM T B G Total Length (H.W.D.P.: ) 'Consists of Pump Liner Stroke SPM Pressure GPM Jet VeL Ann. Vel. Bit HHP Pump HHP , His. O~orations Coveria~ 24 Hours [ndin~ ~ Midni~hl ,, ,,,, ~ DaiiyMud /V/ ICumMud /'~PO J Daily Tangible ICumTangible IDailyWell~o~ff~ ~CumWe,l /Z~7;8 . Prmted in U.S.A. Dril Morn' Depth Proposed TD ' ~0/ MD TVD ( XY77 P.TD)'" MD TVD .; DOL ~ Days Hrs. / Days /~ . Last Casing Size ~ Set O ~ r~ MO I~ ~/r" ~ ~ t. Il I QTVD JShoe Test EMW .~ Cum Rol. Hrs.: IDepth Worst Wear % Rem, ~ On Casing JSince Last Cal. I Liner Set ~ MD TVD- TOP ~ MD TVD ~tI. CO FV PV ~ Pm Pf/Mf CL CA Ex Lime El Stab m / Wt. Material Gel Caustic Lig. CIs. Salt CaCI~ Other M ~ ~n~le ~irection IV~ Caordinates ...... ,. ,,, No. Size Type Set: No. Jets In Out Feet Hrs. WOB RPM T B G , Total Length (H.W.D.P.: ) Consists of' ,, Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations ~overin~ 24 Hours [ndin~ ~ Midnight . ~ ~ ' . . . ,, . , DailyMud '~~Po?umMud '~'~'~Fue. ] Daily Tangible JCumTangible .JDailyWel.,,, ~'J~otalAppr. Drilling Morning Report I;C-Morn. Oivision ]Proposed TO Oep~h ~01 MD TVD ( ~V77 PaTm aO TVO DOL DFS Hrs Total Rot. Hrs. ~ DaYs Hrs. Days /~ · Last Casing Size ~ SetO ~ MD ~/Y . -I1~ TVD EMW ' Cum RoL Hrs.: iDepthWorstWear · ]%Rem On Casing ~Since Last Cal. Liner Set ~ MD TvD- TOP ~ MD TVD Pm Pr/Mr / CL /l~ ~ CA Ex Lime El S~ab Wt. Material Gel ~Causfic Lig. CIs. Sal~ CaCI~ Other Avg. Drillin9 Max. Brillin9 Conn. Trip M D AnBle Direction TVD Coordinates V S DLS ,, No. Size Type Ser. No. Je~s In Ou~ Feet Hrs. WOB RPM T B G Consists of Tmal Length (H.W.B.P.: ) , ,, Pump Liner S~roke gPM Pressure GPM Je~ Vel. Ann. Vel. Bi[ HHP Pump HHP Hrs. a~erations Co~rin~ 24 Hours [ndin~ ~ Midnight G~o .~a, le~ ~uu b.,Ig sa.d + s&do~. ~ata. oul{,.~ ~1- recooerod x~ aA~ ~, 6~ PS g . Y -- Daily Mud 13 ?~ ' Cum Mud ¢10tlt? 'lDaily Tangible. /[ intangible Cml.Daily Well ~3~o ICum Well //3/ygy Pnnted in U.S.A. c,..o,.. Drillinq Morning Report IRegion IOivision '"" '"" Depth ~] MD TVD ( ~g77 PBTD) MD TVD ,, . ~Proposed ~ Days Hrs. Days Hrs. Cum ~ot. Hrs.: o~th Worst Waar On Casin~ ]Sinc~ last Cal. Set ~ MD TVD- TOP ~ MD TVD i , Pm Pf/Mf CL CA Ex Lime El Stab Wt. Material Gel ICaustic Lig. CIs. Salt CaCb 'ioth~r M O Angle Direction TVD Coordinates V S O LS . . No. Size Type Sar. No. Jets In Out Feet Hrs. WOB RPM T B G total Length : ' (H.W.D.P.: ) Consists of Pump Liner Stroke SPM Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. O~eradons Coverin~ 24 Hours [ndin~ ~ Midnight , ,,, GO1211 (C0-3-851 Pr,hied in USA. ,,..o,.. Drilling Morning Report. ~ aw-3v w.~. ~o~,- '' g~~a ~tu~ .. I~ ~/~,/r~ I o, I Proposed ID Depth ~/ MD TVD ( ~~ PBTD) MD TVD 'OOL JDF,S JTota, Rot. Hrs. ~ Days Hrs. Days Hrs. Torque ' ~Drag Rm..Wt. P/U Wt. JSlack Off WL JShoe Test Last Casing Size Set ~ MD TVD EMW Cum Rm. Hrs.: JDepm Worst Wear ~% Rem On Casing ISince Last Cal. , Liner Set ~ MD TVD -TOP ~ ~ MD TVD Pm Pf/Mf CL CA Ex Lime El Stab Wt. Material Gel JCaustic Lig. CIs. Salt CaCI~ Other - Avg. Drilling Max. Drilling ]Conn. JTrip I Trip Chlorides JRemarks' M D Angle Direction TVD Coordinates V S DLS ,. No, Size Type Ser. No. Je~s In Out Feet Hrs. WOB RPM I B G ,,, ,, Total Length (H.W.D.P.: ) Consists of . Pump Liner Stroke SPM -Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP ,, Hrs. Operations Covering 24 Hours Ending ~ Midnight , ~ Daily Mud ~' ipo{C;;Mud~, ¢,r I~'"'"'¢'e Ic.m T..gib,e ,Daily Well~ ~, ~, ~Total ]Cum Well , ~ qO~ ,, , 60-1211 (CD-3-8§i Printed in U.S.A. cc..o,.. Drilling Morning Report Company ~ //~ U R ON (,dES ~" ~ ~-~ ~.~. Ic~'~°'' I~'''" ~,,~ ~,0~ 1~'' IProposed TO Depth ~/ MD ., TVD ( ~Y77 PBTD) MD TVO ' D'OL JDFS JTotal Rot. Hrs. · ~ / Days Hrs. Days Hrs. Casin~"Sizo , Last Set ~ MD TVD jShoe Test EMW [ .~ Cum Rot. Hrs.: ~Depth Worst Wear % Rem ~ On Casing ]Since Last Cal. l Liner Set ~ - MD TVD- TOP ~ MD TVD ~ P'm Pf/Mf CL CA Ex Lime El Stab m / Wt. Material Gel ]Caustic Lig. CIs. Salt ~aCl~ I Other M ~ ~n~l~ Direction IV~ CoorOinatos V S ~ , ~o. Size l~e Set. ~o. 3ets In Out [ee~ Hrs. ,.. total [enoth {H,~,D.P,: } Consists of ~um~ Uner Stroke SPM Pressure ~M ~et VoL Ann. Vel. Hrs. O~orati~ns Coveria~ 24 Hours [ndin~ ~ Midnight , . I , ~. Daily Mud,, ~j ~JCum Mu, ~ ~t f J Uai,vTangible CumTo.g,b,. IOa,,vWell aa ~3 ]Cum Well G0,1211 1CD-3-85) Printed in US.A, cc..o,.. Drilling Morning Report Company C/L~_~ ~.,)RO/~ IFlegi°n ~1_.~".~ T~'/~/~ IDivisi°n / L~~ Depth ~ ~0 ( MD TVD ( ~(/77 PBTD) ~Proposed TD MD TVD Last Casing Size Set ~ MD TVD JShoe Test EMW ' Cum Rm. Hrs.: . JOepth Worst Wear J°/o Rem. '~ On Casing ~Since last Cal. Liner Set ~ MD TVD- TOP ~ MD TVD ~ Pm Pf/Mf CL CA Ex Lime El Stab Wt. Material Get ~Caustic Lig, Cls. Salt ~aCl~ Other ~ Avg. Drilling Max. Drilling ICe,. IT, i, JTrip Chlorides , M D Angle Direction TVD Coordinates V S DLS' ,.. No, Size Type Ser. No. Jets In Out Feet Hrs. WOB RPM T B G Total-Length (H.W.D.P.: ) Consists of , . . Pump Liner Stroke S~M Pressure GPM Jet Vel. Ann. Vel. Bit HHP Pump HHP Hrs. Operations Covering 24 Hours Ending ~ Midnight 51/l ' ' . $ Daily Mud G0.1211 ICD-3-851 Pnnted in U.S.A. STATE Of ALASKA ALau:..A OIL AND GAS CONSERVATION CON .... ~SSlON APPLICATION FOR SUNDRY APPROVALS "1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ]~ Other 2. Name of Operator ..Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location of well at surface 899' S & 1399' W of NE Corner, Sec. 34, T13N, lOW, SB&M 5. Datum elevation (DF or KB) G.L.=88' K.B.= 110 6. Unit or Property name Beluga River Unit 7. Well number BRU 241-34 feet At top of productive interval Same At effective depth Same At total depth Same 8. Permit number 72-0016 9. APl number 50-- 283-20038 10..Pool Sterling & Beluga 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 6501 feet 6501 feet Plugs (measured) 5477 feet Junk (measured) 5477 feet Casing Length Structural 16 ' Conductor 381 ' Surface 2356' h~-ter-me~a.te * 90 ' Production 6267' Size Cemented Measured depth True Vertical depth 30" 44' 44' 20" 800 sks 405' 405' 13 3/8" 1705 sks 2380' 2380' 10 3/4" 112' 112' 9 5/8" 1060 sks 6389' 6389' Perforation depth: Top 90' of productioncasing is 10 3/4" 51# P-110 Csg. measured See Attached true vertical See Attached Tubing (size, grade and measured depth) RECEIVED SEP 1 5 198(; Packers and SSSV (type and measured depth) Alask~ 011 & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal [] Detailed operations program I~ BOP sketch [] 13. Estimated date fOr commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that ~e foregoing is true and correct to the best of my knowledge Signed ///~ Title Acting Area Operation Superintendel~te Commission Use Only Conditions of approval Approved by ~y [~t~. Form 10-403 Rev 12-1-85 Notify commission so representative may witness [] Plug integrity [] BOP Test © Location clearance ~eturm~l ~ __ [ ApprovalNo. ~23 Commissioner by order of thecommissionDate ~-'/~-~ / Submit in triplicate CHEVRON U.S.A. INC. WESTERN REGION. ALASKA AREA WELLWORK PR(X:EDUR. F,. ~JJMMARY ORIGINAL OBJECTIVE ' LOC.' '~'"~, C' '~ ct/ TYPE WELL' TYPE,JOB' SUMMARY l-1 SUPPLEMENTAL SUMMARY ~L, NO. WELL DATA' K.B. ~-~. '"' ~' /~.~"--//&) /T.D. &~-'4) / ~' PBTD ~-Y77 ' c^S~NG' ~/,~" ~. ~ ~ ~-//~) ~ ~- ~a ' ' LINER' PERFORATIONS · REIt:'! v t:u NOTES: SEP 1 ~ · , n--~ ..,,- I'~nmnliGglnn AlasY~ u. (x a~o ..................... PROGRAM an~.hnmgO DETAILS ATTACHED Distribution: Original to Well-File Orig. Superintendent Engr. ($) Field Office (I)- Preparer (I) Engr. Technician (I) WELL' PROGRAM CHEVRON U.S,A. INC. WESTERN REGION ALASKA AREA WELLWQR~ P~D~RE SUMMARY (CONTINUED)' DETAILS ATTACHED Distribution: 0rl~. Superinte.dent Efl~r. (~) ~sCOBS, COfll~iSSIO~ Field Office (I) Preparer (I) E~gr. Technicion (I) Approved by -II _ . . ~r~l ,El:) .... ........... ,~:P :I. 5 ]985 Nas~ 011 & Gas Cons, .Commission Anchorage U N/lm"~ STATES s~m~ (Other lnatruetions DEPARTMEt -F THE INTERIOR ,erse-'de) BUREAU OF LAND MANAGEMENT ,.qEP 0 8 1BSl/UNDRY NOTICES AND REPORTS ON WELLS (Do not u~se this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such pr~possJs.) ~. F~DL;CT', ~ '~ 2. NA%~E OF OPKRATOR Chevron U.S.A. Inc. 3. ADDREHS OF OPERATOR ._ P. O. Box 107839, Anchorage, AK 99510 I. COCATION OF ',VSL~ (Report location clearly and tn accordance with any State requirements.* See also space 17 below.) AC surface 899'S & 1399' W of NE Corner Section 34 _( PER,MIT NO. 50-283-20038 15. ELEYATIONS (Show whether DF, aT, ga, etc.) G.L. = 88' K.B. = 110' Form approved. Budget Bureau No. 1004-0135 Expires August 31, 1985 5. LEASE DESIGNATION AND sm~IAL NO. · ,. BRU 241-34~ ._!0. ~ZELn~i/O-n~r~, Oit W~LVCAe t~elu~a River, Beluga and Sterltnq __ Il. BBC., ~., u., M., OI BLK, AND BUIVB! Oil ~uu& 'JO Sec.34, T13N,R'~W, SB&M -- 12. tOaSTY oa P~amHj 13. STA~E Kenai Borough J Alaska [ Check Appropnate Box To Indicate Nature o[ Notice, Report, or Other Data NOTICE OF INTENTION TO: FRACTUaE TREAT M U L?IPLr COM PI.ETE SHOOT oa ACIDIZ~ ~B&NDON* { (-)thor) ~ J flUBSEQUBNT mmpOItT OF: wATEa SHUT.)Pr ~ aEPalaxso WELL FRACTURE TREATM&NT ALTBRIN~ CASINO SHOOTING OR ACID/ZING ABAN~NMBNT* (Other) (NoTE: Report results of multiple completion on Well completion or Recompletion Report and Log form.) bE.%('RIBE I'ROI'OSED OR COMPLETED OPERATION-~: (Clearly state all portlnent details, and give pertlnont dates, Including ~tlmated date of starting any proposed work. If well is directionaJly drilled, give subsurface locations and measured and true vortical depths for all markers and ~ones perti- nent to thi~ work.) * See attached program. We anticipate starting work immediately. I hereby eertif~ is true and correct Acting Area TZTL~ Operations Superintendent D~ 8'~.9-~./- , APPROWV S~ _J0seoh A_ CONDITIONS OF APPR(~¥AI~: 4C lN Asststant I lstrl t TITL~E'~J'Ii',/jejem .~ tl~ .... , DA~E SEP 3- 1986 Title 18 U.S.C. Section !001, makes it a crime for any person knowingly and willfully to make to any department ur agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. /" STATE OF ALASKA ~ ~ ALA,_..,,x OIL AND GAS CONSERVATION CON .... ..,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) Chevron U.S.A. Inc. G.L.=88' K.B.=I l0 feet 3. . Address P O. Box 107839~ Anchorage, AK 99510 Location of well at surface 899'S & 1399'W of NE Corner Sec. 34, 13N,10W, SB&M 6. Unit or Property name Beluga River Unit 7. Well number BRU 241-34 At top of productive interval Same At effective depth Same At total depth Same 11 · Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface X X XrK~clKaZeX Production Length 16' 381' 2356' 90' 6267' 6501 feet Plugs (measured) 6501 feet 8. Permit number 72-0016 9. APl number 50-- 283-20038 10. Pool Sterling & Beluga 5477 feet Junk (measured) 5477 feet Size Cemented Measured depth 30" 44' 20- 8oo sKs 4o5' 13-3/8" 1705 SKS 2380' 10-3/4" 112' 9-5/8" 1060 SKS 6389' True Vertical depth 405' 2380' 112' 6389' X~tXXX * Perforation depth: Top 90' of production casing is 10-3/4" 51// P-110 Csg. measured See Attached Program "-" '/ i true vertical Same 2 9 1986 Tubing (size, grade and measured depth) See Attached Program Packers and SSS¥ (type and measured depth) See Attached ' Program 12.Attachments Description summary of proposal [] Alaska 0,i ~ c,a~ (;0,s. Commission Anchorage Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation Immediately 14. If proposal was verbally approved Name of approver 15. I hereby certify that the/oregoing Signed Date approved is true and correct to the best of my knowledge Acting Area Title Ooerations Suoerintendent - Commission Use Only Date Conditions of approval Approved by 11¥ Lgttttli II" $11lli Form 10-403 Rev 124-85 Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Approveo C~oy Commissioner No. by order of the commission Date Submit in triplicate PRO 316-1 PROPOSAL FOR WELL OPERATIONS WELL: FIELD: LOCATION: ELEVATION: PRESENT STATUS: BRU 241 - 34 Beluga River At surface: 899'S & 1399'W of NE Corner Section 34, T13N, R10W, SB&M At Top Prod. Interval: Same At PBTD: Same At TD: Same G. L. = 88' K.B. -- 110' TD (MD): 6501' PBTD (MD): Casing: 5477' (Bridge Plug) 30" La 44' 20" Cemented La 405' 13-3/8" Cemented La 2380' 9-5/8" Cemented La 6389' 112'- SFC with 10-3/4" Pll0' Perforations: 5375' - 5345' 5331' 5271'- 5255' 5233' 5201' - 5186' 5161' 5048'- 5032' 5024' 4972' - 4968' 4911' 4878'- 4875' 4858' 4835' - 4831' 4784' 4770'- 4766' 4757' 4503' - 4499' 4489' 4398' - 4394' 4386' 4222' - 4215' 4186' 4358'- 4337' 4276' 4138' - 4072' 3968' 3943'- 3939' 3900' 3870' - 3866' 3836' 3804' - 3797' 3738' 3693'- 3681' 3663' 3643'- 3623' 3617' 3545' - 3537' 3522' 3503'- 3493' 3462' 3425' - 3416' 3411' 3340'- 3334' 3318' - 5326' - 5213' - 5137' - 5016' - 4907' - 4856' - 4780' - 4732' - 4464' - 4382' -4184' R C't'r~~ - 4259' - 3963' A!-J~ ~ c) ]§86 - 3896' 381~l'aska bi~ ~ ~ ~ ..... - 3718' Anchorage - 3657' - 3614' - 3518' - 3450 - 3405' - 3312' 3392'- 3362' 3283' - 3244' 3167' - 3148' 3131'- 3126' 3111' - 3101' 3096' - 3066' 3057' - 3056' Squeezed 3024' - 3023' WSO Tubing: Junk: NOTE: BLOWOUT CONSIDERATIONS: See the attached detail . The No. 2 string is parted below the second packer at 3180'. The exact fish detail is unknown. o The Brown HS-17 3C packer at 2856' appears to be leaking.. String No. 1~ also appears to be leaking through either sleeves or the plug set in the "S" nipple at 4048'. e . Gas: This well is capable of producing over 20,000 MCFD. Care must be taken at all times not to swab the well and to keep the hole full on trips. ® Lost Circulation: None anticipated, but lost circulation material (salt pills) should be readily available at all times. Precautions: Any kicks should be handled by normal procedures. Rig crews should be made aware of these methods, and care must be excercised at all times. Maximum Anticipated Formation Pressure: 2428 PSI (from build up data January 1977). Programmed weight of 9.6 PPG will provide 80 PSI minimum overbalance. Formation Equivalent Interval Pressure, PSI Mud Weight, PPG 3167' - 3066' 1446 9.1 - 8.3 3548' 3244' 1404 p ~ r" ~IV F ~J 8.8 3943'- 3614' 1646 ~ ~ ~ ~. 4503' - 4072' 1504 7.1 5048' - 4732' 1941 ~.~'~...,~ ~ ~ ]~86 7.9 5375' 5137' 2428 9.1 Maximum Anticipated Surface Pressure: 2274 PSI = FormatiOn Pressure at TVD - .03 (Gas Gradient) *TVD 2428 = (.03 *5237) 6. Blowout Prevention Equipment: Minimum of Class III - 3000 PSI. BRU 241 - 34 WORKOVER PROGRAM . . . . Prior to moving in the workover rig, install Cosasco BPV's in all four tubing strings. Move in and rig up the workover rig. Remove the back pressure valves from the #1 and #4 tubing strings. RU C. A. White, and make sure all "XA" sleeves in string #1 above 4048' are closed. Open the "XA" sleeve at 2811', and kill the annulus by circulating down the long string and taking returns through both the annulus and #4 string (heat string). RU C. A. White. Open the "XA" sleeve in string #1 at 3177'. Remove the plug from the "XA" sleeve in string #2 at 3167'. Open the "XA" sleeve in string #2 at 3167'. Circulate the #1 and #2 strings dead by circulating down string #1 and up string #2. . . . . 10. 11. 12. 13. 14. 15. 16. 17. RU C. A. White. Remove the BPV from string #3. Remove the plug from the "D" nipple in string #3 at 2874'. Circulate the #1 and #3 strings dead by circulating down string #1 and up string #3. RU C. A. White. Open the "XA" sleeve in string #1 at 3569'. Circulate the # 1 string dead by circulating down string # 1 and up string # 2. RU Schlumberger, and jet cut string #1 at 3566'. Install BPV's in all four tubing strings. Nipple down the tree. Nipple up the class III - 5000 PSI BOP stack; and test the rams, manifold, and valves to 5000 PSI. Test the annular to 3500 PSI. The BLM and AOGCC may witness the test, and must have 24 hours prior notice. Install offset 2-3/8" rams in BOP's. Pull out of the hole with the 2-3/8" heat string and production equipment. Change offset 2-3/8" pipe rams around. Pull out of the hole with the 2'3/8" #3 string and production equipment. RU dual slips, elevators, and tongs. Install dual rams in BOP's. BUR 241 - 34 WORKOVER PROGRAM Page 2 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. Release the triple packer at 2856' by shear release (approximately 40,000# over). Attempt to release the dual packer at 3181' by shear release. The safety joints at 3143' and 3155' are set for 50,000# shear release. Pull out of the hole, and lay down the tubing and production equipment. Pick up and trip in the hole with a guide, extension, overshot dressed with grapples, bumper sub, jars, pump out sub, drill collars, and drill pipe. Wash to the top of the fish estimated at 3236', and work over fish (estimated to consist of 10.75' 2-7/8" pup joint, 2-7/8" "XA" sleeve, 10.5' 2-7/8" pup joint, 2-7/8" "D" nipple, 10 joints 2-7/8" tubing, and wireline re-entry guide). Pull out of the hole and lay down the fish. Trip in the hole with a 9-5/" retrievable bridge plug and retrievable packer on drill pipe, and set the RBP at 2975' + Dump two sacks of sand on top of the RBP. Test the 9-5/8" casing above the RBP to 2000 PSI for 30 minutes. Locate leaks if there are any. A squeeze procedure will follow if there are any leaks. Pull out of the hole with the packer. If there are squeezes, after all squeezes and clean out runs are made, make a 9-5/8" casing scraper run to the top of the RBP. ND the BOPE and tubing spooL NU the 13-5/8" x 11" 3000 PSI tubing spool and test to 1500 PSI. NU the BOPE and test to 3000 PSI. Trip in the hole with the retrieving tool, and POH with the RBP. PU and TIH with the fishing string to the top of the #1 tubing string at 3565'. Work over the top of the fish. RU C. A. White. Attempt to remove the plug from the "S" nipple at 4048'. If successful, attempt to remove the plug from the"D" nipple at 5109'. Release the packers with shear release. POH and lay down the tubing and production equipment. Pick up and TIH with an 8-1/2" bit and the drill string. Clean out to PBTD, and circulate the well clean. Pull out of the hole. RU Schlumberger, and run CNL, CET, and Casing Inspection logs as directed by Anchorage Engineering. It will be decided at this time whether to test the bottom two zones and whether to reperforate the top two intervals. Additional procedures will follow as required. BUR 241 - 34 WORKOVER PROGRAM Page 3 31. 32. 33. 34. 35. 36. 37. 38. 39. 40. 41. Trip in the hole with the 8-1/2" bit and casing scraper to PBTD. Circulate the well clean. Lay down the drill string. RU dual slips, elevators, and tongs Install dual 2-7/8" pipe rams. Run dual 2-7/8" production tubing and equipment per the attached proposed tubing detail. Internally test the tubing below the table to 5000 psi. Space out as required with a full joint on top, and install BPV's in both strings. Land the tubing in the parent hanger. Install 2-3/8" pipe rams. Run the 2-3/8" heat string and equipment per the attached detail. Internally test the tubing below the table to 5000 PSI. Install the BPV, and land the 2-3/8" tubing. ND the BOPE, and NU the tree. Test the tree to 3000 PSI. Remove the BPV's. Reverse circulate diesel down the annulus until clean returns are obtained at the surface as follows: A. Up the heat string. B. Up the short string. c. Up the long string. Hydraulically set the packers. 'Pressure up and shear out the ball. Test the annulus/packer to 1500 PSI for 30 minutes. Open up the long string to the production seperator as directed by Anchorage Engineering, and flow the well until it cleans up. Open up the short string to the production seperator, and flow the well until it cleans up. Test the heat string side per the Area Production Foreman. Install BPV's in all three strings Release the rig, and rig down the rig. Remove the BPV's, and return the well to production. V. W. Angell WORKOVER FLUIDS PROGRAM BRU 241 - 34 BELUGA RIVER FIELD FLUIDS SYSTEM: PROPERTIES Kill Circulating Type Litesal/Liteplug Litesal/Liteplug Weight (PPG) 10.0 9.3 - 9.6 Viscosity (SEC/QT) 65 - 70 35 - 50 Fluid Loss (CC/30 MIN) 5 - 7 NC Plastic Vis. (CPS) 8 - 10 8 - 10 Yield Pt. (LBS/100 Ft2 20 - 30 8 - 12 Gels (LBS/100 Ft2 8/12 3/3 pH 9 8 Solids (% by Volume) 17 7 KCL (% by Volume) 3 3 Use primariy a brine water system with the above pills for either kill plug setting or lost returns. Partial returns was a problem during both the workover in 1974 and the recent killing operation to repair the wellhead leaks. Spot lost return pills as required during workover operations. Spot a viscous pill above the cut tubing at 3566' prior to pulling out of the hole with string #1. ,~l, Od" A~,q~' . 2 '-'b'DO~9 ,~.r'/ ! 7d ! d'~Y/d'X/ 7' -1 Wi 4004.82* --~ - : 400- 34 ~ ' ~o,z'-,.-404~ 52' ~ ~ JT. 2~ E~ 8rd N-80 ~G. , I .... '-..' l ~- ~ :~ ~m ~ ~. Il ' ::::.:::: I '. I / ' I I · ~4s~e'o~,~ . I 4608 59' ~ -- B~ H-1S~ Packer I-I ~{::~ I . I ; I llll"}~l I ' I t I, i' ,so,'-,r / !1 .... "'"5 . -- 5059 73' 1 ~, ~" E~ 6rd N-80 ~G, t' I I ' ~'-- B~ 'CC' S~TY JT. /1 I I--~o~ ~,~ ~' ~ ~ I .i ~o~'~s,~I . ~ - . l ,-,'-,,' l '~ ~E~ ,,o'.oo. TOP OF PLUG 54T~' . - i ~ / ~ '"'" .... I :1~1"'""' ' · :" ' · T 0 6501 .. 20" 04e NeD 4 ~LT ~. l~ .~ 8r~ t;-~3 ~. 6 13%02100' Z - 90 ~S. 2~" J ~ 2~" P~ JT. E~ 0rd N-80 ~ I.XO" --2846,34* ~t-- BR~ iCC' ~A~ JT, J I · 2%' P~ JT. J ~ 8 ~S. s,z~>~,',--3142.90 ~_ 9~4 STraiT PU~ S~ JT. ZoS3e [ z ~l PL~ JT E~ 8~ N-80 ~G ~0.04e . ..... ~ 2 2~" P~ ~ E~ 8td N-80 ~G 4,40' ...... ~Z ~" e~ ~. E~ 8rd N-80 ~G lQ.SO' 5~,z'.-re~ ~2--~ 'D' NZPP~ .94° ~f~::~; I ~ NOTE: No.z STRING O' TUBING PARTED alLOW SECONO PACKER ANO ...~. ~3S33.05' ~ · ~1- B~ HI S~ PA~R 9.45' :S~t r-B4' l ' 399? 37'~ I JT. 1%" EC~ 8rd N-80 TBG. 30.4?' 2~" Pt~ JT. 3.52' 2134.&7' 8.330 Xg73,84' ' 9,70' . · ~g2* · ~0.60' .' · ' .S8' !~97, 5b' 13.10' ~0.28' 1.40' 4.10' 3.S2' 2.50' 7.05' 1.30' 30.93' 1.58' · 13.20' 29.42' 1.40' 4.50'~ 3.52' 1.30' 7.06' 1.30' 30.68 ' .96" 123.66' .67' IBELUGA RIVER 241- :54 CASING i TUBIN(; DETAILS SECTION ~,4, T. 13 N R.IOW. 0 o GAS zLL OPEN FLOW POTENTIAL TEST 4-POINT TEST Test Initial. ~ Annual U .'DRT Special ['--] Field Reservoir j Test Date · Beluga River Beluga Formation J 10-1-79 Oper,'~tor Lease J %Vell No, Chevron U.S.A. Inc. Beluga River Unit JBRU 241-34 County Kenai Loc~'ttion Section 34, T13N, R10W, SB&M J J C0mpi0tl0nDate j T0tal D,pth J T/Pay I ~r0du~i,gJ~ 8-10-72 6501 66 ,4v--C4503 · Producin~ Thru j ae,em'oJr I Wellhead [ CSm Slze ~Vt/Ft. ' ] I.D. J Se,~ 6500' T~G. J CSO. Temperature 'Temperature 88'~ 77 'F 9-5/8 43.'5 8.755 Bridge Plug ~ 5477' 2-7/8 6.5 ? 875 2 ~1 5235 {Separator) Length {h} -~aflo ~lr~ ~er Bbl. Liquid · · 0.558 ..... Pipeline Conneetton ~Tpe Chugach Electric ~ssoeSat~on ~lange Multiple Completion (Dual or Triple) String 1. Long. string J Type production from each zone · (3rd interval) of .triple coaplettoa , Dry Gas Note: Production is through OBSF. RVED DATA sleeve at 4595' (1)Flow Data (1) (2) Time (Prover) " 'Orifice Static. jDiff~ren'~'ii~l Bottom- Cas,!ng Flowing No. of Flow (Line) Plate ~ 'Pen [Pen Hole Press. Temp. Hours Size Si Z e 1Re ad in s~ 1950 Packer I. 2.0 J 4. 026 2.000 5.90 1.50 1915 ". .... 88° ~. 2..0 .. J 4.026 { 2.000 5.90 3.20 1872 " 88° ~. ,,2,0J 4.026 ,',j ,2.000 5.90 4.80 " 1813 ' " 82° ~... 2.0 J 4.026 2.000 5.90 J 6.50 1738 .. " 74° FLO~V CALCULATIONS , ,. Coeffi- Static ' Flow Temp. Gravity Compress. No. cient X Pressure Factor Factor Factor IRate of Flow F F F Q MCF/D (24 Hn) Differential psia t ~ pv L 123,500" 8. 850 Coefficients .were ...calculi,ted accordin~ to 1093 2. 123,500 18.880 "Bulleti~ T.C.-561'', publi.,~hed by the California 2330 .~. 124,402 28.320 Natural Gas ASsociation ~Lnd adjusted t~ 14.65 psia. 3522 ~. 125 ~646 38. 350 ............. 4818 PRESSURE CALCULATIONS (3) P f2 2 2 P w Cal. w · ~ (p.~ia) P~ F q (F q)' (F Q): X l-e-- PW Ps - Pwf p :t C C C :~' P t XlO6' e ~ ...... -- --. 3.67 ,. ,.1,,3..5,275, - , - ~-. - ..... '3.50 298,116 - - .~. - ... - - - - 3.29 515,531 .. .- - ~. I -' .... 3.02 .. 781,856 - . - ... Al,solute Potential JIl 20 ~ 000 MCF/D 0. 868 CERTIFICATE: I, the undersigned, state that I am thru Areal' En~. of the Chevron U.. S.A. -Inc. (company),' and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts../%ta~/ t~h~re~ the best of my ~owledge. Si~ature ~1) Measured from 100"x2000.' psi'Barton Re co rde r (2) Pressures measured with bottom-hole recorder hung at 4575' and adjusted to 4288' (mpp). psia. (3) Pwf '-: Bottom-hole flowing pressure (psia) Ps = B~,,ttom-hole static pressure (psia) are tyue, 9orrect and complete to Alaska Off and Gas Conservation Commission Gas Well Open Flow Potential Test Report (4-Point Test) Form No. G-1 Authorized by Order No. 1 Effective October 1. 1958 10.0~o 010 8 7 6 5 4 1.5 ldO0 ~000 ""~ ,~;,.- ~..,~ 2 2..5 3 4 5 ,,. 7 a ~0, Chlvron U.S.A. Inc. q MCF/D ' BELUGA~ ~IVER UNIT '2'4~-34, STRING 1 4 POINT OPEN FLOW POTENTIAL ENGR. RGH DATE .1.0-79 Chevron Chevron U.S.A. Inc. P. O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 June 13, 1977 / Mr. H. Hamilton q Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Mr. Rodney A. Smith Regional Oil & Gas Supervisor Alaska Region U. S. Geological Survey P. O. Box 259 Anchorage, Alaska 99510 Gentlemen: Chevron U.S.A. Inc., as operator of the Beluga River Unit, respectfully submits the attached 2 hour isochronal 4 point open flow potential test for Beluga River Unit Well 9241-34, String #1, G Zone. The testing of this well took place during March 16 and 17, 1977. Very truly yours, Area Engineer WAB:dmw Attachment CC: Mr. C. N. Segnar, San Francisco, Attention: L. G. Eginton Mr. J. W. Hart Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Mr. P. J. Carroll Shell Oil Company P. O Box 881 Houston, Texas 77001 GAS~ ~.,~LL OPEN FLOW POTENTIAL TEST R .)RT 4-POINT TEST Test Initial. ~ Annual [~ Special Reservoir Fi eld Operator Ch~xz~c~n Tl~A Yn~. County ~lultlPle Completion (Dual or Triple) .... Strinq #1 of a triple completion Test Date 3-16 &3-17 1977 V~' ell .~o. Lease I Beluga River Unit 241-34 _ I Location J completion rote J T0tal Oepth T/~ay J ,r0du,~i.gInterval Kenai Section 34, T13N, R10W SB&M . 8,10-72 . 650~ 4732-5048 ProductnK Thru Rese~oir ~ Wellhead I CSG. Size )~vt/Ft. [ Lb. TBG. J CSG. Temperature ' Temperature ,X "F - OF 9 5/8 43.5 8.755 Bridqe Plug at 5477 (Separator) Length (E) Ha!10 MCF Per Bbl. ~ ~ Liquid (Apl) 2 7/8 6.4, 2 7/8 2.441 5235 .561 - - Pipeline Connection Type Taps Chuqach Electric AssoCiation Flange Type production from each zone Dry Gas OBSERVED DkTA ' Flow Data Time (1) (Prover) (Choke) Static - (2) Diff, Pen Bottom (3) Casing. Flowing of F'low (Line) (Orifice) Press. Temp. Hours Size Size Pen Readir!g Reading Hole pstg °F · (2) 211 R Packer ..... Hours 4.026 1.5" 5.78 3.80 2090 PaCker 108'F Hours 4. 026 i. 1.75" 5.82 . 4.85 2042 . ?~cker . 105'F Hours 14.026 2" 5.75 4.15 2014~ ........ padker ~ 97'F Hours)4 026 2" . 5.90 7.68 1716 paCke~ ' 90'F FLOiV CALCULATIONS Coeffi- Static ...... Flow Temp. Gravity Compress. Al0. cient Multiplied Pressure Factor Factor Factor Rate of Flow -~ ,:~ psia F F F Q MCF/D . (24 Hr.) by Diff. t g ~. 68690 21..q6~ Coefficients were calculaled accordinM to 1408 2. 94569 ~a.227 . "Bulletin TS 561", publist[ed bY the c~l[:~ornia ~ ~ 2504: 3. 125535~ ~2_~6~ Natural Gasoline Association and have bsen 2850 ~. 12~535 45.~12 adjusted to ]4.65'PSIA pr(ssure,base. ~' ~' ~ ~:-~ : ' 5481 PRESS[: RE CALCULA~TIONS w (psia) P" F Q (F Q)-" (F Q)-" X 1-e-s p.~ po _ p~ Cal. w , p :t c c c w c , w P ~ w P t c ~. - _ _ , - ,- 4_36R A 118 . : , _ 2. - .... 4.170 ~ ~]6 - - . 4. - .... 2.944 l_B41 - - ., , . l. Absolute Potential n 9900 MCF/D : I%[CF/D ,, area~ 52~ · CERTIFICATE: I, the undersigned, state that I am th,En(~ineer of the ~Chevr~n TI..q.A ThC. (company), and that I am authorized by said company to make this report; and that this report was pre- pared ullder my supervision and direction and that the facts staj~jed~ect and complete to the best of my know]edge. : 2 Hour Isochronal procedure. -.~nature . . Flow rate measured with 100" - 2000PSI Barton recorder. Pressure measured with ~ bottom hole pressure recorder hung at 4600' and corrected to 489~0~.. Alaska Oil and Gas Conservation Commission Gas Well Open Flow Potential Test Report (4.Point Test) Form No. G-! Authorized by Order No. I Effective October 1, 1958 ,o/. IP:,-.// I ~r ([.:[ .t;' "-~ i ON ;-' .... ]',-' .., v ,- -.. . . ..... ' -' i :, T ~ ~ ~-~ . : . _ ~ ; ......................... _~ ~ ~__ i . ' .... ' -_..r;.: :' g=. --'.-./' ' -- ' .... ~ ' - ........................................ ,, [ ...... ].' ......L ............... - ......... J ........ ........... ~._ _ . ............. ~e :Iog log paper us~ for plo~g ~e ba~ pre~s~q ~e sh~ be of at least fitr~ ~eh .ey~. . _ .'/.r; ,' :.. . _ . ................................................................ ') : ~ :Ae~.r~te of flow ~t ~d'Ogtflow}~e~tod at.'W.~._~or~g .press~e ( · .' , . "- MCF/da~)~ 14.65 p~a and.~OFC i , .................................... ~:~]-_ :- f .... : ....... '.~ ....................... - ~r r- -~ ~]: [ ( ~ .......... _ .. c:= :_-: ........ -'A52J~Z_, 2.'-~ _ · .... ,_: .................. ..... ~ .............................. 'i ........... -.- ~ -~. ,- .: ;..C~ W . ?" '~" .~:.k.. _ ........... ~__ -]' ......................... w~ead-.Press~e (~b~g ~-flow~g ~h ~b~g, eas~g ff-~ow~g ~rough cas~g.) ps!a- '; P .... -=Meter pressure; psta m ....... :W .......' ......... / ........ -.m .-L'. '_ : ':._ . r.~ .... ....... F' '=Gra~t~ eSrree~Oh' . ..... ~.. - . -- ~- - =~low~g- temperate co~eeflon . . . _ _ ~ =Shpereompres~abffi~-' fne~r ~ pv . ...................... n =Slope of bgek press~e e~e ........... GL =G mix times average producing 1.ength of flow string Note: If P cannot be taken because of manner of completion or condition of well, then P adding the pressure drop due to friction within the flow string to P . ,. t must be calculated by -s F Q and 1-e c are factors utilized in calculating the pressure drop due to friction, 0 0 I~. '0 Z ! 000 i0000 MCF/O CHEVRON USA INC. BELUGA RIVER UNIT 241.$4 STRING I "G" ZONE 2 HOUR ISOCHRONAL 4-POINT TEST iooooo Chevron Standard Oil Company of California, Western Operations, Inc. Mr. O. K. Gilbreth, Jr. Alaska Dept. of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen · P. O. Box 7-839 Anchorage, Alaska 99501 March 23, 1976 Mr. Rodney A. Smith Regional Oil & Gas Supervisor Alaska Region U. S. Geological Survey P. O. Box 259 Anchorage, Alaska 99510 Standard Oil Company of California, as operator of the Beluga River Unit, respectfully submits the attached 2 hour isochronal 4 point open flow potential test for Beluga River Unit Well #241-34, String 3. The testing of this well took place dUring February 10 through the 13th, 1976. R. M. McKinley Area Engineer WAB: j tm Attachment cc: Mr. C. N. Segnar, San Francisco, Attention: J. O. Kistler Mr. J. P. Johnson Atlantic Richfield Co. P. O. Box 360 Anchorage, Alaska Mr. F. H. Richardson Shell Oil Company P. O. Box 881 Houston, Texas 77001 Field Beluga River Operator Standard 0il Company of California [ Reservoir [?~'~-i'~';.) Ij~,,' [ Test D~te Upper Sterling 2/12 & 2/13, 1976 [Lease DiViSiON OP C'iL AND GA'3 I wen xo. Beluga ~ver Unit AN~Ci'fO~'*'~:~ 241-34 County I Location Kenai Section 34, Ti'3N, R10W I Completion Date [Total Depth T/Pay I Producing SB&M 8/10/72 6501 Interval 306'6 '-3167 ' · TBG. [ CSG. Tempera%ute ' Temperature x 68 °~ ---°F 9 5/8" 43 5# 8.755 IBridqe Pluq at 5477 ~ ~. ~' , 2 3/.8 4.6 2 3/8 1.995 2886' .555 .... Pipeline Connection Type Taps Chugach Electric Association · Flange Multiple Completion (Dual or Triple) ] Type production from each zone String #3 of Triple Completion t Dry Gas oBSERVED DATA Flow Data Gra~'ity of Liquid ( Apt ) Time (Prover) (Choke) Static Differen- Bottom Hol( Casing Flowing of Flow (Line) (Orifice) tial Pen Press. Temp. Hours (1) Size Size Pen ~_~...s..u_.r~.~e (-" ) pstg °F .. ~aa~g(2) Readin~ ..2 hours 4.026 1.250 :: 5.71 7.50 2 hours 4.026 1.750 5 72 7 82 ~ao~ ~a~k~ 67 .... ~ , ~ 2 hours ~ 4.026, 2_250 .5:77 6.58 1265 Paakar 63 2 hour~ 4.026 2 ,~00 5.83 ~ .45 12~0 Packer 62 FLOIV CALCULATIONS Coeffi- Static Flow Temp. Gravity Compress. NO. cient MU!tiplied bi' Pressure Factor Factor Factor Rate of Flow (24 Hr.) Differential psia F F F Q MCF/D t g pv ~.. ..... 46621 42.83 ..Coefficients were calcul~ted accordin~ to 1887 2. 93167 44.73 "Bulletin TS 561", published by the Cakifornia 3951 .% .. i160064 37.97 Natural Gasoline Association and have ])een .5859 ~. . 203725 31.77 adjusted to 14.65 PSIA ~lessure base. . .. . 6382 PRESSURE CALCULKTIONS P P Cal. w w (psia) F: F Q (F Q)-" (F Q)-" X I-e-s p-~ p~ -- P2 p P t :t c c c w o ~ w P x 106 x 10 ~.. ..... - - - ,_ - - 2.313 .0736 - - 2. - .... . 2.031 ,3564 - - · ~. - .... 1.600 .7868 - - .. ~. - .... 1.664 .7229 - - , , Absolute Potential n 9900 MCF/D .542 (l) (2) (~3) Area Standard Oi 1 CERTIFICATE: I, the undersigned, state that I am th,, Eflqineer oI the (company), and that I am authorized by said .company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated ther~p are true, .co'oct and complete to the best of my knowledge. ~~~ 2 hour isochronal procedure signature Flow rate ~easured with 100~ - 2000 PSI Barton Recorder P~essure-measurad with a bottom hole pressure recorder hung at 2865' and corrected to 3095' ii Alaska Off and Gas Conservation Commission Gas Well Open Flow Potential Test Report (4.Point Test) Form No. G-1 Authorized by Order No. I Effective October 1, 1958 ...... ! ......... INSTRUCTIONS . This 'form is to be used for repo~g multi-p0il~..t.:ba'ck pressure tests on.ga's wells:in Alaska, except those on-wlllch special orders are applicable. The log log: paper used for plotting the back pressure curve shall be of at least three inch cycles. N01V[ENCLATURE Q =Actual rate of flow at end of flow period at W.H. working pressure (%).-- McF/da. @ 14.65 'psia and 60OF.. P =72 hour wellhead shut.in' Casin~-(or tubing')' pressure Whichever is greater, psia O _ . · P --Static wellhead working pressUre as determined at the end of flow period. (Casing if flowing thru tubing, W tubing if flowing thru casing), psia P --Flowing wellhead pressure (tubing if flowing through tubing, casing ff flowing through casing.) psia t P --Meter pressure, psia m h --Differential meter pressure, inches 'water W F --Gravity correction factor g F --Flowing temperature correction factor- .t F -- Supercompressability factor pv n =Slope of back pressure curve GL ..G times average producing length of flow string nlix Note: If P cannot be taken because of manner of completion or condition of well, then P W W adding the pressure drop due to friction within the flow string to P . must be calculated by -S F Q and 1-e C are factors utilized in calculating the pressure drop du'e to friction. lO I0 8 6 '.1 2.5 , .+_ ._ j TANBARD OIL 'cOMPANY OF CALIFORNIA';W:O.L . . BELUGA RIVER UNIT 241-34 . ~"T"r'"~ I I/'~ Chevron Standard Oil Company of California, Western Operations, Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 J. L. Rowland / ?:; 'i /: -'-~' /.-:,,~ ,. Area Supervisor / ~/~,~, Producing Department / ' - '976 December 31, 1975 Beluga River Unit 241-34 Circulated Gas Heating System Mr. O. K. Gilbreth, Jr. Alaska Oil and Gas Conservation Committee Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: This letter is to confirm the telephone conversation on December 30, 1975, between Mr. H. Hamilton of your office and Mr. W. A. Brommelsiek Of Standard Oil Company of California pertaining to Beluga River Unit Well #241-34. We are presently installing a gas heating system that will enable us to circulate heated gas into the tubing-casing annulus to prevent the formation of hydrates in the producing tubing strings of the subject well. This system will use the gas from string #3 which produces from the Upper Sterling Sands. Because of previous mechanical problems in this well, we have not obtained an open flow potential test from this zone. We anticipate testing this circulated gas system for approxi- mately two weeks and then obtaining the open flow potential test of the Upper Sterling Zone. During the testing period, we plan to circulate +3000 MCFPD of gas which will be produced to our sales gas system at Beluga. We will notify your office when we are prepared to obtain the open flow potential test. Very truly yours, land' WAB :mld - =---~ 2~20.93' 2846.34 ' - 2853 ' 2855. -- 2864 .: 287:3.80" 3177.38~ -- 3997.37' 4004.82 ' 4008.34 4o?z'-$s - 4047.52 I i141 · ~ 4Z55'-76' o · 4394%96' ~ 4464%89' 4546.64' 4590.02 ', · . 4595.52' ' 4599.04' 4601.54" 4608.59' , 4640.82' · ' PL~ '~. 2~ E~ ~r:~ N-~0 ~. 6.39t 64 J~; ~" EL~ 8r~ N-S0 ~. --I'~ 90 ~S. 2~" Z~ 8~ N-80 ~. 2782.48' ~2 .2~" Pb~ JT. E~ 8rd N-80 .~G ~--OTIS. -~ .~ ~T.' 2%" Z~ 8rd N-SO ~G. 31. ~ '. --BR~ "CC" S~ETY ~. 1.4~~ I . - 2~"~'P~ ~..E~ 8rd ~80 ~G. 8.0.0' ~' STZN~A . -- BRO~ .HS-17 ,3C PA~R 8.33' 2- BR~ ~T~ ~ION ~ : 4 ~ JTS.. 2~" E~ 8rd N-80 ~G. 1 P~JT. ~" E~ 8rd N-80 ~G. ~ . ~ '=8. ~S; 2~" E~-Srd N-80 ~G. ~ ~D~ NIPP~ ~ 3 ~ P~ ~. E~ 8rd N-80 ~G ~ ~~ SHOE -- -- ~.~, :- :-1'~ ~":"E~' 8r~: N-SO TBG. 31;95' ~ ST~ PU~ SA}'~Y JT. -- OTIS "~". SE~ 3.52' --B~ ~~ 2~ P~ JT. E~ 8rd N-80 ~G. -- BRO~-A~T~ ~ION ~ ~ ~ P~ ~. Z~ 8fa N-80 ~G. OTIS "~" ~2 .~ P~ JT. E~ 8rd N-80 ~G ~ "D" NIPP~ ~: 1~ ~s. 2%" ~ Srd N-SO ~G 373.68' " 18.00 ' 8.03' -' '1973.84 2824.67 ' 2782.70 ' 8.10' 3.52' 31.32 ' 8.33'... 3.40' 27.77 '249.38' 10.05' 2.53' 10.10' 3.52' 10.04' 7.44' 4.40' 3.40 ' 10.75' 3.52 ' 10.50 ' .94' 2.00' 8.33' 9.70' ~92' 10.60' ' .58' , ~ :, · 10 .'I~**..2~" EUg 8rd N-80 TBG. 310,53' ~I~ NOTI~' NO. 2 STRING OF TUBING PARTED BELOW SECOND PACKER AND DROPPED TO ~ FEET. SHOE --B~0%~ "CC" SAFETY JT. ~" PUP JT. EUE 8rd N-80 TBG. SLEEVE --B~ORN H1 S~ PACKER 1 JT. 2~" EUE 8rd N-80 TBG. I--~S "S" NIPPLE, ,P. osition #4 11 JTS. 2-~" RIlE 8rd ~-80 TBG. -- CA~4CO ~.- ~IDREL I JT. 2~" Et~ 8rd-N-80 TBG. I--BROWN "CC" SAFETY JT. 2~" PS~ JT, EUE 8r~ N-80 TBG. I--OTIS "XA" SLEEVE BROWN H1-SRP PACKER 1 JT. 2~' 'EUE 8rd N-80 TBG. OTIS "S" NIPPLE, Position #3 16 JTS. 27i" EU~-8rd N-80 · 2.53' 4.04' 3.52' 7.45' 31.76' 1.60' --'CAMCO MM MANDREL 1-JT. 2J£UE 8rd N-e0 T]~G ---BROWN "CC" SAFETY JT. 2~' PUP JT. E~E 8rd N-80 TBG, ~-- OTIS "XA" SLEEVE 4¥' BTT x 2~". EUE X-OVER ~-- BROWN H-lSRP Packer -- 4%" BTT x 2%" EUE X-OVER ,: ~ -i JT. 2¥' EUE 8rd N-80 TBG. OTIS-"S"' NIPPLE, Position #2 · . '407~'-,.' 12 .JT$. 2~" EUE 8rd 1~-80 TIKe. ,4945 :4go?'-it* · ' · ' ' "i ' :4gGe'-~Z' ' ~ 5016' 24' - .5o~r ~.-5017.11 · ' " ' ..' I ' '- ~~~~ ' I . 5059 73' ~ JT;' ~' Z~ 8rd N-80 ~G. · - ' ' I ' . ~,- .~"cc."s~~. . I ~6~ 63,~ 2%- ~ ~. ~ etd i ~ so~:l~,~'- ~s .~ ~ ~! I . · ~ - ' 5077'5~,~1- BR0~ ~I-S~ PA~R ~ '- ! ' ~,--~%".~x~"l~x-o~. ' ~' :' , ~ ~T 2¥' E~ era N-80 ~.' . ~sl~F-~' ~ './I-- ~CO-"D" NIPP~ , ~ ~ s,es~o,: .' ' [ 4 JTS. ~' Z~ etd N-S0 ~SG. I [ --. 5235 00' %~NTU~ S;~E . 5 'a! ' - · ] : o[ : ~3,,'-~,' . · · ': ' ': '. ~'1 ~/1,,,,'-4, . - . - · ~ · . , . , _ . · · % .... , · . · -. . · - ' ' LO. 5 I '.' :.:.-..::-. ../. . 12.96 ' 30.47 ' 1.40' 6.05' 3.52' 7.45' 31.73 ' 1.58' 13.10t ~0.28' 1.40' 4.10' 3.52' 2.50' 7.05' 1.30' 90.93 ' 1.58' 37~,7.t' . 13;20' 29.42 ' 1.40' 4.5O ' 3.52 ' 1.30' '7;06' 1.30, 30.68 ' .96' 123.88' .67' ii BELUGA RI V E R 241.- :.'54 . CASINO i TUBING DETAILS: · "SECTION :~4,T. 13N. R.IOW. STAll)AiD. OIL '.COMPANY Of CALt[.~P. NIJ form No. p--< '"~ ....I C. r~lC I ..... .~, ~¢v. s.s0-6? STATE OF ALASKA su~Mrr n~ D~)-ICAT¢ , "" [5. A~I N~E~C~ CODE ~ J ['~C [ -'~ OiL AND GAS CONSERVATION CO~I~E~ ~ 502283_20038_00 .... [ 2 ~-.,)c. MONTHLY R ~PORT OF :DRILLING ~. ,~s~ o~s:o,-,~zo~ ,~o s~ ~.~o..' ::"?: AND WORKOVER OPERATIONS ~ ') ~:"::'::' ........ 7, IF INDIAN, A~I fEE OR TRIBE NAS~E] ~"'~' OIL ~ GA8 WELL ~ WELL OTHER ~ ')'C'~:OL} ...... ~. N~E OF O~TOR ' ' .... Standard Oil ComPan~ off Califfo~nia W.O.I. Beluga ~ve~ ) REV ~, ~B-~ss OF o~b~ .... P. O. Box 7-839 ~Chorage, Alaska 99510 241-34 .... ~ ..... S5C ~'. LOCA~ON O¢ ~¢~.L - ..... '. 898.50'S ~d 1399.19, W. from the Northeast corner, Sec. n. SEC., T.. R.,M.. ~BO~OMHO~ 34~ T13N, ~0W Seward B & M o~~ Sec. 34; T13N, ~0W Seward B & M , ..... , 13, RPORT TOTAI. ~ a~ ~T~ ~ MONTH, CHANGES IN HOLE SIZE, CASING A/WP CE1VIENTING JOBS INCLUDING DEPTH SET A/kq3 VOLU/VIES USED, ~F~RFO~L~TIONS, T~STS A_~TD I~ESULTS. FISt{ING JOinS, JD-NK I/~ HOL~ A/~D SIDE-TI{ACKED HOLE A2qI);~NY OTHER SIGNIFICANT CHAN-~ES IN HOI.~ CONDITIONS. . . July 1974 Commenced work 9:00 P.M,, July 31, 1974. Killing well with 98 pct calcium chloride water. AUI3 t9/,'!. ANCHORA6~ 14. I herebyrc~j~y ~hat tl~foreg~i~g is_[_~_)~ ~ ~ " " NOTE--~eport on this form is required for each calendar month, regardless of the status of operations, anO must ~ filed with the Division of Mines & Minerals by the [Sth of the succeeding month, unless othe~ise directed. GAS/ !L OPEN FLOW POTENTIAL TEST 4-POINT TEST Test Initial. [~ Annual [--] Special Field BELUGA RIVER Oper,'ttor ~ STANDARD OIL CO. OF CALIF., ~OT Reservoir BELUGA FORMATION Lease BELUGA RIVER UNIT Test Date 1/13/73 ¥,'ell Xo. BRU 241-34 Producing g]J~"~ '-5375' ('ounty I Location C0mpletl0nDate '] Total Depth KENAI I Sec. 34, T 13 lq, R 10 W, SB&M 8/10/72 I 6501 · TBG. [ CSG. Temperalure ' Temperature X 92°F .... ¢ 9-5/8" 43.5#/ft. 8.755" Bridge.. plug at 5477' TrG. Size I ,Vt/Ft. ' [ O.D. I I.D. { Set {~ ] Gasgravltr / Av,.Prod. I GL J ga;-Ltq,idll)'d,'ocarbon 2-7/8" 6.5#/ft. 2-7/8" 2. 441" 5402' (Sepa~, Length(b) ....... Ratio MfF__ per Bbl. Grat'ity of Liquid (Apl) Pipeline Connection [ Type Taps Chugach Electric Association _- I Flange " Multiple Completion (Dual or Triple) [ Type production from each zone String I (long string) of triple completionI Dry gas OBSERVED DATA Flow Data . ..... Time. ]' (Prover) - (Chokc) ........ ~-~atic Differential' Bottom Casing Flowing No. of Flow (Line) (Orifice) I' "Pen ^ , P&n Hole P'res3 Press. Temp. Hours Size. Size ' Readingz j Reading2 (psia) psig s~ ...... ... ....... , 2379 Packer --- !. _ 1 h~:. 4.0.26" 1'500" 5'88 f 4.i5 .. 2210 Packer " 74° ~. 1 hr. 4. 026'' 1. 500" 5.92 I 7.70 2002 Packer 650 - a. ~ 1 hr, ! ~.02'6" 2.000"" t 5.93. 5.33 ! 1876 Packer 67° .. i.a___ :~l:h.ro__i 4.02"6'"'. ' 2.000'' . 5.93 ' I 8.03 1675,. .. Packer I' 67° FLOXV CALCULATIONS .... 1 T I 1 ....... Coeffi- [ Diff o Flow Temp. Gravity Compress. Pressure Factor Factor Factor Rate of Flow 1~Io. eient X 2 psla F F F Q MCF/D (24 Hr.) Static t g ~' .: pv - ~. _. ~'8802 1 24.40 Coefficients have been c~'lculated, according., to 1679 ~. . 6954--6 45.58 "Bulletin TF.,561".publis~ed by the Califon~ia . . 3170 ~.:. 126907 31.61 Natural Gas¢,line Association and have been 4011 !a.___._126780.. 4,7.62 adjusted to.a i4'"65 'psiatPressure bas~. " 6036 PRESSI:RE CALCULATIONS P P w Cal. w 'p (psia) P-~ F Q (F Q)-' (F Q)~ X 1-e's p-~ pi __ p~ :t e c W C P ' t , c : 06w ,- w "P x 106 x 1 c ~__. ......... 4. 884 O. 775 ...... ~. -- .......... --" 4.608 1.6'51 ---'"' --- ~. --- . ......... 3.518 2.14~ ____2 " , !a_~.____~' ...... 7, 2. 804 2. 855 --- I --- Absolute Potential n 10,400 .x~cF/~.~ 0. 918 . -. 1. 1 hr. isochronal procedure 2. zFlow rate measured with a 100"-2000 psi Barton recorder. -3 Pressures measured with a bottom hole pressure bomb hung at 5415'. CERTIFICATe: I, ~e undersigned, state that I am the, S. upt, of the Standard oilr~ ' ' l ~,,~'F (company,, and ~a,I am au~or~ed by said company to m~e ~is report; and that this report w~re- pared trader my supervision ~d d~ection and that the facts stated there~ are true, correct and com~t~to ~e best of my ~owledge. q ~fl. /Z~" -~ ~ m~at~e ,(J. ~. WALKEK · / Alaska Oil and Gas Conservation Co,nmisston Gas WeE Open Flow Potential Test Report (4.Point Test) Form. No. G-1 Authorized by Order No. 1 Effective October 1. 1!)58 GAS/ _L OPEN FLOW POTENTIAL TEST ~ JRT 4-POINT TEST Test ~n~ti~ LX_] ~nnua~ CJ Special Field { Reservoir BELUGA RIVER STERLING FORMATION Operator ' ~ Lease STANDARD OIL CO. OF CALIF., W0I I BELUGA RIVER UNIT ('ounty ] Location KENAI Sec. 34, T 13 N, R 10 W, SB&M · Pr°ducinr Thru { Eesen'°tr I Wdlhead I CSG' Slze IT~G' I CSG. 'Temperature %Vt/Ft. [ I.D. { {T mPW[ ....F 9-5/S" 43.5#/ t. .8.755" Completion Date { Total Depth s/: 0/72{ 6501 Test Date 1/14/72 %Veil No. BRU 2/,1-34 T/Pay [ ]'roduclng 120' 13244'-3545 Set ~ 6500' TBG. Size I %Vt/Ft. 2-7/8"[ 6.5#/ft. Bridge plug at 5477' Gas-l,lq,id ]tydrocarb0n ] Gravity of Ratio .MCF per Bbl. l,hluid {Apt) Pipeline Connection { Type Taps _ Chugach Electric Association . { Flange AIultiple Completion (Dual or Triple) / Type production from each zone String II (middle strin$) Qf triple completiCn~ Dry ~as OBS F~RVED DATA Flow Data Time 1 {Prover) (Choke) Static Di'fferentia~ BottOm Casing Flowing .~o. of Flow (Line) (Orifice) Pen ~, I Pen lHole Pres. Press. Temp. · . Hours, Size Size Reading~ { Reading2 ! (psia)S psig °F s~ ............ t ,. --- 1732 Packer .... --- ,, !. 1 hr. 4.026'" 1'.500,, 5.90 I 6.33 ........ 1_7,20 ,,Packer 68° ~. 1 iir. 4.026" ' '~.250,' 5.94 { ' 5..29 17....09_.. Packer 64° ~. 1 hr. ~ 4. 026" 2. 250" 5.96 7.84 16..95 .... Packer 50° ~. "1 h'.r.., ! ~4.026'" 2,1','75,',0" { 6.06 ..... 6.51 16,79 , { Packer 51° ,,, FLO%V CALCULATIONS { CocCi- Diff Flow Temp. Gravity Compress. No. cient ' Pressure Factor Factor Factor Rate of Flow X F F F Q .~CF/D (~4 Hr.) Stafiic2 psiz t g Pv - ,. _69_218 } 37.35 ' Co"efficient~, have been c~lcU~ated acccrding to 2585 .~. 164491 ...3!.42 ' "'BUlle~in""T~l-561"'publis~d~Y the Ca]~ifornia : 5!69.. s. 167337 46.73' ' Natur~i' Gas(!line AsSoc'ia~ion and have !been 7819 ~'[' ' -2'69467 .~ 39,--45 ...... adJustedi"i'ot'a 14.65 psialP'reSsure ~"~je .... 1Q6.31 PRESSURE CALCULATIONS P P Cal. w w (psla) P-" F Q (F Q): (F Q)e X l-e-s po p2 _ p~ p p :t C c c w ~ W W P t x 106 x 106 c !. - ....... , .... , ...... 2,960 0.039 ..- ...... ~., ........... . ,2.92_2__, ., 0.07_.6 ....... '~-, ........ - ..... 7. .... 2 .--872 0 ._126 ...... --- ~., .... -_ ,,, ---I ,2:818 0.18~ ,, ---_ Absolute lPotential n 140, OOQ, , .~CF/D 0. 925 CERTIFICATE: I. the undersigned, state that I am tho up. t, . of the Standard 0il (company), and that ! am author/z~d by said company to make this report; and that this report was pre- Flow rate measured with.~t. 1 " 2 ' 00 - 000 psi Barton re%~~ Pressures measured with .hole pressure bomb hung pared under my supervision and direction and that the facts stud therein are t.,ry~ correct and complete to . 1 hr. isochronal procedure - ' Gas Well Open Flow Potential Test Report (4.Point Test) Form No. G-1 Authorized by Order No. I Effective October 1, 1958 X OJ ---~ :~-~',-'~-~:':--=~--::~--~i~;;q - :::[:; :1 V~:7'~';-v¥:: -t!:~! ~.r~hT[:~i:-U'"(~;,__'z:! ..~ -~ :~ ~-~i~ ~ '. '-IL I~[~',~ : r ---~ ~4---~ ~-i- I-L:--. ;~4-i-; -~H~ Hfl~':i· ~;j--t-r'r~;~f~r .... r ~ --? ;-t- -' r'l-l-~ ~ ] ~q" ir '] t'! - l:1 t.:r'l l -- ~ ....... ~-.-i- ~-+-~- - ~ ~ ~-~-+,- ~;~-':4~i ~-~--,I-~-''+ -' ~';~'"~'~tl--fl-- i--l-~ ~-q i-ff---~ ~ "i-Iii'- it?t'rt/ ~'-~ ! i' ] ,'t I ~;'r[~ -i' , , ' I , i ....... ' ', t ' I' , ' . I , , , ~, I, !',i' "-~--/ ...... ~ ~; i; IIt ~;; i ~ii ' ~'i ::~I~/~ iii ~ ;; 1 i ~ i .~ ' , , ~ i~ ; ' ~ ~ II i . , -- ' · i ' I0.0~ i ' ~ ~ L !J_~ ~. ~ ~..~_ ,,~ ~_; ,~. ,. ~ iL:~;;¢'~ - i- ~ ~- - *-~ , , , -; ,-- r-i ~ , . ' i~t.,,I]t~ --~ ;-;--~ .... ~~+ .... 4-; ..... ~"~-~--"~ :;*- ~4*i~=r~'"~''f''] ....... i-- * ...... -1"-' ..... ,-t ,* · ' ' ~ --]-?'.:: -i:.": : :~:: :;:: :: : '.:'.!!'.i;; : . , ~ ; ~ : , . ~ t . : J ! ' : ~' ' ' '~ ' ' 'l -~=~:5;'~'G~ ~:Lq:~:_:EF ]H-~.~ :~:H-~ :;7: :~:nt~:-~!:~':: !:::~' T~: :~ -r-!: ; :~ ii :~ :.lh:11~ '.~- ~- : [ ~ ~: ~ ~' ' ~ ':~ ; i'' ''' ;;4'' I · i , : i i' : '; 'l: ; ; i; :;; i ' -- ~- -~ ~.4- ~-~ ** +t~ ..... L: *--'--: ~- r- -.~-* ]'t-t-~ -:~' :~ ....... ' ' ~ '''- ¢' 'j-r 'r'~tf , , j,~ .,, it ._[_~i.t~ - , ,~ : · . . , , , ~ .... iZii~_'-~._].,;i x !A,]_..;~-~ ..... ,-~ .~..z4~;-.,] .:,'.~u.$;:, =:. + :q.; ........ '.4.. l~-,;-:~::,,~,!.;, !,t1~, ....... .~ ~-.11 -i ?~-- ~':zt_~;t_'?J~[: ::t~ {::J J: :i;:. :r~i: ::i:-:-t~.~::. ~:~'J~;~ :' ~ r ] ::_ ' ~_;:' :: ::.~i: i$[': 't:i;: :1 ;: ::;-::111:-I. ". ;" .-: :~;~ ~ ~:::--~:::-~:;-:4:?:?-;:¢.;::~:~h'!~¢;:~;~+::r;-t:~:~J:;~:~:~:~i~i~: BELUGA RIVER UNIT 241-34 i I i!ii ]!~i ~i i~. ! ; ~ii','.h] ~:iii:i',l 4-POINT TEST --F '~-~ ..... ~-t-~ ....... ~-~-~** ~" '~r ~--~,~,~-~'r-~ r,'EN6R: ~ B DATE. 1-73 I~ I0,000 ..... I00,~0 Chevron C. V. Chatterton District Superintendent Producing Department Standard Oil Company of California, Western Operations, inc. P.O. Box 7-839, Anchorage, AK 99501 · Phone (907) 279-9666 October 10, 1972 Mr. Homer L. Burrell Director, Dept. of Natural Resources State of ~s~ ............ .... 3001 Porcupine Street Anchorage, Alaska 99504 BELUGA RIVER UNIT 241-~4 BELUGA RIVER FIELD Dear Mr. Burrell: Please refer to your letter of September 29, 1972 regarding our recently completed Beluga River well BRU 241-34. We regret the delay involved in the transmittal of.the completion report, well logs and core analysis. It was not our intention to withhold this material past the due date, September 9, 1972. However, a series of extenuating circumstances occurred just prior to that date which resulted in the delayed delivery. Our technical and clerical personnel responsible for preparation and submission of these data initiated the work on August 9, 1972, but were unable to complete the package prior to both of them being re-assigned to our Marketing Department the third week in August. The transmittal form dated August 9, 1972 noted in your letter was in error, as it was intended only for the submission of preliminary field logs to our partners at that time. Following transfer of these people, previous instructions as to the due date iSeptember 9th) and responsibility for final preparation and delivery were temporarily overlooked. Though it may appear to the contrary, there was no intent to delay transmission of the data until after the State Lease Sale. The well is an infill develop- ment location and had no bearing on the sale. As you noted, we did not even mark the well as confidential. We regret the delay in transmittal of these data, and the ensuing mis- understanding as to the reason for it. We have always made every effort to comply with State directives and will continue to do so in the future. Very~..(ly y.ours, c. v. dP, T 2 1972 DM$ION OF OIL AND GAS O01 B STATE of ALASKA To: [- Thomas Marshal I Ch i ef Petroleum Geo Iog t st FROM: John Levorsen ].~/~ Petro I eUm Geo ! og i st ~ / '~ ~ / DATE : September 29, 1972 SUBJECT: Standard Oil Company of California - Beluga River Unit - 24.1-34 To the best of my recollection on Wednesday, September 20, I cai led Standard Oil Company Concerning the Monthly Report of Drilling and Workover operations (Form P-4) for this well, in the month of August, which was due September 15. I was referred to Mr. John Wilson, and discussed with him the lateness in fi ling the P-4. I also mentioned that if the well had been completed prior to August 20, a Form P-7 (Well Completion on Recompletion Report and Log) and logs should have been fi led, as well. Mr. Wilson said he would check on these reports and call back. He called back and reDorted the logs and reports were on Mr. Tinker's desk, ready for f'iling, and would'be hand delivered to our office by Mr. Tinker on Monday. He also volunteered that they were being held due to the postponement of the Alaska Lease sale. I reported the above discussion with Mr. Wilson to Tom Marshall that afternoon. Logs and reports on this well were delivered the following Wednesday, September 27. A Form P-4 was not included in the material. However, a well completion report, or history, was included, which contains a paragraph on operations conducted during August I-I0, 1972. The Form P-7 reports this well was comDleted as a shut-in gas well on August I0, 1972, which makes the 30 day filing period following com- pletion end September 9, i972. Bl~I ~4t'"~ ~ t,~ ~l.~r Fie I d Dear Mr. C~at~erton: The ~tred ~lett~ rap~ (Form mT) ~ell logs, mil hlst~ and m aiR:is e s~J'~ mil ~ere haad-dellvered to this office on ~~ 27, 19'/2' The ~letton ~ shol~ fha ~ell was ~leted as a shut-in gas ~11 ~ A~g~f I0, 19~. Therefore, pursu.~f to AS 31.05.035 all of ~ ~~ ~d lnfmt!~ ~ere due In ~ls offl~ ~ la,er ~f~r g, t~. We ha ymr fr~lttal fora dated August 9, stating +~. l~s ~m- tn ~e ~tl to us, thus If ~pears ~ l~s were aal 1 ~ te ~at date. Comaenctng August 16. I972, personnel of ~hls office had some telephone conversatl~ w-l~ varl~ of your ~~! concerning, among o~her ~rs, the )ul-reCl fJlJ.ng ~ fits material. About September 20, 1972, ~ of your pe-rson~et ¥olun~eered that delivery of the material was beJ~ ~!ayed till a~er ~he postponed lease sale. None of this ,as call~ ~-~f at~enft~ ~tl I Sep~r 27, 1972. Yo~ a~entton ts d:Irected to AS ~I.O5. I50 which provides for penalties for willful violation ~ ~ Alaska Ol ! and Gas Conservatlon Act (AS 3I). tnasm~ ~ ~ of ~ aaterlal suball~ed on ~ember 27, 1972, was mark~ ';=.f!~tlal", t h~e dl:~ed all of if ~ made public a? ~,~, m~~ ~o AS ~ I. 05.0 ~. ,. ~r L. ~rre I I rector ~;Jh ' 0 (SEE ~+E LOW) STANDARD OIL CO. OF CAL. BRU-:~41-3 - BELUGA RIVER GAS FIELD KENAI, ALASKA ENCLOSED ARE; 5" 2" PLM-W/CAL. PLM-W/CAL ' BCSL~-W/CAL. 4-ARM HRCD .~,~', I ~MHR~D]~3 · t2 5II GR-N CBL-VD CC L- PR - CFD L-GG -F -LOG CFDL-GG-CNL CFDL-GG CFDL-GG-CNL-GR OiL AND Gentlemen' Company ' Field BELUGA R IV[R GAS F J [~ , County State AL/L~KA on: $ · prints ENCLOSED ARE; Additional prints are being sent to: ~11 211 PLN-W/CAL. PLN-WlCAL BCSL ~W/CAL. B CS L-W/CAL /+-ARM HRCD /+-ARM HI;lCD prints __prints GR-N CBL-VD CCL-PR CFDL-GG -F-LOG CFDL-GG-CNL CFDL-GG CFDL-GG-CNL-GR prints prints prints prints " " ,---- I I ~'D!~' 'l "i SUBM]~ S'~'A'~ o~ ,~.,:,s~<^ ~c.' .... ~ :~,,, t ~ p,O. ~.~ 7--8~~AlaSl~. 99510 ' gl - ~, ,.o~.~,,~-..--~: ..,~,.~~o,.~ k,~O.: ~w .~,.~~--;~-~ ~~~~rP ~' %I1 I[~i ! ~.~,,~ R~,,~,~ ' . ' . ' ' E~::~~ ......... : S~, - DIVISION OF OIL AND ~ISION OF OIL AND ~A~.. · 6/]-7/'~~'. t 7/.~s/~ j 8/zo/7~ / ~o9.7'~ I 88.~' · ~ -: - - : ~ ' I ~.,~ ' · - j j How~,~Y, · ~ ~ot~om 3504 ~ j Ster1~,~,~ 'Ssnds - ~op 3'023~ . .~~g~~~~_ Bat-tom 5~75J ~ ~OTC'O · ~- -' ~ .... ~ .- ~ ...... : .,.- .. ; ....... ~ ........... 20". .-'. L: 94~ - I u*.~n t405' 1'26" I - 800 sacks i ~one .e ". ~"t~t~'~'~,.- ,.,',,-'. --m~'_'-, :.~'... , 28. PE~OP&T[~S OP~' TO PRODUC a (interval, size and number) ' ~. -ACID SiZOT. ~*/(,(C1 6~ C~,t'2N'T SQU2ZZ?..ZTC. ' SEE ATI?.ACtIMENT ."C" D.------------------~TPII INTC,7%V.~ (~,I1:); [ AM'JUN [' ,',-.ND }21;';D OF ~.i&li:['.[,~ USeD " 5 8"x ............... _Z0 3/4 -9 ./ _~ .................. : _ ~,.~-~!~ annul_ B'A~ ....................... ~~ce ~. 350 sacks o~ nea~ cement. · .~. P!~;ODUCTION DATE i'IE~/ P£~ODUCTION T ~ODUCTION ~[Ei I'fOD (Flowh~g, gaz lif~, pump~g--size and type o~ pump) ~'?,~i.7 STATUS (Prozh.icfng cr Shut-f.n j pending 4 point potential tests . ITEa'r WITNESSED BY At t-ac'~~~ ,' &Cf and all lo~s run. ' '.' "~ /, ;." ,;7~// ,' :'7"'-~ ' -: S'i'G~' "( '~'7"t/. ,-/ it i-~,''''?~f(fCf~. ~ .....'2':I~ TITLE District SUperintendent o~'n.' AuKust I1, 1972 ' ,._ · :-.-:.:" ' T .,.PT ] . . ' .. .' : . . . - -_ _ ~: ~ ....- _ __ ~.~~~ " . · · *(S~e .In~ruction~ o.d Spaces for Additional' Data on Reverse Sid,) , . . V, .'.' 7 -ES~ ,~. CASI~NG PR~SSUR~ ]CAI.Cbq_.A~E;D Oi~BBL '..~S~.. · ., ' ' . [24:~OU~ TL.~ [ . . ~l: D~Pu:~o~; ~r .fuel, rent:ed, etc. ) . - .. ' General: This form .is designed fo~ submitting ~ comp ere and correct well comple?i~n repot! end !o9 on all types of lands and leases in Alaska. item: 16: Indicate which elevation is used as retere,',;e (where ~o~ otherwise shown) for depth measure- meats given in clher sp~ces on Ibis form and ~n any Items 20, and 22:: If Ibis kc, ell is completed ~or sepa~3'c i)rnduction {rom more than one ~nlerval zone (muir,pie completion), so sta~e ~n ~ten~ 20. and in i~e,~ 22 show top(s), bottom(s) and name (s) (if any) for only ~he irtcrv.,~ ret)orled in i~em 30 Suhmi~ a separale report (page) on this form, adequately identified, for each a,Jcl,~,or~al interval to be seperateiy produce, i, show- lng the a~it:fio'nal data pertinent to such ~nterval. Item26: "Sacks Cement": Attached supplemental fecc, ds for this well shoulJ show Ihe details of any mul- · t'iple stage cementing and the location of the cementi ~g tool. .. Item 28: Submit a separate completion re~rt on this form for each interval ~o be separately produc~. (~e instruclion [or i~ems 20 and 22 above). WATEII AND SEE WELL HISTORY .'~, t"OllE DATA. A'I'i'A('It I;I~.IEI," D~_.¶,C|~IP'I'I'IONS"'~F 'I.ITrtOLOGY, POROSITY, FItACW~tK~, APP~NT DI.~S' SEE IAIELL HISTORY NAME .u J ~IEA$ I . COMPLETION REPORT - NEW WELL STANDARD OIL CO~PANY -~F CALIFORNIA, W=~'"~ _ · ,~ ~o.~.RN OP~'RATIONS, ~NC. OPERATOR ' · AREA: West Side Cook Inlet LAND OFFICE: Anchorage PROPERTY: Beluga River Unit LEASE NO.: A-029657 WELL NO.: BRU 241-34 API NO.- 50-283-20038-00 'SEP 2 7 DIVISION OF OIL AND. GA5 ELEVATION: 109.7' K.B., 88.2' ground level' A~CHO~RA~ C. V. CHATTE~TO~.I D~s~r~cS Supe~inSenden~ DRILLED BY: R. B. Montgomery Rig #33 DATE CObiMENCED DRILLING:-June 17, 1972 DATE COM?LETED DRILLING: August 10, 1972 DATE OF INITIAL PRODUCTION: Shut-in S UMM A RY TOTAL DEPTH: 6501' PLUGS: 5477' ._(Hg~!libUrt.9.n' c. ast ..i~9~i b.~ri, age pl_ug) CAS I NG: 20" cemented at 405' JUNK: None 13 3/8" cemented .at 2380' 9 5/8" cemented at 6500'.Top 112' csg. 10 3/4" Stage collar at 3512' Page 2 SUMMARY (CONT'D) PERFORATIONS: LOGS: 4 - ½" holes/ft. - 4 - %" holes/ft. - 4 - ½" holes/ft. - 4 - %" holes/ft. - 4 - ½" holes/ft. - 4 - ½" holes/ft. - 5737'-5742' (DST #1) 5584'-5594'; 5550 "5560'; & 5490 '-5500' (DST #2) 5345'-5375'; 5326'-5331'; 5255'-5271'; 5213'-5233'; and 5186'-5201' (DST #3) 3056'-3057' (Squeezed) 3023'-3024' (DST #4, WSO) 5137'-61'; 5032'-48'; 5016'-5024'; 4968'-4972'; 4907'-4911' 4875 '-4878'; 4856'-4858'; 4831 '-4835'; 4780'-4784'; 4766'-4770'; 4732'-4757'; 4499'-4503'; 4464'-4489'; 4394'-4398'; 4382'-4386' 4337'-4358'; 4259'-4276' 3939'-3943'; 3896'-3900' 3797'-3804'; 3718'-3738' 3623'-3643'; 3614'-3617' 3493'-3503'; 3450'-3462' 3334'-3340'; 3312'-3318' 3148'-3167'; 3126'-3131' ; 4215',4222'; 4184'-4186'; ; 4072'-4138'; 3963'-3968'; ; 3866'-3870'; 3818'-3836'; ; 3681'-3693'; 3657'-3663'; ; 3537'-3545'; 3518'-3522'; ; 3416'-3425'; 3405'-3411'; ; 3362'-3392'; 3244'-3283'; ; 3101'-3111'; 3066'-3096'. Schlumberger - Dual Induction - Laterotog - 408'-6500' Compensated Formation Density (F-log) - 2380~'-6505' Continuous Dipmeter - 2380'-6504' BHC Sonic - 2380'-6503' Proximity Log Microlog - 2380'-6504' Compensated Formation Density (C_.NL) - 2380'-6505~' Cement Bond Log - 615'-6451' Cement Bond Log - 2550'-3150' Gamma Ray-Neutron - 2800'-5737' Casing Collar and Perforating Record - 3000'-5250' INITIAL PRODUCTION: METHOD - Well Shut-in pending 4 point potential tests. OIL - ~ WATER - GAS - GOR DST - Formation Test #1 - 5737'-5742' DST- Formation Test #2 - 5490'-5594' DST - Formation Test #3 - 5186'-5375' DST - Formation Test #4 - 3023 '-3024' (WSO) Completion Report Well # BRU 241-34 Sec. 34 T. 13N Date Au~us~t 17~ 1972 R. 10W SB & M Page 3 June 17-23~ 1972 Spudded well on 6/17/72 at 7 P.M. Drilled 17%" hole to 415'. Opened hole to 26" from 26' to 405'. Ran 10 .joints, 407' of 20" 94#, H-40, casing. Cemented through duplex shoe. NipPled up 20" Hydril add CSO rams. Tested okay to 800 psig. Nippled up blow and kill line manifold. Tested okay to 5000 psig. Rig up mud loggers, 6/22/72. 75 pcf mud. 20" CASING DETAIL Description Above K.B. Bottom Joint incl. shoe Next 9 Joints On Hook 10 jts. incl. shoe Length · · 45'45' 361.55" 407.00' . Size 20" 20" Weight 94# 94# Grade' 'H-40 H-40 Thread Buttress Buttress K. B. Depth -2.00' 43.45' 405.00' 20"_ Cementin~ Detail .Ran 4½" D.P. and screwed into Baker Duplex Shoe. Mixed 800 sacks of Class 'G' cement with-3% calcium chloride. Displaced with 48 cu.ft, of drilling fluid. Cement in place 11:15 P.M., 6/20/72. Good circulation and cement returns to .the surface. June 24-26~ ~1972 Drilled out cement and shoe 405'-415'. Drilled ahead in 17½" hole to 2234'. Conditioned-mud for logs. Ran Schlumberger DIL 2234'-408'. Drilled ahead in 17½" hole to 2380'. Conditioned hole for casing. Mud logger started logging 6/24/72. 72-75 pcf mud. .June 27-29~.. 19,72 Ran 2390', 59 joints, of 13 3/8" 68#, K-55, Buttress casing. Shoe at 2380'. Cemented with 1705 sacks of cement. Removed 20" Hydril and CSO rams. Cut off 20" and 13 3/8" casing. Installed 12" 3000# x 13 3/8" SOW casing head. Tested okay to 3000#. Nippled up 12" 3000# BOPE, Class II~ and Shaffer Rotating head. Tested BOPE and casing okay to 2500 psig. Tested Hydril okay to 1500 psig. Tested kill and blow lines okay to 5000 psig~ 75 pcf mud. Completion Report Well # BRU 241r3~ Sec. _~4 T ._!3b[_ ....... Da t e ~u__s t__!_7 ~, ~ .!. 972 SB&M Page 4 13 3/8" CASING DETAIL DescrJ ption Above K.B. Top 57 joints Bottom 2 joints incl. float collar & shoe On Hook Le_ngth .. 2305.88' 83.91' 2389.79 ' Size 13 3/8" 13 3/8" We~.ght 68# 68# Grade K-55 K-55 Thread Buttress Buttress K. B. Deoth -9.79 cut off 2296.09' 2380' 13 3/8" Cement Detail Mixed 1420 sacks of c~ment with 1.5% gel~ by weight of water followed by 200 sacks of neat cement. Displaced with 1250 cu. ft. of drilling fluid. Bumped plug. Cement in place 3:00 P.M., 6/27/72. Good circulation throughout job. Ran 100' of 1" pipe down' 13 3/8" x 20" ann, lu~ for top cement job. Mixed 85 sacks neat cement. Cement in place at 11:00 P.M., 6/27/72. June 30~ 1972 Drilled out cement at 2367' and shoe at 2380'. Drilled ahead in 12¼" hole to 3034'. Conditioned hole for coring. 79 pcf mud. Jul% 1.-4~ 1972 Diamond cored 8 15/32" hole - Core #1~ 3034'-3054' 20' cored 18' recovery~ Interbedded very fine to fine silty sand, sandy clay, silty clay, clayey siltstone, and coal. Opened 8 15/32" hole to 12¼" from 3034'-3054'. Diamond cored 8 15/32" hole - Core #2, 3054'-3074' 20' cored 19.5' recovery 'Tpp 12' is thinly bedded very fine silty sandstone, siltstone and carbonaceous clayey siltstone, and silty clay. Bottom 7.5' is fine grain, moderately friable sandstone, gassey. Opened 8 15/32" hole to 12¼" from 3054'-3074'. Drilled 12¼" hole to 3285'. Conditioned hole for coring. Page 5 Completion Report Well # BRU 241-34 Sec. 34 T. 13N Date August 17, 1972 R. 10W SB & M · · Diamond cored 8 15/32" hole - Core #3~ 3285'-3305' Cored 20' ., 20' recovery_ interbedded silty clay and clayey siltstone with minor amounts of coal and silty sandstone. Opened 8 15/32" hole to 12¼" from 3285'-3305'. DrJ~Xled 12~" hole to 3522'. Conditioned hole for coring. Diamond cored 8 15/32" hole - Core #4.~ 3522'-3542' Cored 20' _ interbedded claystone, siltstone, and sandstone, gassey. 20' recover~ Opened 8 15/32" hole to 12¼" from 3522'-3542'. Conditioned mud for logs. Ran Schlumberger D.I.L. 3542'-2380'. Shot 30 sidewall sa~ples, recovered 26. 78 pcf mud. July 5-7~ 1972 12¼" · Drilled hole from 3542'-4320' Conditioned hole for coring. Diamond cored 8 15/32" hole Core #5,__4320'-4340' Cored 20' ..... ~~ ~ ~ ~_no_ ~ltstone and minor sand. Opened 8 15/32" hole to 12¼" 4320'-4340'. 19.5' recovery_ Diamond cored 8 15/32" hole 'Core #6, 4340'-4360' Cored 20' 18'3/4" recovery_ ~S~nd'y· silty clayston~e with thir% very fine to medium grain sand interbeds. Opened 8 15/32" hole to 12¼" 4340'-4360'. Drilled '12¼" hole from 4360' to 4585'. Conditioned hole for coring. 78 pcf mud. July 8-9~ 1972 Diamond cored 8 15/32" hole Core #7, 4585'-4605' Cored 20' 17¼' recover~ Top 7' silty, clayey sand and claystone. Bottom is predominately coal with thin. clay interbeds and medium grain sand at bottom foot. Diamond cored 8 15/32" hole .Core #8~.. 4605'-4625' Cored 20' . 17¼' recover~i Sandy siltY clay an-d[ siltstone. Minor very fine silty clayey sandstone. Thin coal bed near top. Opened 8 15/32" hole to 12¼" from 4585'-4625'. 77 pcf mud. Complet ion Report Well # BRU 241,34 Sec.. 34 T. 13N R. IOW SB & M Date August 17, 1972 . . · ¢ Page 6 July 10.-.13~ 1972 Drilled 12¼" hole 4625'-5802'. Ran Schlumberger D.I.L., Compensated .Neutron-Density, and Dipmeter logs. Ran Schlumberger BHC Sonic. Shot 30 sidewall samples, recovered 30. 79 pcf mud. July 14-16, 1972 Drilled 12¼" hole $802~-6501'. Ran Schlumberger D.I.L., Proximity, and Dipmeter logs. Ran Schlumberger Compensated Neutron-Density, and BHC Sonic logs. Shot 26 sidewall samples, recovered 23. Conditioned hole for 9 5/8" casing. July 17-18, 1972 · .. Ran 6389', 150 joints of 9-5/8", N-80 and P-110, 43.5# casing and i12', 3 .Jo~in.t$, of 10 3/4", P-110, 51t/ casing. Cemented in place with 1410 sacks of Class 'G' cement. Casing shoe @ 6500' and stage collar at 3512'. 9 5/8" CASING DETAIL Description .Above R.B. Top 3 joints ~. Cross-over Next 68 joints ~Marker joint Next 11 joints Stage collar Next 22 joints Marker joint Next 12 joints Next 5 joints Cross-over Next 28 joints Bottom 2 joints (incl. shoe & float collar) On hook 153 joints, 2 cross-overs, stage collar shoe & float collar Le~t~h . . 124.13 ' .25' 2902.86' 20.72' 475.30' 2.28' 946.83' 34.35 ' 509 .'03 ' 193.84' 40.02' 1172.77~ 88.82' 6511.20' SJ~ze 10 3/4" 10 3/4" x 9 5/8 9 5/8" 9 5/8" 9 5/8" 9 5/8" 9 5/8" 9 5/8" 9 5/8" 9 5/8" 9 5/8" 9 5/8" 9 5/8" 9 5/8" & 10 3/4 Weight_ 51# 43.5# 43.5# 43.5# 43.5t! 43.5# 43.5# 43.5# 43.5# 43.5# 43.5# Grade P-110 N-80 N-80 N-80 N-80 N-80 N-80 P-110 N-80 P-il0 P-il0 80 pcf mud. Thread '8 Rd ST&C · 8rd x 8Rd LT&C 8Rd K. B. Depth -11.20 ' 112.93 ' 113.18' 3016.04' 8Rd 8Rd 8Rd 8Rd.- 8Rd 8Rd 8Rd 8Rd x Butt. 3036.76' 3512.06 ' 3514.34' 4461.17 ' 4495.52' 5004.55' 5198.39 ' 5238.41' Butt. But t. 6411.18 ' 6500.00 ' Completion Report Well # BRU 241-34 Sec. 34 T. 13N Date August 17,.._1972 R. iOW SB & M Page'7 9 5/8" Cementing Detail Through Shoe Cemented around shoe with 385 sacks of Class 'G' cement mixed with 2.4% (by volume of water) of gel, followed by 200 sacks of Class 'G' cement. Good circulation throughout job. Cement in place at 4:13 A.M., 7/17/72. 9 5/8" Cementin~ Detail Through Stage Collar Opened stage collar at 3512'. Couldn't break ci£culation. Squeezed 375 sacks of Class'G' cement mixed with 2.4% (by volume of water) gel, followed by 100 sacks neat Class 'G' cement. Pumping pressure 800 psig. Bumped plug and closed stage collar with 2500 psig.' Cement in place at 8:15 A.M., 7/18/72. Squeeze Job #1 10 3/4"-9 5/8" x 13 3/8" Annulus Closed Hydril. Broke down formation with 800 psig at 20 cu. ft. per min. Mixed 350 sacks Class 'G' treated with 3% calcium chloride. Squeeze away at 6-800 psig with 405 cu. ft. dri21ing fluid. Final pressure 500 psig. Held pressure 7 hours. Tested 9 5/8" x 13 3/8" annulus okay to 1500 psig. ,July 19-21~. 1972 ~ Landed and cut Picked up ~w ,.. · . . v~ cas~. R~mov~ BOFE In~talled tubing head Tested secondary seal okay to 3000 psig. Nippled up BOPE. Tested okay 2500 psig. Tested kill and blow lines okay to 2500 psig. Cleaned out cement and stage collar at 3512'---and cement and float collar at 6455'. Tested ~tage collar, casing and float collar okay to 2500 psig. Conditioned mud. Ran Velocity Survey and Variable Density Cement Bond Log 615'-6451'. Schl~berger perforated 4-~" holes per foot from 5737' to 5742'. ~n Halliburton testing equipment for DST #1. 78 pcf mud. July 22-23~ 1972` Ran DST #1 on interval 5737'-5742'. Packer set at 5697' with tail at 5714'. No cushion used. Tool Assembly.: Reversing sub, drill pipe, choke assembly, Dual'~CIP valve, hydro- spring tester, top and bottom inside recorders, safety joint, packer, 5' of per- forated pipe, top and bottom outside recorders, and temperature device. Opened tool at 6:33 A.M. on 3/8" down hole bean and 1" and ½" surface beans for one hour flow period. Weak blow throughout flow period. No gas to surface. Shut in at 7:33 A.M. for a three hour seven minute final shut-in. Pulled loose at 10:40 A.M. Pulled to rise and recovered 120' of drilling fluid. Filtrate tested 27 gpg NaC1 compared to mud filtrate of 25 gpg NaC1. Charts indicates some plugging but were okay. Bottom hole temperature 90° F. , Conclusion: Test conclusive. Formation very tight. Page 8 Completion Report Well # BRU 241-34 Sec. 34 T. 13N Date Ausust ..!7~ 1972 R. 10W SB & M · · .! Recorder Depth Pressure, psig IH IF FF FSI FH Top Inside 5679' 32'52 10---7 9---8 1'508 3237 Bottom Inside 5683 ' 3242 106 105 1491 3220 Top Outside 5706' 3272 123 120 1508 3246 Bo6tom Outside 5710' 3279 120 125 1511 3255 Ran Gamma-Ray Neutron Log from 5737' to 2800'. Schlumberger perforated 4 - ~" holes .per foot from 5584' to 94'; 5550' to 60'; .5490' to 5500' for DST #2. Ran DST #2 on interval 5490' to 5594'. Packer Set at 5448' with' tail to 5465'. No cushion used. Tool Assembly: Reversing sub, drill pipe, choke assembly, Dual CIP valve, hydro- spring tester, top and bottom inside recorders, jars, safety joint, packer, 5' of perforated pipe, top and bottom outside recorders, and. temperature device. Opened tool at 3:05 A..M. on 3/4" downhole choke. Gas to surface in one minute at a low rate. Surface pressure built up to 10 psig in five minutes. Turned to 2" flare line at 3:25 A.M. with 1" bean at tester head. Brief low volume flare died in a· few minutes. (Estimated +100 MCF/D). Well headed @ 3:35 A.M. at estimated_+500 ~/~, rate, g~aaual~y died by 3:50 A.M. ShuL-in at ~,~rface no pressure bu~l~-up. Surged perforations at 4:05 A.M. Shut-in at surface~pressure built up to 80 psig. Opened to flare through meter by pass at 4:15 A.M., pressure bled down to 10 psig in five minutes with estimated maximum flow +100 MCF/D. Shut-in at surface again and pressure built up to 40 psig. Open to fl--are line again 4:25 A.M. Surface pr~essure bled almost to 0 psig by 4:30 A.M. Surged, reset, and re,opened tool at 4:37 A.M. Surface pressure built to 80 psig in eight minutes. Started 87 min. F.S.I. at 4:45 A.M. Bled down surface lines. Pulled and recovered 2680' .net rise gassey mud. Sample 'top and' bottom, tested 70 g/g salinity. No plugging. Conclusion: Test conclusive. Formation very tight. Bottom hole temperature 110° F. Recorder Depth Pressures~ ?si~ IH IF FF FSI FH Top Inside 5430' 30---77 40---0 16---03 2613 3~62 Bottom Inside 5434' 3082 385 1589 2605 3057 Top Outside 5457' 3084 380 1598 2616 3061 Bottom Out'side 5461' 3115 391 1607 2620 3101 R~n casing scraper. Stopped at 5592'. Conditioned mud. Ran 8 5/8" bit, stopped . 8~" __ at 5592' Ran a O.D. impression block. Block indicates +3/4" jagged obstruction on lip and slightly decreased casing i.D. 78 pcf mud. ~july 24 ,~ 1972 Schlumberger ran and set a Halliburton wireline cast iron bridge plug at 5477'. Completion Report Well #.. P~RTT Sec. 34 T. 13N Date August 17, 1972 R. 10W SB & M Page 9 Schlumberger perforated 4 -½" holes per foot-from 5345' to 75'; 5326' to 31'; 5255' to 71'; 5213' to 33'; 5186' to 5201' for DST #3. Ran DST #3 on interval 5186' to .5375'. Packer set at 5129' with tail to 5146'. No cushion used. Tool Assembly,: Reversing sub, drill pipe, choke assembly, Dual CIP valve, hydro- spring tester, top and bottom inside recorders, jars, safety joint, packer, 5' of perforated pipe, top and bottom outside recorders, and temperature device. Opened tool~ at 7:37 P.M. on 3/4" downhole choke, and ½" and 1" surface chokes, through by-pass in meter run. Gas to surface in five minutes (moderate rate - not "measured). Mud tc surface at 8:01 P.M. (24 minutes). Mud heading with gas. Shut- in at surface at 8:27 P.M. to relight flares; re-open at 8:30 P.M. Gas rate con- tinued to increase. Turned g~s from by-pass' through meter run at 8:50 P.M.. Initial measured gas rate - 3.72 x 10v SCF/D at 250-270 psig surface pressure. Shut-in at surface at 9:01 P.M. to relight flare; re-opened at 9:06 P.M. Surface pressure increased to' 820 psig .during shut-in. Mud continued to head with gas until 9:15 P.M. and a thi~ spray of mud continued throughout duration of flow period Final rate 4.38'x 10v SCF/D at 300-310 psig surface pressure. Shut-in well at ~0:08 P.M. for 119' minutes FSI. Pulled loose at 12:08 A.M. Recovered 20' net rise of gassey mud. Chares okay~ COnclusion'' Test conclusive, interwal gas productive. Bottom hole temperature 98° F. .. Recorder De?~h Pressuresj~ psig IH IF FF FSI FH Top Inside 5111' 28---80 2-~6 69'6 243-----3 · 2'863 Bottom Inside 5115 ' 2885 207 693 2427 2826 Top Outside 5138 ' 2897 269 716 2432 2854 Bottom Outside 5142' 2896 226 715 2433 2845 Conditioned gas cut mud at 5477'. 78 pcf mud. July .25~ 1972 Schlumberger set wireline bridge plug at 3150' and perforated 4 - ½" holes at 3056' for squeeze job #2. Squeezed 350 sacks of cement in two stages. -. ~ S~ueez.e Job #2~ 1st Stage-- Ran Halliburton E-Z drill cementer on drill pipe and set at 2976'. Broke down for- mation through perforations at 3056.' with 800 psig at 20 cu. ft. per min. Pumped 50 cu.ft, of water ahead of 215 sacks of Class 'G' cement. Squeezed away at 800- 1000 psig, with maximum pressure build-up 1400 psig. Formation broke down and final pressure was 500 psig. Cleared holes with 20 cu. ft. of water. Cement in place at 8:30 P.M., 7/25/72. Let cement set for six hours. Completion Report Well # · Sec. ~ 13N Date August 17, 1972 R. 10W _SB & M .. · Page 10" Squeeze Job #2~ 2nd Stage _ Broke down' formation through perforations at 3056' with 1200 psig. ~{Pumped away at 20'cu. ft. per minute at 2000 psi. g. Pumped 50 cu. ft. of water aheadm165 sacks of Class 'G' cement· Squeezed away approximatelyol50 sacks through perforation at 1200-1600 psig. Final-pressure 2000 psig. Cement in place at 3:35 A.M., 7/25/72. July 26~ 1972 · Ran in 8 5/8'-' bit. Located E-Z drill retainer at 2976'· Drill~ up retainer and cleaned out-cement 3076' to 3150'. Condition mud for W.S.O. test. -. schlumberger perforated 4 - ~" holes at 3023' for DST #4, (WSO).. 80 pcf mud. ~ 27~ 1972 · - . Ran DST #4 '~SO)at 302{' Packer set at 2992' with tail to 3009'. Used 1858' of water cushion. .. . ' - . hydro- Tool Assemb~_~!: Reversing-sub, drily pipe, choke assembly, Dual CIP valve, 5' of sp~ing tester, top and bottom inside r~corders, jars, safety joint, packer, perforated pipe, top and bottom outside recorders, and temperature device, · · Open~d tester at 10:46 P.M'. for 1 hour 14 minutes flow period. Immediate blow with water Cushion to surface in t~hr~e minutes-, gas to surface in seven minutes~,, Turned tO flare line at 10:57 P.M. to clean up ~<Lth 600 psig surface pressure on a~d 1" surface beans· Cut back to ½" surface bean and turned through meter run at 10:59 P.M. Flowed well at approximately 4400 MCF/D rate. Sporadic small drops in rate and in- crease in pressure, indicating possible small ice plugs forming and breaking loose. No indication of free water· Shut-in at 12 midnight for two hour FSI. Pulled loose at 2:00 A.M. Recovered 70' net rise mud (no sand). Mud filtrate from ~ise tested 26 g/g NaC1 and 105 ppm NO3. 'Mud filtrate before test was 27 g/g and 88 ppm NO3 · Conclusion: WSO good Packer failed ten minutes after start of'.shut-in period. · , ~ot'tom h°le temperature 81° F. 80 pcf mud. Recorders ~ Pressures.} psig. · IH IF FF FSI FH Top Inside 2974' 1687 722 t335 Packer 1687 Bottom Inside 2978' ~689 720 1330 failed 1689 Top Outside 3000' 1691 735 1333 1691 Bottom Outside 3004' 1705 752 1383 1705 Completion Report ' Well # BRU 241-34_ __ Sec. -~'~4 ~ T:_--j3N R. ]~W__SB a M Date._ _ -Angust 17; _1972 July 28-31~ 1972 Ran in hole to top of cement retainer. Conditioned mud. Drilled out retainer and cl&aned out to top of bridge plug at 5477'. Conditioned mud for perforating well. Sc.hlumberger perforated 4 - ½" holes-per foot, .the following intervals with 3 3/8" 'O.D. strip guns or 4" carrier guns: 5137'-61'; 5032'-48'; 5016'-24'; 4968'-72'; 4907'-11'; 4875'-78'; 4856'-58'; 4831'-35'; 4780'-84'; 4766'-70'; 4732'-57'; 4499'- 4503'; 4464'-89'. Staged in hole to 5477' and conditioned mud. Continued perforating ~t 4394'-98"; 4382'-86'; 4215'-22'; 4184'~86'; 4337'-58'; 4259'-76'; 4072'-4138'; 3963'-68'; 3939'-43'; 3896'-~3900'; 3866'-70'; 3818'-36'; 3797'-3804'. Staged in hole to 5477' and conditioned mud. Continued perforating at 3718'-38'; 3681'-93'; 3657'.-63'; 3623'-43'; 3614:-17'; 3537'-45'; 3518'-22'; 3493'-3503'; 3450'-62'; 3416',25'; 3405'-11'; 3334"-40'; 3312'-18'. Staged in hole 'to 5477' and conditioned mud. Continued perforating at 3362'-92'; 3244'-83'; 3148'-67'; 3126'-31'; 3101'-11'; and 3066'-96'. Ran perforating log 3000'-5250'. Staged in hole to 5477' with casing scraper. Scraped perforations and conditioned mud for tubing. · ' · - 83 pcf mud. ... August 1-10, 1972 .. . · Ran dually and hv~ro~=s~=d, to 6000 psmg, t%~ s~ngs.~ of 2 7/g".. ~ N-80.. 6.5i[: EUE tu~ing. 1st string at 5402' and 2nd string at 3553'.. Ran singlely and hydrotested to 6000psig 3rd string, 2 3/8", N-80, 4.7t~, EUE tubing, to 2992' . Ran 4tM string (heater) 2 3/8", N-80, 4.7.~/, EUE tubing to 2028'. Removed BOPE. Installed x-mas · tree. Tested okay to 5000 psig. Displaced well and attempted to set packers. T.riple packer leaked and cauged all packers to fail to set. Killed .well. Remqved x-mas tree. Nippled up BOPE. Tested okay to 2500 psig. Pulled strings 3 & 4. Pulled dually strings 1 & 2 to triple packer. Repaired triple packer. Reran tUbing, hydrotesting to 6000 psig. Removed BOPE. Installed x-mas tree. Tested okay to 5000 psig. Displaced well and set packers. Packers and tubing shoes as follows: Packer Depth (top) Type. Tu. bi.n..g' String Shoe Depth 2974 i Triple 1 5402 ! 3202' Dual 2 3553 ' · 3576' Single 3 2992 ' 3991' Single 4 2028 ' 4618 ' Single 5088 ' Single · Released rig at 1:00 P.M. 8-10-72, H. BROWN C~omp3[e ~J~ on Report Well # BRU 241-34 Sec. Da.te __~A~7_,. 197 2 R. 10W SB&M Page 12 Descr~tion K.B. to tubing hanger Tubing hanger Next 94 joints ~ Otis 5L~' sleeve . 1 joint ::~'. Brown "CC" safety joint :_~ Pup joint .~ Brown HS17-3C packer Pup joint Next 6 joints Brown straight pull safety joint 1 joint Ot is ' Y~; sleeve Brown RS17-2C packer Pup joint Next 11 joints Brown straight pull safety joint Pup joint Otis 'XA' sleeve Brown H1-SRP packer Otis 'S' Nipple (Pos. #4 Pup joint Next 11 joints Camco 'MMA' 1 joint Brown straight pull safety joint Pup Joint Otis 'XA' sleeve Brown H1-SRP packer Otis 'S' Nippl.e (Pos #.3) Next'lB joints Camco ' b~A' Next joint Brown straight pull safety joint L~ngth 21.50 ' .60' 2908.80' 3.21' 31.10' 1.05' 7.97' 5.95' 2.10' 183.82' 2.55' 30.36' 3.i7: 7.10' 8.08' 343.78 ' 2.53' 10.03' 2.74' 7.30' 1.57' 8.03' 337.65' 13.10' 31.60' 2.53' 10.08 ' 3.00' 7.12' 1.60' 558.78 ' 12.96' 30.54 ' 2.52' WELL BRU 241-34 TUBING DETAIL STRING #1 Size 2 7/8"x 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8"x 2 7/8"x 2 3/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8"x 2 7/8" 2 7/8" 2 7/8" 2 '7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 7/8" 7/8" 7/8" 7/8" 718" 7/8" 7/8" 7/8" 2 7/8" 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# 6.5# Grade N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 N-80 Thread EUE top & bottom EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE EUE K. B. Depth 21.50 ' · 22.10' 2930.90' 2934.11' 2965.21' 2966.26' 2974.23' 2980.18' 2982.28' 3166.10' 3168.65' 3199.01' 3202.18' 3209.28' 3217.36' 3561.14' 3563.67' 3573.70' 3576.44' 3583.74' 3585.31' 3593.34' 3930.99' 3944.09' 3975.69' 3978.22' 3988.30' 3991.30' 3998.42' 4000.02' 4558.80' 4571.76' 4602.30' 4604.82' Completion Report Well # 'BRU 241-34 Sec. 34 T. _ _"~ R. ~SB & M Date Augu. st 17 ~_~_1972 · · -. · Description. Otis 'XA' §leeve .... Brown H1--~RP packer _ Otid 'S" Nipple (Pos f/2) ~_~ Next 13 joints .~:. Camco ' MMA' .... Next jioint ' ..... BroWn straigh.t-pull '- safet'y joint :~ Pu~ joint . ~ Otis 'XA'-sleeve m:- B~own: Hi'-SRP packer -- Next joint _ . 'D' Nipple . -~ . :::-Bottom 9 joints ~:~ Shear. Sub ' . . . -o Length 10.10' 3.19' '6.41' 1,57' 401 .'8 2, 13.16" 30.80' 2.52' 9'.96' 3..16' 7.33' 31.55' .96_~ 273.92 ' :92' o. WELL ~RU 241-34 TUBING DETAIL STRING #1 (Continued) Size 2 7/8" 2 7/8"' 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8, 2 .7/8" 2 7/8" .2 7/8-. - 2 7/8" 2 7/8" 2 7/8" 2 7/8!' Weight · . 6.5# · 6.5# 6.5# 6,'5#. 6.5# 6.5# Grade N~80 N-80 N-80 N-80 N-80 N-80 Thread EUE EUE . EUE EUE EUE EUE EUE 'EUE EUE EUE EUE EUE EUE EUE EUE Page i3 K. B. Depth 4614.92 ' 4618.11' 4624.52' 4626.09 ' 5027.91' 5041.07 ' 5071.87 ' ' 5074.39' 5084.35' 5087.51' 5094.84' 5126.39' 5127.35' 5401.27' 5402.19' Completion Report / Well f! BRU 241-34 Sec. 34 T. ____~3N Datq..j AuKust. 17, 1972 _%Iiw___SB & M · Description. K.B. to tubing hanger Tubing hahger Pup-joint . - Next' 95 joints - Otis '.XA' sleeve Pup.~ j 6 int Brown HS17-3C' packer . . Brown adj. union f~ext 6 joints 2 pup joints. · o Brown straight pull safety, joint Pup' j o int Otis 'XA' sleeve Pup joint Brown HS17-2C packer n.~'Brown adj'. union · 1 jo. iht .~... Camco 'D' Nipple ~ .Bottom~.~10 joints (~ail) ..... Venturi shoe Length 21.50' .60' 1.62' 29 39 · 12'' 3.15' 8.24' 5.95' 3:74' 184.24 ' 18.13~ 2.54' 6.12' 3.17' 4.06' ' · 7.10' -. 3.11' 29.49' .93' 309.99' .67' WEL5 BRU 241-34 TUBING DETAIL' STRING f/2 Size 2 7/8:'x 2- 7/8" 2 7/8" 2 7/8" 2 7/8" 2 7/8" 2. '7/8."x 2 7/8"X 2 3/8." 2 7/8" 2 7/8" 2 7/8" I' 2 7/8, 2 7/8" 2 7/8" 2 7/8" 2'7/8"x · 2 7/8" 2 7/8" 2 7/8" 2:7/8" 2 7/8" . 2 7/8" · . Weight 6.5f! 6.5f~ 6.5# 6.5~! 6.5~ 6,5# 6.5~! 6.5# 6.5f! Grade N-80 N-80 N-80 N-80 N-80 N-80'. '.N-80 'N-80 N-80 Page'14 Thread EUE Top & Bottom EUE EUE EUE EUE' "EUE EUE EUE EUE ~ EUE EUE EUE EUE EUE EUE EUE EUE EUE ... EUE o 'K. B. Depth 21.50' 22.10' .. 23.72, 2962.84' 2965.99'' 2974.23' 2980..18' 2983.92' · 3168.16' 3186.29' 3188.83 ' 3194.95' 3198.12 ' 3202.18 ' · 3209.28' ' oo 3212.39 ' 3241; 88 ' 3242.81" 3552.80' ' 3553.47.' Completion Report / Well # BRU 241-34 Sec. 34 T. 13N Date August--~, i'~ ::~esc~iption. :-....iK. B. to tubing hanger .~ubing -hanger : . ~:.:2 pup j'o iht s ':::~ext 95 joints ..:otiS'" 'XA' sleeve'- : joiht -:':Drown J-4 latch stinger :~rown H17-3C packer..i "~am~o ,.D, Nipple z:~up .joint o :x%Jontur :i. shde Length ' 21.50' ;60' :15.94" 2901.38 '" 2'.87' 31.42' .'52' .5.95' .92.' 9.97'" .58' Re 10W SB & ,, · · WELD BRU ~41-34 TUBING DETAIL STRING Size Weight -. 2 3/8:'x " 2. 3/8" 2 3/8" 4.7(! 2 3/8" 4.7f/' 2 3/8" 2 7/8"x 2 7/8"x '2 318" '.2 3/8" 2 3/8" 2 3/8". 4.7(! _ .. Grade 'N-80 N-80 N-80 N-80 Thread EUE top & bottom EUE EUE EUE EUE · EUE top EUE EUE EUE EUE .o .. Page'15 K. B. Depth 21..50' 22.10' 38.04' 2939.42~ 2942.29'' 2973.71' 2974.23' 2980.18' 2981.10' 2991.07' 2991.65' Com~le. tion Report -Well # BRU 241-34 Sec. __3.~ ._T.__13__N_ Date A~ust..~17, R. 10W SB&M WELL BRU 241-34 TUBING DETAIL STRING #4~ HEATER STRING Page 16 Description K.B. to tubing-hanger Tubing hanger Next 64 .joints Bottom joint leveled to 45° angle ,Length 21~50' .60' 1976.42' 29.75' Size 2 3/8"x 2 3/8" 2 3/8" 2 3/8" weight 4.7# 4.7# Grade N-80 N-80 Thread EUE top & bottom EUE EUE K. B. Depth 21.50' 22.10' 1998.52' 2028.27' Page 17 DEPTM 415' 958' 1448' 2234' 3034' 3522' '4116' 4320' 4585' 5465' 5802' 6311' BRU 241-34 TOTCO SURVEYS DEGREES 1o l°30' 0o25, 0°75' 1o 1o lO25'' 1o 1o 1° 0°45' 1o Long String (#1) Intermediate String (~j2) Short String (~3) Hot Oil String (f~4) ATTACHMENT "B" TUBING RECORD 2 7/8" 5400' 2 7/8" 3554' 2 3/8" 2982 ' 2 3/8" 2000' packers @ 5084'; 4615'; 3994'; 3574'; 3200' (dual); · 2965' (triple) packers @ 3200' (dual) & 2965' (triple) packer @ 2965" (triple) no packers * NOTE: Three strings of tubing have ,been run to control production, thereby minimizing any sanding potential and enabling the exclusion of possible ATTACHMENT "C" PERFORATION RECORD 4 - ~'~ holes per foot - 5737'-5742' (DST#t) $~ 4 - ½" holes per foot - 5584'-94'; 5550'-60'; 5490'-5500' (DST~2) ~Z 4 - ~" holes per foot -_ 5345 '-75 ' ; 5326'-31'; 5255'-71'; 5213'-33'; 5186 '-5201' (DST #3) 2, 4 - ½" holes per foot - 3056''3057' (Squeezed) ~. 4 - ~" holes per foot - 3023 '-3024' (DST# 4, WSO) .~. 4 - ½" holes per foot - 5137'-61'; 5032'-48'; 5016'-5024'; 4968'-4972'; 4907'-4911'; 4875'-4878'; 4856'-4858'; 4831'-4835'; 4780'-4784'; 4766'-4770'; 4732'-4757'; 4499'-4503'; 4464'-4489'; 4394'-4398'; 4382'-4386'; 4215'-4222'; 4184'-4186';~ 4337'-4358'; 4259'-4276'; 4072'~4138'; 3963'-3968'; 3939'-3943'; 3896'-3900'; 3866'-3870'; 3657'--3663'; 3623'-3643'~ 3614'-3617'; 3537'-35'45'; 3518'-352'2'; 3493'-3503'; 3450'-3462'; 3416'-3425';. 34.05'-3411'; 3334'-3340'; 3312'-3318'; $362'-3392'; 3244"-3283'; 3148'-3167'; 3126'-3131"; 3101'-3111'; 3066'-3096 · · LOC. AT CORE Ii0. FO,~V, AT ..?/.~TAIIDARD OIL COMPAItY OF CAI. IFOR~NIA, "* I~tESTERH OPERATIOJtS~ IRC~' · --- ' GRAPHIC CORE LOG EXP-z~z DRILLER' J o CORING TIME FZ./Hn. 7 · . . · · . , · . _ .. 5J).', $~.Ty, sli ely, · . . ~ . ':' '-,.'" :..-. i ~ ' ' ' ~'- ' '~.. . ' '' '~..'~-. ,.3': ~ ~ ,~ ' '' · · ' ' . _.:...:.;- ' -. . . . ,. · . · ?. . . . ... . . . .- . . ....... ' ...... L.' ' C-:':. . } ' ": · - ' : "' _ -. .-.~ -..~'"~'>( ,'-'x':'..'.:_ -:,,... .:'-_..'~.'.. ' .'.' .'- >.'i ~:- .- .'. .... ... : ..... . . . · : . .' .' . . /". ) /4/'(-.: ,- /'.t..)-'::'.'/,^ >.~-'"ttT ': e..*""~'."~ ,/ ,,.- .* .: ,:.w.,..,:7, r *..,,,- ........ ........... 1 ...... . ¢ . .,.., .. ....:., ,,/., ,,'. ',..c' "' -' '""~." '": CUTTER READ, KltJD /,lid SIZE::?/""' COItPAII¥ LOCkT 101! ¢~£ I{0._ _ STAIIDARD OIL COHPAIiY OF CALIFORIIIA, ~'IESTERlt OPERATIOJl$, ll'l&''''-'~' · " : 'GRAPttiC CORE LOG EXP~--O2 " : CORING TIME o . . · _ LI Ti'!OLOGI C DESCR i PT I 0t{ · · · (,6 67.., ¢ · · · . -, .. DEPTH . . . · . _ . '~ ..... ::':* :." :*" -. i:" ~ TANDARD OIL COHPAtlY OF CALIFORNIA, ..': -" ~"' ' Ol{S, ~r%'""..:~" ' " ' · ,. · :L.::.," ':/,' WESTERII OPERATI · : ,*,'-:' ':'?.',:;;;;'.:-.:.,;:.-' .. i...-.,'-.;..:-', :'."."-GRAPHIC CORE LOG EXP-~:..o2 ..-,. .~- .... &, ' ""' :~ ':'..-' " -' ~.,~z/ .,z 4,/- Z 'r' r~£t~ zCe,4,~. ~P, ~. ,, --,, COHPAN¥..~*~C 0 'dELL_ ,. " Lo~,~z~o.' .~.~. ~5/ ~. fi.t~v; ~,~. /~cou~ ,' - ; o · CORE I10. -~ FROH --~ ~ ~G'~-'""- TO ........ ~---~',~'-~"- RECOVERED '~ 0 / ,STATE , · . ~ -. , ' . CORING ~T./.~. - ~ * :~*"LIT~OLOG]~ DESORIPTIO~ .'z~z Po. d! ..... COt,IPAI-IY_ . ' "' .'..,,.~.$TAI{DARD OIL CO~'IPANY OF CAI. IFORHIA '?' "' '' · . , l llC?'-'''~ ' . . ... :.¢.':Y" t/ESTERH OIERATIOIIS · · '" -'-' :""' "'. . "': GRAPHIC CORE LOG EXP-,..u2 .. ..'i. · LOCkT I 0It CO~E KO. "Z// FI)RI/AT 101t TO j$~ a _ z/L CORING rT./HR. __ _ __ . ~5" ! .. ,- . . · .. ,- · . · .! ! '°:~'~.:" '- " '.'."'"--'..-..:.-:--~',,~_$TAI{I)ARD~ ,._~ OIL COHPANY OF CALIFORNIA~_~_ · ,:'" "' .- -'" :' ' W~S~E~I[ OP[RATIn'''~,,,,~ lite,~ ~ "' ~ ...... ' "' '~ ' ' ' "~. 'GRAPHIC CORE LOG EXP-~2 .. . . · , .,' "'~' .... FIELD ! -' c~ ,o..... ~ '~o~-~~0/ ~o ~~0 / ; . .. ·;., , '. ,. . " .. . . . , . ., , , -, . '. -. . ~ ,,.. ;~ ,. ~ .. ' ~ ~ ' , .,: .:'' - , .. , , ,. · ".. ~, ' , ..-. ~, -~, ~_.-: . . , - -, .. ·" t ~ t'' - ' " - ,. CORING TIME 8-[AI{DARD OIL COMi'A/tT Ut- (;ALII'UtiNIA~ " '....-'.. · I,'IESTERI,I OPERATI O~'IS~ II{C.~,-~-, . .... ,- '" ",, ,. GRAPHIC CORE LOG EXP-i d " ..' ,,~,. Z,,~(- ~ q ,,~,_~ TS.(-. Lo r~ r~ ~'~,~?.~_ RECOVERED I,"~-. "~STATDATE. --"7,/~('"'/ 4., .% LIT~OLOGiC DESCRIPTIOti r · . ' ~ESTERlt NC ....... , . - . , . '_ . . ~, _'? .-., * ........ · ' "~'~ ~' ~ · '', '-., , ' - OPERATIO~'IS, . ..,. .. , , "i: .... : / GRAPttlC CORE LOG EXP-'" -"-" "':" """":" ' C.' ,-qo~. ' "- .-_ -'.~, ' ro,,{I,~t I OU ~_?~-,~:L.O ~ ~ .. ' - ,, · · . . · . 'CORING TIME " ' ; : · ' F*r./,r. -. ...... * .:. LITiIOLOGIC DE$CRIPTIOfl ' ,.**' · * 'i'/" .** ' i* . '.**.. .-. · · '* ~ · · '. .. . _ ., _~_~ (n-L--er ,' ~ ~c ~:t. c~ .. ":'.:,,-:'." .'.," " I I"' . II ~" ~., ,'~, . .'" .'..""" . ~-- .6-.0~1'" .'j-rlab!~., ~!55i~ ~'.5~f" '' :" '.:-'. ..:'":".. "".'." . - . . · 3~ poor qmJ~ coc~/- ¢ c. Ja~l¢,1 , . ' ~,~ c%\-a~ 'day ~;nt'*,"?~(?~de-,d -~;~rl~,-s~d:r'~ .... ,," .." ..,~.. , .. -,.~-. -; . :.. - . . ·. -. : ' .. ' ..~ -'iia,l.:~~.J (or~, .~.. co~l -f:/',.fis., sky . .: ':'..".'...;.~:-!.:;'..".,.... -..~.-, _ .. ....-......... :.::...:::,: :....:,'::':.'.:-'.: ,=,_Z .. -. o,l_d,,~,i,,.l.-' :":'.-.'-:it .:..,":' i: .::-!'.:: :. '. (;:'..'/' :' '"' ~¢ ~'o~[ _ ,ot: ~- -. ', 'i: ': '":':::~ ~-~!':"_!7:'i' :'~-':.. ":-'-:- .... . ~- ~ . ..... ~ ,, . · _ o , · ,.. '.,~.-',,, ' ,·,., ..... ,,,, ,. .. -.:.":'. :.. . ., . . Z2 (,.OCl - O,c ) ., . ....: .:.;. . . ~,~1~' . . · ' . ' '. , . · · "°' 7- ,,_..~ _ ~,~, I,5i~'d- ;~ *,--,~q,~-,~.~ .' ', :.. · '; ,, ---- _ _ ~ ,,',___,' ,,_( ,n,t~n,"4"'? ~ I )-"" ~l~):;l~- r.;,,(a,,,. ,;/,, dj ~ tI '.~, ,c.~ . : t r u.,O, r:'~^ ~ ~'"1 . __i _z J---~ "'~ I ~ ' hr,.)'& "=- ;' ' "' ' " ' "' .:z=. ~' LN.o Rcco'.t'~:¢-.-'-~ · a.,/occ, m,<d ~, ,.., ,, _ .... . . re./ ....... ,,,.,,,,,.,.,,,,, o. DEPTH · t8 ' ,,-..., i'IESTERtt OPERAT I 0l~$ ... "" / GRAPHIC CORE LOG EXP - · cormO tm£ f."'; i LITtlOLOGlC DESCRIPTION rt./Hr. ' .- · .'..'::..... :.:: .' ,. . . · :..- ..... .' ..:;,.:.. - ... :'.-: :;!. :....'.-:.:.",:.,':;::,!.....- t . ....... :".', '.,' ';/ "'CORE LABORATORIES, INC. '""" ' """' "' '-' :'":'* ' : ...... :""_ ' Petroleum Reservoir £ngineering ~mpany gTANDARD_DJ3._[IO- OF CALIF. L:'~Vell BELUGA RIVER_UNTT Y}241-34 _.~eld ~unt¥ .... KEN. AI ' State ALASKA --::T.ocation · 'DALLAS, TEXAS · · Formation Cores RUBBER SI.RIVE Drilling Fluid ..... Elevation Remarks , CORE ANALYSIS RESULTS (Figures in I~rentl~ese$ re[er to [oolnole rem~r]ts) -' ' · : ,' -;.,?: , '.-:'~ ';.L:-, .'~' · ~,,,, ,; ; . '. f. ,.:." . . - , · . Page~ of File. ~P-~-~6~ Date Report 7-5 - 72., Analys~ ~R '"' ' PERM'EAI~iLITY RESIDUAL I 7~'- 8&MPL~ DEPTH MILLIDARCYS POROSITY SATURATION PROBABL~ :¥~=-NUMEIER FEET J PERCENT O --~'L--e J TOT*L PROOUCT,ONwATER R~MARK' HORIZO~AL, VERTICAL ~ VOLUME ~ PORE ~ PORE ] , , , , , _ ::. COILg #1 w3 3034-35 1.7 3035-36 3.6 3036-37 402 3037-37.5 55" 3037.5-39.5 8 ' 9 ........ 10 ........ 11 ..... L ....... 13 :.:.. 15 L.. 16 2:-17 : COAg #2 3039.5-40 13 3040-41 9 .'4 3041-42 0.6 3042-43 110' 3043-44 1.3 3044-45 O. 6 3045-46 1.6 3046-47 0.5 3047-48 3.8 3048-49 41 - · 3049-50 11 3050-51 6.4 3051-52 3.4 ' 19 ....... 21 ...... 22 .... ;25 :.~.26 27 :28 ;30 3054-55 67 3055-56 I 86 3056-57 184 : 3057-58 -2980* : 3058-59 8, 3059 -60 i1110, 3060-61 4.1 3061-62 470* 3062-63 63 3063-64 17 3064-65 64 3065-66 775 3066-67 310 .35.2 34.3 -31.8 31.0 30.7 31.6 '26.3 27.4 -26.6 27.0 30.8 . · .. ss,{fg,stlty,cly,no flu. do ss,vf-fg,no flu. sltst,sh part.no flu.*HF shale ss,vf-fg,sh, part.no flu. ss',vfg,silty,no flu. s'ltst~sandy,no flu. ss,vfg,silty,cly,no flu. *HF 'ss,vfg,cly,sh part.no flu. ss,vfg,silty,cly,no flu. ,do ' - ss,vfg,cly,sh.part.silty,no flu. . . · ss,vf-fg,cly,no flu. . . . .. ss, f-mg,cly,no flu. · Ss,vf-fg,.cly,no flu. .' _ . 23.0 23.9 24.4 24.2 17.9 20.4 19, 6 22.5 23.5 23.5 34.1 35.9 35,9 . . - '.-..-..,. ss,vfg, silty,no flu. - ..... .. ~s,vf§,silty,sh part.no flu. FULL DIA~ZTER SAMPLES #18 thru ~27 '= I · ss,vfg,silty,no flu. *VF ss,vfg, silty,no flu. ss,vf-fg,silty,no flu. *VF ss,vfg, silty,no flu. ss,vfg,silty,no flu. *VF ss,vfg, silty,no flu. do ss,vf-fg, silty,no flu. ss,vf-fg,no flu. ss,vf-fg, silty,no flu, , REFER TO ATT^CHED LETTER. {t~} OFF LOCATION ANALYSE~--NO INTE~RPRKTATION OF RESUL. T~. INCOMPLETE CORE RECOVERY--INTERPRETATION RESERVED. ~le~ analy~es, opinions or Interp~tations are bas~ ~ ob~atl~s and materials supplied by ~e client ~ whom. and f~ wh~ exeh~ve and confident~ use, this rci~rt Is made. ~xe Interp~tatlona or ol)inh~3s expre~ ~pres~t the best Ju(tKment of C~e l~boratortes, Inc. (all e~m and ¢ept~): but Core ~boratories. Inc.. alld its officers illld emtdov~s, a~tul~e no ~llsibililY alld n~ke t~n wnrrnntv nr ~nre~l~intl~mm. ns In ~e t)r~iucUvltv. STANDARD OIL CO_ OF CALIF. · BELUGA RIVER UNIT #24]-34 DEPTH FEET · ~ CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS · State .... ' ,, Formation, Cores .Drilling Fluid Elevation Remarks CORE ANALYSIS RESULTS (Figurer i. pdre.theseJ reter to footnote re,~ar4s) POROSITY ] PROBABLE: PERCENT I nil_ 1 TOTAL I PRODUCTION --'- dL ---- IWATER I .i% VD,UN,, ,o--! % ,o, ,, :2 38 :139 --.40 :--41 ~--42 CORE #2 cont. 31 3067-68 183 32 3068-69 477 33 306%70 2405 34 3070-71 1725 '_-.':-35 3071-72 -443 36 3072-73 222 37' 3073-73.5 153 CO~ #3 · 3288-3300 3300-01 3301-02 3302 -03 - 3303-04 3304 -05 ~_~43 . 3305-0~ CO~ ~ -1.9 1..0 35 0.6- 6.8 · . .. ,..;~;+..:,,,:~;..,.:: ..:..:..'.,. . :i "'"'i'"' '"" :"':':" ~':'" '"" ":" '::; '..;""' ':- .. r..~., :~ :" :: '"'.,.. ''''~'. ';~' ';' ':' ":" · ,. · '~ ' "i.~' :.' · Page 2 , ,. of File BP-3-265. Date Report . Analysts REMARKS 34,7 ... se,vf-fg, silty',no flu. - '36.3 ' ' ' do '.'. .... -- .35.1. 37.9' 28.4 30.8 -o · . . '.~ 34.1 do -. . : ~ ' . "- :. - ('5:: : .......... ~-:" ................... .... ::... .... : :. -.. :. : 7' '.-- ' .... ,, . :,.-. .'.-::- . , '..'.....-'!.: -. . - ..-.... - . .- . . ~' ..:. .'. '.. - . .- . :' . '.. . . . . · . ~. -:' 25.3. " 5.8 . 31,4 .- . . * 33.1 ' :-32.4 ... 32,0 - ' ', ......... 33.7' ,.: :'"'~'?.:_'.'.,'. - .i":' .'"' ': ' 5.1 ·- 22.6 .. 77 -' 26.8 ss,vf-fg, no flu. .. do 5...-. ' ,.' ss,vf-f,g, silty,no flu. · 3522-24 /:4 3524-25 . -" ·3525-27 -2-45 3527 -28 ,'-- 46 3528-29 146 3529 -30 "-±47 3530-31 1.6 :.--48 3531-32 4.'5 :' .=49 . 3532-33 263 ii:SO 3533-34 328 .... 51 353/+-35 457 ::~52 3535-36 1.6 ' - 53 ' 3536-37 42 · ::,i,~' 3537-38 2640* .,L.55 3538-39 56 _ .- 56 3539-40 . . . 28.1 23.1 24.6 26.0 27.9 27.9 24.0 ' 26.5 27.2 2 .8 14 26.0 NOTE; .sltst&shale interbedded ss,vfg,silty,no flu. do ss~f-f§,siltstone lam. no flu. ss,vfg,silty,no flu. ss,vf-fg,sltst, lam., no flu. do ' · '::<."'.-" ' '-- ' '.. ' . · shale ss,vfg,sltst&shale lam. no flu. silts tone, sha ly ss, f-mg,no flu. do '.:: :. ':;., - . ~ t1~ s t;one ) shal7 ss,vfg,sltst&shale lam. no flu. sltst, ss&shale lam. no flu. ss/f-rog, no flu. do do sltst, ss&shale lam. no flu. ss,vfg,silty, no flu. ss,vfg,sltst&shale lam. *HF ss,vf-fg,sltst&shale lam. ss~vf-f§~silty, no flu. · REFER TO ATTACHED LETTER. "' ": (2) OFF LOCATION ANALYSES-NO INT£RPRETATION OF RESULTS. INCOMPLETE CORE RECOVERY--INTERPRETATION RESERVED. *J31ese anal)'ses, opinions or lnte~tatlo~ are bfls~ ~ ob~rvatlons and mnterlflh supplied by the client to whom. and for wh~ excl~dve and cnnfldentbl U~l t~}s ~cp~t Is p~de. ,q~e In?rp~tatlm~s or opinl~s exprei~ ~present the best Judl~ent of Core I.aboratorles. Inc. (fill ermm and m.i~mttq ex- eept~l; ~ut <ore ~Dorator~es. inc.. and its offlce~ and etnplov~s, a~t~e I~o ~spo~siblllty and make no wa~aK'v or I~premntntl{m~ as to the pr~ucUvlty. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS .~ . . Formation Page- ~ . of Cores File BP-3-265 Company STANDARD OIL CO. OF CALIF. Well__ BELUGA RIVER UNIT ~241-34 Field Drilling Fluid Date Report County State Elevation , Analysts ' Location Remarks CORE ANALYSIS RESULTS (Figures in parentheses refer to footnote remar]t$) L PERMEABILITY RESIDUAL SAMPLE DEPTH M ILLi DARCYS POROSITY I SATURATION LE NUMBER FEET [ PERCENT OIL [TOTAL ' ~IONIWATER REMARKS HORIZONTAL VERTICAL 0/0 VOLU,~E % PORE % PORE DENS]~7¥j , ,, , , CORE #4 57 3540-41 57 26.0 58 3541-42 52 25.2 ss,vf-fg, no flu. sltst, ss&shale lam. no flu. .... SIDEWALLS 59 2448 60 2457 61. 2772 62 2786 2860 63 2914 2990 64 3022 65 3081 66 3104 67 3163 3212 3265 68 3314 69 - 3337 70 3380 71 3407 72 3420 73 3460 74 3498 326 33.3 417 29.0 418 ' 28.1 279 24.3 855 30.9 113 34.5 216 33.7 230 31.2 156 35.2 39 34.0 63 34.2 452 31.1 168 32.5 '91 35.1 140 33.5 54 31.1 2.64 2.68 2.69 2.68 2.64 ss,vf-fg, no flu. ss,m-cE,silty, no flu. ss,f-cE,silty, no flu. ss,m-vcg,peb,s£1ty, no flu. coal ss,f-mg,silty no flu. coal ss,vf-fg, no flu. ss,f-mg, no flu. Ss,vf-fg,s£1ty, no flu. ss,vf-fg,no flu. coal ss,vf-fg. Ins. Sample sltst, ss&shale lam. no flu. ss,vf-fg, no flu. ss,mg,silty, no flu. ss,f-mg,silty no flu. ss,vfg, no flu. ss,vfg,s£1ty no flu. ss,vf-fg, no flu. NOTE: ( ~ ) REFER TO ATTACHED LETTER. ¢ 2) OFF LOCATION ANALYSES~NO INTI~RPRETATION OF RESULTS. ¢ I ) INCOMPLETE CORE RECOVERY--INTERPRETATION RESERVED. These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best Judgment of Core Laboratories, Inc. (all errors and omissiomq ex- cepted); but Core Laboratories, Inc., and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operation, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. Company_ _ Well_ __ Field County , Location CORE LABORATORIES, INC. Petroleum Reservoir Engineering. DALLAS. TEXAS STANDARD OIL CO. OF CALTV. .. BELUGA RIVER UNIT #241-34 Formation Cores Page 4 .... of_ File BP-3-265 .Drilling Fluid State Elevation , Remarks CORE ANALYSIS RESULTS (Figures in parenlhe, ses refer to ,footnote remark.:) Date Report Analysts L_ PERMEABILITY RESIDUALI SAMPLE DEPTH MILLIDARCYS POROSITY SATURATION J PROBABLE NUMBER FEETl I PERCENT ~liO,~ I TOTAL '/ PRODUCTION R E M A R K $ HORIZONTAL ¥£RTICAL ~,VO, LU~4'E-! , , CORE #5 4320-22 75 4322-23 76 4323-24 77 4324-25 4325-29 78 4329 -30 4330-32 79 4332-33 4333-35 80 4335-36 81 4336-37 82 4337-38 83 4338-39 84 4339 -40 101 27.1. 71 26.5 270 27.8 28 1'6 182 350 331 31 17.0 1.0 17.9 CORE #6 ' 85 4340-41 7.6 86 4341-42 9.6 4342 -45 87 4345-46 2.6 88 4346-47 13 89 4347-48 2.9 90 4348-49 10 91 4349-50 18 92 4350-51 8 .'8 93 4351-52 64 94 4352-53 73 95 4353-54 267 96 4354-55 7.7 97. 4355-56 17 98 4356-57 9.3 4357 -59 24.6 23.7 23.9 23.3 26.9 21.3 21.6 16.7 21.3 18.5 20.8 23.0 . 20.6 23.4 22.6 25.6 21.7 21.9 22.5 interbedded sltst&shale ss,vfg,silty,cly,no flu. do ss,vfg,cly,sh.part.no flu. interbedded sltst&shale ss,vfg,silty,shaly,no flu. sltst,shaly ss,vfg,stlty,shaly,no flu. interbedded sltst&shale ss,vfg, intbed sltst&shale do do ss,f~mg,intbed sltst,no flu. ss,vf-fg,.no flu. ss,vfg,sltst&shale lam. no flu.. do sltst, shaly. ss,vf--fg,silty, no flu. do d© do do do ,vf-fg,silty,sh.lam. no flu. ,vf-fg,silty,no flu. ,vf-mg,silty, no flu. ,vf~mg,silty, sh.lam, no flu. ,vf-mg,silty,sh.part. no flu. ,vf-fg,silty,sh.part. no flu. sltst.shaly. NOTE: ! * ) REFER TO ATTACHED LETTER. (2) OFF LOCATION ANALYSES-NO INT~'RPRETATION OF RESULTS. ( I ) iNCOMPLETE CORE RECOVERY--INTERPRETATION RESERVED. These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and cox~fldenttal use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions ex- cepted): but Core Laboratories. Inc.. and its officers and employees, assume no responsibility and make no' warranty or representations, as to the productivity, proper operation, or profitableness of any oil. gas or other mtneral well or sand In connection with which such report is used or relied upon. CORE LABORATORIES, lNG. Pelroleum Reservoir Engineering DALLAS, TEXAS Company STANDARD OIL CO. OF CALIF. Page Formation Well ~' BELUGA RIVER UNIT #241-34 Cores. s!DEWbLL~_. ..................... File. BP-3,265 Field Drilling Fluid Date Report County ........ State .................. Elevation . _ . Analysts, Location Remarks P&P BOYLES LAW CORE ANALYSIS RESULTS (Figures in parentheses re/er to /oolnote remarks) PERM EABILITY RESIDUAL .~AI~PLE i DEPTH MILLIDARCYS POROSITYISATURATION ..... l~llf~lLJ,'l~LE R E M A R K $ HORIZONTAL VERTICAL % VOLUME % PORE % PORE SIDEWALLS 99 2814 100 29 70 101 3640 102 3720 103 3801 104 3835 105 3868 106 3941 · 107 39 64 108 4097 109 4130 4150 110 4218 111 4262 112 4272 113 4385 115 -/~->-~48 116 4785 117 4928 118 5038 119 5148 120 5257 121 5350 122 5370 123 5490 124 5549- 125 5596 126 5705 127 5742 143 235 66 0.5 125 13 249 21 19 -4.2 277 - 305 96 6O5 206 3.1 152 15 30 23 68 5.9 .. 11 141 88 33 18 160 16 31.7 30.6 28.2 27.7 28.7 24.7 27.7 26.3 25.9 28.0 29.3 28.4 29.4 27.6 28.1 24.6 26.8 25.2 24.8 23.7 25.0 24.2 22.4 22.9 23.6 22.8 22.0 25.6 20.6 2.65 2.68 2.64 2.51 2.69 2.62 2.65 2.69 2.69 2.69 2.73 2.66 2.68 ss,vf-fg,silty,no flu. ss,vf-mg,silty, no flu. ss,vf-fg,silty, no flu. ss,vfg,V-silty, no flu. ss,vf-fg,silty,carb.part.no flu. siltstone,Interbedded ss,vfg. ss,f-mg,no flu. ,ss,vf-fg,silty, no flu. ss,vfg,silty,Intrbed.sh.lam, no fl siltstone,V-sdy,no flu. ss,f-mg, no flu. coal ss,f-mg,sh.part, no flu. ss,vf-fg,silty,sh.lam, no flu. ss,f-mg,silty,coal part. no flu. do ss,vfg,silty, sh.lam, no flu. ss,vf-mg,silty, sh.part, no flu. ss,vfg,silty, sh.lam, no flu. ss,vf-fg,silty, no flu. do ss,vf-fg,silty, coal part.no flu. ss,vfg,silty, no flu. ss,vf-fg,silty, no flu. ss,vf-fg,silty,coal part. no flu. ss,vf-fg, no flu. ss,vf-fg,silty,no flu. do ss,vf-mg,silty, no flu. ss,vf-fg,silty, no flu. NOTE: ( ~' ) REFER TO ATTACHED LETTER. ( 2 ) OFF LOCATION ANALYSES--NO INTkRPRETATION OF RESULTS. ¢ I ) INCOMPLETE CORE RECOVERY--INTERPRETATION RESERVED. These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom. and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions ex- cepted); but Core Laboratories. Inc.. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operation, or profitableness of any oil, gas .or other mineral well or sand in connection with which such report Is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS Company STANDARD OIL CO. OF CALIF. Formation Page 6 Well BELUGA RIVER UNIT #241-34 Cores ,, File, BP-3-265 Field Drilling Fluid Date Report County State , Elevation Analysts, Location Remarks CORE ANALYSIS RESULTS (Figures in parentheses re[er lo /ootnote remGrlts) ~L PER M LAB I L ITY RES i DUAL SATURATION SAMPLE DEPTH M I LLI DARCYS POROSITY PROBABLE NUMBER FEET I PERCENT OIL [ TOTAL' PRODUCTION I I WATER HORIZONTAL VERTICAL % VOLUME % PORE % PORE CORE' 128 4585-86 1.9 129 4586-87 27 130 4587-88 14 131 4588-89 44 132 4589-90 2.6 4590 -02 133 4602 -03 14 CORE #8 4605-14 134 4614-15 8.7 135 4615-16 9.0 136 4616-17 21 137 4617-18 3.2 138 4618-19 22 139 4619 -20 14 140 4620-21 0.6 141 4621-22 4.8 142 4622-23 4.8 19.6 23.2 22.1 22.4 23.5 20.2 21.4 24.1 22.1 21.9 22.1 23.1 21.8 24.8 20.7 ss,vfg,v-slty,cly,carb.part. do do do ss,vfg,v-slty,cly,carb.lam. Interbedded sltst.& shale. ss,vfg,slty,cly,carb.lam. Interbedded sltst.& shale. ss,vfg,slty. ss,vfg,slty,carb.lam. ss,vfg,slty. do ' do ss,vfg,slty,carb.part. 'ss,vfg,v-slty. ss,vfg,slty,carb.lam. ss,vfg,slty. $ I DEWA LLS 143 3662 61 27 . 1 144 5158 3.9 22.0 145 6003 6.9 21. O 146 6285 24 22.5 147 6453 15 19.0 148 6483 49 23.0 ss,vfg,silty,clay,no flu. ss,vfg,v-silty,clay, no flu. ss,vfg,silty,clay, no flu. do ss,vfg,v-s£1ty,clay, no flu. ss,vf-fg,silty,clay,coal part. NOTE: ( * ) REFER TO ATTACHED LETTER. ( ~* ) OFF LOCATION ANALYSES-'NO INTI:'RPRETATION OF RESULTS. ( $ ) INCOMPLETE CORE RECOVERY--INTERPRETATION RESERVED. These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom. and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions ex- cepted); but Core Laboratories. Inc., and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operation, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied uoon. ~ No. P-~ STATE OF ALASKA svB~crr IN DLTPLICA'I'I~ ~ ' DI ~. 9-~0-~: s. APl N~EmC~ CODE OIL AND GAS CONSERVATION CO~I~EE 50-283-20038-00 ~'i:~ ~''' EN~'ENG~ MONTHLY REPORT OF ~DRILLING AND WORKOVER OPERATIONS A-02~6~7 --.~ . . W~LL W~LL OTHER :. ~'OF O~TOR ' ~, ~T,F~ OR LEASE ~ ST~D~D OIL OF CALIFO~IA W. 0. I. Beluga River P. O. Box 7-839 Anchorage, Alaska 99510 B~U 241-34 B~luma River 898, 50' South and 1399.19' West of Northeast n. s~C..o~~ ~'' ~'' ~" (~o~o~ ~o~ ............... SEC corner See. 34, ~13N, R10W SB & M CONFER: See. 34, T13N, .~, SS"~ t~. P~IT NO. 7z-zf , , 13. REPORT TOTAL DKPTH AT END OF MONTH, CI-IANGF-,S IN HOLE SIZE, CASING AND CEMENTING JOBS I SET A/XFD VOLLrlViES USED, PERFORATIONS,TESTS A/xFD RESULTS, FISHING JOEMS, JLrNK IN HOLE A_ND SIDE-TRACKED HOLE AND A/YY OTI-IERSIGNIFICA/~T CI-IA-N~S IN HOL~ CONT)ITIONS. JULY, 197 2 ..~ July 1-4, 1972 Ran 6 3/'4" core barrel and cut core #1; 3034' - 3054'. Opened hole from 8 15/32'" hole to 12 1/4" from 3034"-3054'. Cut core #2; 3054' - 3074'. OPened 8 15/32" hole. to 12 1/4" from 3054' to 3074'. Drilled ahead to~3285'. Cut core'#3; 3285' -3305'. Opened 8 15/32" hole to 12 1/4" from 3285' t.o 3305t. Drilled .ahead to 3522'. Cut core #4; 3522' ~ 3542'. Opened 8 15/32" hole to 12 1/4" from 3522' to 3542'. Conditioned hole for logs~ Ran Schlumberger DIL log from 3530' to 2380'. Shot 30- sidewall samples, recovered 26. July 5-9, 1972 Drilled ahead in. 12 1/4" hole 3542" -4320'.. Cut core #5; 4320' - 4340'. Cut core #6; 4340' --4360'. Opened 8 15/32" hole to 12 1/4" ' Drilled ahead to 4585'. CUt core #7; 4585' - from 4320' - 4360 .14605, _. 4625'.. Opened 8 15/32" hole to 12 1/4" 4605' and core #8~ from 4585' - 4625~ Drilled 12 1/4" hole to 5170' July 10-16, 1972 Drilled ahead in 12.1/4" hole to 5802'. Conditioned mud for logs. Ran SchlUmberger DIL, Compensated Neutron Density~ Dipmeter, and BHC Sonic Logs'from 5802' to 2380'. Shot 30 sidewall samples recovered 30 Drilled ahead in 12 1/4" hole to 6501'. Conditioned mud for logs Rmn SchlUmberger DIL, prOximity,' Dipmeter, Compensated eu ron S ot recovered 23. Conditioned hole for 9 5/8 "casing."" '%:' ~?~,~ .~ [}~ il--,~ S~GN~D ~. v~ bt~atLter~on'- TITL~ District Supar~ntand~n~A~ 'A~gust 8. 1972 NOTE--Report on this~ form is required for each calendar month, regardless of the status of operations, ancl must be filect in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Monthly Lessee's Report Well ~,~ .BRU,...241-34 _ Sec.... ~.4 .... ~T....13N Date. Augu. s.t 8.' .19.7.2 R. i0W SB6~! July 17-23, 1972 Ran 6389' 9 5/8", N-80, 43.5#, casing and 112', 10 3/4", P-110, 51#, casing Cemented w/585 sx. ; around shoe and 475 sx. through stage collar at 3512.' Squeezed 350 sx. cement down 10 3/4" - 9 5/8" x 13 3/8" annulus. Landed and cut casing off. .Removed BOPE. ~Installed tubing head. Tested okay to 3000 psig. Nippled up BOPE. Tested okay to 2500 psig. Drilled out cement at 3521' and 6449' to 6455'. Tested casing okay to 2500 psig. Ran Schlumberger Variable Density CBL. Ran Seismic Velocity Survey. Ran Schlumberger and perforated 4 - 1/2" holes per foot from 5737' to 5742'. Ran Halliburton test equipment for DST #1, set packer at 5697'. Opened tester had light blow throughout test no gas to the surface. Pulled test tools. Had 100' rise of drilling fluid. Tested tight. Ran Schlumberger Gamma Ray- Neutron Log from 5737' to 2800'. Schlumberger perforated 4 - 1/2" holes per foot from 5584' - 94', 5550' - 60', and 5490' - 5500'. Ran Halliburton test equipment for DST #2, set packer at 5448'. Gas to surface in 1 minute at a low ~olume. Maximum rate estimated at 500 MCF/D ~through a 2" flare line and 1" surface bea~. Shut-in surface pressure built up to '80 psig in 5 minutes. Surged perforations several times and bled off pressure. Pulled tester recovered 2662' of rise, all gassy mud. Tested tight. Ran in w/ bit and csg scraper. Stopped at 5590'. Ran in w/ 8 1/2" 'OD block, indicated 3/4" + obstruction on lip. Schlumberger ran and set cast iron bridge plug at '5477'. July 24-26~ 1972 Schlumberger perforated 4-1/2" holes per foot from 5345'-75', 5326' - 31', 5255'~ - 71", 5213' - 33' and 5186' - 5201'. Ran Halliburton test equipment for DST #3, set packer at 5129'. Gas to surface in 5 minutes. Mud to surface in 44 minutes. Stabilized flow rate for last 45 minutes of test 4500 MCF/D with 300-310 psig surface pressure. Well producing a thin spray of mud during test. Recovered 20' net rise of gas cut mud. Test conclusive. Ran in and conditioned mud. Schlumberger ran and set wireline bridge plug at 3150' and perforated 4 - 1/2" holes at 3056'. Ran Halliburton E-Z drill cement retainer on drill pipe and set at 2976'. Halliburton broke down formation at 3056' with '800 psig. Mixed and squeezed 215 sx. cement through perforations at '3056~. No buildup. Cleared holes w/20 cu. ft. water. Let cement set 6 hrs. Broke down formation with 1200 psig. Mixed and squeezed 150 sx. cement through perforations at 3056'. Final pressure 2000 'psig. Drilled out E-Z drill retainer at 2976' and cleaned out cement to 3150'. July 27-31, 1.972 Ran Schlumberger Variable Density CBL. Perforated 4 - 1/2" holes at ~il ~'~ i~~'~ '~3'. Ran Halliburton test equipment for DST #4, a WSO test. Set ~ ii$ ~ ~kers at 2992~''~ Used '1858' of water cushion. Opened tester. Fluid ~jsurface in 3 minutes. Gas to surface in 7 minutes. Turned well to ~QTQ meter. Gaused well at 4400 M/M on 1/2 bemm with 850 psig surface ~ pressure. Pulled packer. Recovered ~70' rise of mud. Test conclusive, Well ?~ BRU 241-34 $~c. 34_ T. 13N D.atc AuB~_sA__8~ 1_ 97__2 WSO ok. Ran in hole. Tagged cement retainer at 3150'. Conditioned mud. Drilled out retainer and cleaned out to 5477'. Rigged Up Schlumberger and perforated with 4" carrierguns and'3 3/8" strip guns, 4 - 1/2" holes per foot, the following intervals: 5161' - 37'; 5032' -48'; 5024'-16'; 4972'-68'; 4907-4911; 4875'-78'; 4856'-58'; 4831'-35'; 4780'-84'; 4766'-70'; 4732'-57'; 4499'-4503'; 4464'-89'. Ran in hole and conditioned mud. Continued perforating at 4394'-98.'; 4382'-86'; 4215'-22'; 4184'-86'; 4337'-58'; 4259'-76'; 4072'-4138'; 3963'-68'; 3939'-43'; 3896'-3900'; 3866'-70'; 3818'-56'; 3797' - 3804'. Ran in hole %nd conditioned mud continued perforating at 3718'-38'; '3681'-93'; 3657"63~; 3623"-43'; 3614'-17'; 3537'-45'; 3518'-22'; 3493'-3503'; 3450t-62'; 3416'-25'; 3405'-11' 3334'-40'; 3312'-18'. Ran in hole and conditioned mud. Continued perforating at 3362'-92'; 3244"-83'; 3148' 6*7' ' ' ' ' -. ; 3126'-31 ; 3101 -11 ; and 3066 - 96'. Ran in hole with bit and casing scraper to 5477'. Conditioned mud for tubing. AI.I~ 1. I. !0.79 ATTACHMEN~f "A" ELECTRIC LOGS RUN Schlumberger Dual Induction - Laterolog - 408'-6500' Compensated Formation Density W/F-log - 2380'-6505' Compensated Neutron Density (CNL) Continuous Dipmeter BHC ,Sonic Proximity Microlog Cement Bond Log.Variable Density Cement Bond Log Variable Density Gamma Ray- Neutron Casing 'Collar & Perforating REcord - 2380'-6505' - 2380'-6504' - 2380'-6503' - 2380'-6504' - 615'-6451' - 2550'-3150' - 2800'-5737' - 3000'-5250' 0 STANDARD OIL CO, OF CAL, BELUGA RIVER GAS FIELD ,, PLM-W/CAL. BCSL;.W/CAL, 4-ARH HR CD 21II PLM-W/CAL BCSL-W/CAL ~-ARM HRCD (SEE B. ELOW) BRU-241 -.34 KENAI, ALASKA 5II GR-N CBL-VD CC L- PR CFD L-GG -F -LOG CFDL-GG-CNL CFDL-GG CFDL-GG-CNL-GR ..f . DIVISION nF OiL Form` P--3 e ~ ' ' Smbmtt "Intentions" in Triplicate REV. 9-3069 & "Subsequent Reports" in Duplicate STATE OF ALASKA 5. AP1 NU1V~C.~L CODE O1[ AND GAS CONSERVATION; CON~MIY~EF 50-283-20038-00 SUNDRY NOTICES AND REPORTS ON WEL~ (Do not use this fo~ for proposals ~ drill or to deepen Use "APNUlCATION 'FOR ~i'l':" tor such 'p~obosal~,) A 029 657 . . . 2. NAME OF OPE~TOR 8. UNIT, FA~ OR ~SE NAME Stand,rd Oil o~ Californi~a. Wemtern Onerations. Inc. Beluga River ~. ~ss o~ o~'~AZO~ ' - ~. ~ ~o~ P.0. Box 7-839, ~chorage, ~as~ 99510 BRU 241-34 ~. ~oc~,o~ o~ w~ ~. At surface 898.5' South and 1399.19' West of Northeast corner Sec 34, T13N, R10W SB~ n. smc.,~:, O~E~IVE) Sec. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. P~T I 109.7 ' KB 72-16 14. Check Appropriate Box To Indicate Nature of N~ti'ce, Report, or Other D~ta ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPI,ETE ABANDONs CHANGE PLANS Other) WA~E..~I~T-Or, [ ] REPA~B~N0 wEw, ~ FRaCTURm TRmaTMmNT aLTmRXNO CISINO SHOOTING OR *CIDIZIN~ ABANDONMm~T* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form,) I5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, lncludin$ estimated date of starting any proposed work. Anticipated structural advantage required to justify deepening of well to 10800' to test the Tyonek fm. "D Sands" was not realized by 6500'. Accordingly, drilling was halted (TD 6500') and well is presently being completed in known Beluga and Sterling formations. (This space for State o~ce, APPROVED BY TITLE l)4.~t~'iCt Supmrintendent DATE August 3, 1972 // ~/ See Instructions On Reverse Side _,-~'/?/~ .~ ApPf'oved C-.gp~f ' Ee.turneCi Form No. ~'v, ~-~o-~ STATE OE ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY RE!PORT OF :DRILLING AND WORKOVER OPERATIONS '5. AP1 NUAiERICAL CODE 50-283-20038-00 LEASE DESIGNATION AND SERIAL NO. A-029657 1. ?. IF INDIAN, AJ-RDT]-EE OR TRIBE NAME OIL J'-"l GAS ~ WELL WELL OTHE, gg5] ~ 2. NA/~E OF OP~TOR Standard Oil Company of .Ca.lifornia W.O, I., 3: ADDRESS OF OPEI{ATOR P. O. Box 7-839 Anchorage; Alaska 4. ~OCAUON OF W~L Surface: 898.5' South and 1,399.19' West of the Northeast corner, Sec. 34, T13N, R10W; SB&M 8. Lq~IT,FA/RA~ OR LEASE NAJ~E Beluga River 9. WELL BRU 241-34 10. FIELD AND POOL. OR WILDCAT Beluga River 11, SEC.. T., R., ~.. (BOTTOM HOLE OB.mCTrVE) Sec. 34~ T13N~ R10WI S.B.&M 1~-, PI~¥IIT NO. 72-16 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~N'GES IN HOLE SIZE, CASING A_ND CEMENTING JOBS INCLUDING DEPTH SET A/NI) VOLU/VIES USED, PF_~LFO~LATIONS, TESTS AATD RESULTS, FISHING JOB~, JU/~K IN HOLE AND SIDE-TI~ACKED HOLE ANT) ANY OTI~ER SIGNIFICA2qT CI-IA/~F~ IN HOL~ CONI)ITIONS. June 17~ 1972 Spudded well at 7 P.M. June 18-23~ !97.2 .JUNE, 1972 Drilled 17½" hole to 407'. Opened hole to 26". Ran and cemented 400' of 20", 94# casing. Nippled up 20" - 2000 psig BOPE and mud manifold. Tested 20" BOPE okay to 800 psig and manifold okay to 5000 psig. June 24-30, 1972 Drilled 20" shoe. Drilled ahead in 17½" hole to 2234'. Ran Schlumberger D.I.L. log from 407' to 2234'. Drilled ahead to 2384'. Conditioned mud for casing. Ran and cemented 2380' of 13 3/8", 68# casing. Nippled up 12"-3000 psig BOPE. Tested okay to 2500 psig. Drilled ahead in 12¼" hole to 3034' .. Conditioned mud prior to cuttin~~'~i. mGN~D _~/,,~//J'/~~M Z/7 ~TL~ ' Superintendent .~,'r~ J~ly 7. 1972 , , /y. v. ona~zer[o.r~ N~rE--Report on this form is required for each calendar month, regardless of the status of operations, anti must be file¢ in duplicate with tffe Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No. P---4 REV. STATE OF ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF :DRILLING AND WORKOVER OPERATIONS 0IL ~-~ GA8 ~ OTHER WI~LL __ wELL 2. MA-ME OF OPERATOR Standard Oil of California, W. O. I. 3. ADDRESS OF OPERATOR P. O. Box 7-839 Anchorage, Alaska 99510 4. LOCATiON &F WELL Surface: .898.50' SoUth and 1,399.19' West of the Northeast corner, Sec. 34,T13N,R10W, SB &M '5. AP1 NUMERICAL CODE 50-283-20038-00 LF_a%SE DESIGNATION AXD SERIAL NO. A-029657 7. IF INDIA~,~, ALOTTEE OR TRIBE NAME 8. I/NIT,FA/~ OR LEASE NAME Beluga River 9. WELL NO. BRU 241-34 I0. FI~-?-r~ A-ND POOL, OR WILDCAT Beluga River 11. SEC., T., R., M,, (BO'I'TOM HOLE Sec. 34, T13N, R10W, SB & M 1~. PEB.MIT NO. 72-16 13. REPORT TOTAL DEP'rH AT END OF MONTH, CHA. NGES IN HOLE SIZE, CASING A_N-D CEIVIENTING JOBS INCLUDING DEPTH SET A_N-D VOLUMES USED, pERFORATIONS, TESTS ANT) I~ESULTS, FISH/NG JOB~, JLrNK IN HOLE A/qD SIDE-TI~ACKED HOLE AND ANY OTHER SIGNIFICANT ~GES IN HOL~ CONDITIONS. SPUDDED WELL BRU 241-34 AT 7 P.M., JUNE 17, 1972. ~4. ~ helix ~~ .~~//~._~7_ ~District~O'~./~.'!~:~i_~A'ec* ~intendent m,~ ~(~[ June 1~197 2 NOTE~Report o~ t~is form is required for each calendar mo~tb regardless of the stat~s of operations, ~n~ mu~t ~ flle~ iff d~plicate Division of Mines & Minerals b~ the lSth of the succeeding month, uMess othe~ise directed. WELL NO. SECTION NO. 34 TRACT NO. [:3 PRoPOsED 1=3 PRELIMINARY !)~3-FI BRU 241-34 COUNTY OF WELL SURVEY Pro-312 Bel uqa CITY OF . TOWNSHIP 13N RANGE lOW [29 S,B.~/ & 14, !--I H,D,B, & #, LOT NO, FI ELD Beluga Ri Ver 898.50 South and 1399.19 West from the Northeast corner, LOCATION Section 34, T13N, RIOW, S.M., Alaska ELEVATION: GROUND_ 88.2 COtlCRETE MAT DERRICK FLOOR , ..... A:~ T E R N A 1: E 'O R S'"U R 'V E y i~"D 'L 0 C A'"T i 0 N" ' ' "LOCAT.i ~t~ ..................... DES1 G~IATI ON LOCATION COORDINATES HOVE REMARKS Final. N?,624, 278.88 'E 316,5i9.0.7 ............. · ...... ., , . , , , · . . . . . . . . . · . · I~ I .... - - - l l [Sec. ., SKETCIt OR REMARKS Coordinates are Alaska State Pla'ne, Z _ ~_. . . Too-of' rim- Of .we'l-1' Celll'ar:lO~' N,E.: 'side: of well Elev 88.~ I I ............ .......... ........ ........... . · C.C. D IV,, ENGR. FILE SURVEYOR C. Herschbach ~:Ai~IT. FR~I. MAIHT. SUPT. DATE 6/1 5/72 OATE DATE PR0.312 (2500.CD. 1-58} lJ e . Chevron tC;ti Standard Oil Company of California, Western Operations, Inc. P.O. Box 7-839, Anchorage, AK 99501 • Phone (907) 279-9666 C.V.Chatterton District Superintendent May 1, 1972 Producing Department Drilling Program Beluga River Unit 241-34 Cook Inlet, Alaska Mr. H. A. Slack Atlantic Richfield Company P. 0. Box 360 Anchorage, Alaska 99510 Mr. A. A. Winn Shell Oil Company P. 0. Box 3397 Terminal Annex Los Angeles, California 90054 Gentlemen: Attached for your approval is the PRO 316 series to drill Beluga River Unit 241-34. This well is proposed for drilling to satisfy the following two conditions: 1. Evaluate potential additional gas reserves in stratigraphic sequences above and below present known productive measures. The deep objec- tive for evaluation are the "D" sands of the Tyonek formation. 2. Provide back up productive capacity at Beluga in order to meet contractual commitments to Chugach Electric Association in the event of a failure of an existing facility at this remote location. Data regarding and justifying this proposed location are detailed in the discussion portion of the attached PRO 316 series. The estimated cost to drill BRU 241-34 to 5800' and complete in the Beluga River and Sterling sands is $949,000. Participants' share of this estimated cost are as follows: Atlantic Richfield Company $316,300 Shell Oil Company $316,300 Mr. H. A. Slack Atlantic Richfield Company Mr. A. A. Winn Shell Oil Company -2- May 1, 1972 The estimated additional cost to drill and complete in the "D" sands at 10,800' is $354,000. Participants' share of this estimated additional cost are as follows: Atlantic Richfield Company $118,000 Shell 0il Company $118,000 A spacing variance for this location was granted by the Alaska State Division of Oil and Gas on April 27, 1972. Please signify your concurrence for the drilling of this well by signing one copy of this letter and returning it at your earliest convenience. Very truly yours, 2,.0, a01,eitcy V. Chatterton Attachments AGREED TO AGREED TO This day of , 1972 This day of , 1972 ATLANTIC RICHFIELD COMPANY SHELL OIL COMPANY By By • PROPOSAL FOR WELL OPERATIONS Pro-3I6 . FIELD BELUGA RIVER PROPERTY and WELL No. BELUGA RIVER UNIT 241-34 CLASSIFICATION: Development IX I Exploratory Remedial Abandonment I (Dry Hole only) Oil Gas X Other INFORMATION RELEASE: Regular ( X I Special WORK PROPOSED/REMARKS: Drill well 241-34 at the Beluga River Field to evaluate potential reserves at a crestal location. Potential reserves are contained in sands above and below known productive measures. The deep objective is the "D" sand interval of the Tyonek formation. Standard's 1/3 share plus G&A is $492,935. ESTIMATES: I. Depth 10,800' 2. Number of Days 65 3. Initial Production . . . A. Oil - B/D — Oil Gravity B. Gas - MCF/D 8,000 Oil Value Decline Rates: 4. Well Cost (Incl. Pumping Unit) $ 1.303,000 1st Yr. 5. kiFte€1.-12-1t-a>rd—€qui-e+nen-t- .G&A. @ 4 .57 $ 58,635 2nd Yr. 6. TOTAL COSTS: Completion X Dry Hole . . $ 1,361,635 3rd Yr. 7. Payout 4.3* Yrs. 8. Percent Return on Outstanding Investment 30.6 9, Discount Profitability Index @ 72% 2.7 10. Estimated Economic Well Life 20 Yrs. II. Minimum Production for 20% Rate of Return N/A B/D 12. Well Total Rec. Reserves: New 54.0x106 1%=ffMCF (Oil or Gas) Acceleration Bbls or MCF *Well is not producing at capacity for 1st 2 years due to sales contract limit. TYPE OF APPROVALS REQUIRED: District Superintendent I x Div'n Oil and Gas x Division Management U.S.G.S. I x San Francisco Management x Other ( ParticipantS ) ( x BUDGET: Funds in Budget Year 1972 DISTRICT ENDORSEMENTS: Have Funds Been Released? Yes Original Signed By at District Supt. G��l ,�.3 7?i District Engineering / fl ' j-- 3 '7L DI-V-154-814-APPROVAL: Drilling District Witt' Field Operations ;2i � -4+;��s-*oa Manager orAssistant Re uired in San Francisco hatterton Cleared byLand Dept. on q Da -C673/7Z- SAN 73/7L SAN FRANCISCO APPROVAL: General Manager or Assistant General Manager Date DISTRIBUTION: Prepared at Date O PRINTED IN U.S... PRo-316 (2M-CD-11-69) I 111.,I VJfTI. I V11 TT LL.L VI l-I\/'�IIVI1.l 111V-J ILP/-1 ,IV LL VJ4-L., /-l../ I-1 ....,...,-1 I 1 I t CASING REOUIREMENTS AND PRODUCINr EQUIPMENT sterling and Beluga. Formation pletion i WELL/LOCATION NO BRU 241-34 FIELD Beluga River DATE May 1. 1972 FORWARD BUYING NO ESTIMATED SPUD DATF 7/1/72 TOTAL DEPTH 5500' METHOD OF PRODUCTIONFlowing MAX. ESTIMATED SURF. PRESSURE 2200 _PSI ESTIMATED Gas M/D • 12000 _EQUIP. FOR STEAM No INJ No PRODUCER Yes I CASING Gross Footage API Size Weight Grade Threads Coupling Computer Design For: Conductor 400' 20" 94.0 H-40 VETCO VETCO This Well 0 EI Requires 10-26" x 20" centralizers and Baker Duplex Shoe Standard Design For Field 0 ' Surface13-3/8" Well No. 2600' 68.0 K-55 8rd L�&C ❑ Requires 10-171" x 13-3/8" centralizers, Baker triplex shoe and tripieMax-DriftAngle —2.—.° baffle collar � Water String: Design based on mud density 80 lbs./cu. ft. and above max. surf. pressure I 5800' 9-5/8" 43.5 N-80 8rd LT&C • . Requires 10-124" x 9-5/8" centralizers, float shoe, float collar and stage collar. Also two .short marker joints. - Cementing Accessories • Liner • Hanger , • CASING l HEAD: 3000 PSI CWP. Bottom Conn_ Slip on & Weld NOTE: At Swanson River !i UZIKIXXEla! Top Conn 12" - 3000 2 _ 2 n _ Flanged outlets ,i Hilires.One _side_- _Scotch nipple; other 2" - 3000# valve and flange i TUBING HEAD 5000 PSI CWP. Bottom Conn.-12t1 - 3000# Top Conn— 10" - 5000 _ 2 2 II __ Flanged outlets #li '' Type Suspension Quadrup3,e 2-7/e" x 2-7/8" x 2-3/8" x 2-3/8" . . .: - . - . . - 4 . 0 . 0 'r .. f TUBING Feet API Size Weight Grade Threads Type Remarks I ± 9000' 2-7/8" 6.5 , N-80 EUE Prod. Strings(Cross overs,etc.) { _+ 5500' 2-3/8" 4.7 N-80 EDE Heater and Production Strings Requires: 3 - single hydraulic packers, 2-7/8" x 9-5/8" 43.5# ,# 1 - dual hydraulic packer, 2-7/8" x 2-7/8" x 9-5/8" 43.5# 1 - triple packer, 2-7/8" x 2-7/8" x 2-3/8" x 9-5/8" 43.5# Sleeves, nipples and blast joints as required. _ _ XMAS TREF 2-7/8" 4 __Arm 5000 . PSI CWP. vwg. No To be designed Tubing Beans _ Type " Typ,. Casir.g Beans! " Type nType • _ Header "______ Arm _ —__.PSI CWI'. Dwg. No _ . I=3 Stuffing Box "__ Typo. Polished Rod "x 'Long ,; PUMP:_— "x_� _r _ Typo at ill RODS: Grade 'of ": 'of ": 'of " Ill PUMPING UNIT. API Size —Type__ Max.Slroke "Set at "Stroke and _SPM i?' Engine Motor ' —HP Remarks1 i Field Foreman !I Prepared B Area Supervisor_ �I s 0 f p Yew A . roved b • • x mer , C.W. Wilson i'P y I (.0 ?�'�j -�3�T Z- -a R. Tinker III Dist.Supt ill PRO•SIe.A(?M.o•ee) i . rtivrL' AL rL'I\ YV CLL- Li •CKH I IuIVJ rI(CJ-3 i o-H [1 v DC uJCIJ HJ f-1 k. '1/43-1 1 i j CASING RFnUI REMENTS AND PRODUCIP- EQUIPMENT 'D" Sand Completion WELL/LOCATION NO BRU 241-34 FIELD Beluga River DATF May 1, 1972 FORWARD BUYING NO ESTIMATED SPUD DATF 7/1/72 TOTAL DEPTH_ 10800' METHOD OF PRODUCTION Plowing MAX. ESTIMATED SURF. PRESSURE 4,000 PSI ESTIMATED Gas M/D 8,000 _I_OUIP. FOR STEAM No INJ No PRODUCER Yes I CASING Gros.;Footage API Size ' Weight Grade Threads Coupling Computer Design For: i Conductor 400' 20" 94.0 H-40 VETCO VETCO This Well ❑ if. Requires 10-26" x 20" centralizers and baker duplex shoe Standard Design For Field ❑ • l. Surface 2600' 13-3/8" 68.0 K-55 8rd LT & C Well No. . 0 it Requires 10-172" x 13-3/8" centralizers, Baker Triplex Shoe and Max.Drift Angle _____L* lr triplex baffle collar. . Water String: Design based on mud density 80 ('os./cu. ft. and above max. surf. pressure 5800' 9-5/8" 43.5 N-80 8rd LT & C - Requires 10-123" x 9-5/8" centralizers, float shoe, float collar and stage collar. Also two short marker joints. . , i • t Liner: As Follows: - ,- • : . ,. •Bott'om 1800' 7" 29 N-80 8rd LT & C Next 2500' - 7" 26 .N-80 ' 8rd . LT & C • i. --Top- 900' 7" 23 N-80 8rd LT & C Total 5200' Requires 10 7" x 8-5/8 centralizers, float shoe float collar and stage collar. Also 1 marker joint and liner hanger 7" x 9-5/8" 43.5#, grooved for cementing.; ' :CASING - HEAD• 3000 PSI CWP. Bottom Conn Slip on & weld. NOTE: At Swanson River It bbittlafdl! Top Conn 12" - 3000 2 2 ",_ Flanged outlets - Fit.;,,e�__One-.side - Scotch nipple. . other 2"-3000# Valve. & Blind_Flange • :a TUBING HEAD 5000 ,PSI CWP. Bottom Conn._-12" - 3000# . lop Conn 10" - 5000# 2 2 _ Flanged outlets i1 TypoSuspension Cameron Dual DCB or equivalent with COSASCO B/P valve threads. TUBING Feet API Size Weight Grade Threads Type Remarks Cross-Overs,etc.) Bottom - • ----------. ; Production . Total , 10.300' 3-1/2" 9.3 N-80 EUE , String ~ ° . Total - Top + 2000' 2-3/8" 4.7 , N-80 EVE Heater String i 3 Docleears 312- - Requires: 3 - single hydraulic packers, 3 1/2"x.7" 294 • . 1 - circulating sleeve I XMAS TREE _312" 2 Arm 5000. PSI CWP. Uwg. No_To be designed _ Tubing Beans IPType type. I Casing Beans - Type Type Header ___arm __PSI CWF'. Dwg. No l!'' Stuffing Box "_ Typo. Polished Rod _"x 'Long i'' PUMP: "x__ _, _ Typo at +� RODS: Grade • 'of 'of 'of " `k PUMPING UNIT. API Size_ Type_ _.Max.Stroke "Set at. " ' i_ StroRe and —SPM t;; Engine —_____Moicr - HP Remarks �! II, Field Foreman ! i PreparodBt / I- Area Supervisor_ % Dr eg 1 ��, n` �' C.W. Wilson AppfovW` Tinker III Dist.Supt._eb�, V. Chatterton/, A 63 72- - 1 Dist. • •9 0. •0.00 ! PRO 1 A(2M ) �� - ' I K PAGE I OF 2 WELL • WST ESTIMATE WORKSHEET Pro-316-C t: PROPERTY AND WELL NO. Beluga River Unit 241-34 DISTRICT Alaska 1, FIELD Beluga River SEC. 34 - T 13N R lOW ESTIMATED TOTAL DEPTH 10,800 ESTIMATED DRILLING DAYS OR TOURS 65 35 Days 30 Days C-946-2 DESCRIPTION 5,800' 5,800' to Add'l to Comp. ITEM NO. Producer 10,800'&PB* at 10,800' CONTRACT DRILLING DAY RATE - DAYS @ $ 3,000PER DAY 105,000 90,000 1 1 PER DAY I Extra Labor DAYS @ $ 100 3,500 3,000 CONTRACT DRILLING FOOTAGE FT. @ $ PER FT. ' 2 DAYS @ $ PER DAY , 3 COMPANY DRILLING LABOR DAYS @ $ PER DAY ;) 4 COMPANY DRILLING SUPERVISION DAYS @ $ 4nn PER DAY 18,000 12,000 5 .COMPANY EQUIPMENT USAGE • DEU DAYS @ $ PER DAY DERS DAYS @ $ PER DAY 6 FUEL AND UTILITIES DAYS @ $ 600 PER DAY 21,000 18,000 7 SUB TOTAL (1 THROUGH 6) $ 147,500 $ 123,000 $ 8 RIG UP AND TEAR OUT/MOVE IN AND OUT Incl. Prorate to Beluga 55,000 9 DRILLING FLUIDS 45,000 30,500 10 WELL SUPPLIES AND NON-SALVABLE MATERIALS (CEMENT BASKETS. 15,000 4,500 FLOAT EQUIPMENT. CENTRALIZERS-SCRATCHERS) . 11 TRANSPORTATION 55,000 30,000 6,000 CONTRACT SERVICES AND RENTALS fff 12 DIRECTIONAL. TOOLS. SURVEYS & SERVICES 1 i!,.nn.`t LO n,v i ii r I-_HOi !NST. . SERV ICEMAN SURVEYS. FTC. ) , u 13 DRILL PIrE. BITS. REAMERS & OTHER TOOLS 45,000 25,000 (HOLE OPENERS. STABILIZERS. REAMERS. DRILL PIPE & DRILL 20,000 t 1 COLLAR RENTAL, ETC. 14 OTHER SUB SURFACE CONTRACT RENTALS & SERVICES 57,000 18,000 (8,00) (WIRELINE PERFORATING.FORM.STIMULATION.CASED HOLE LOGS,ETC. ) 15 OTHER SUB SURFACE COSTS 5.000 (SWABBING. •HASHING PERFORATIONS. CHANGE OVERS. ETC. ) 16 SUB TOTAL (I THROUGH 15) 8 424,500 $ 246,500 $ • 20 FORMATION EVALUATION CONTRACT SERVICES CORING FT. @ $ PER FT. i SIDEWALL SAMPLES @ S PER SAMPLE r CORE ANALYSIS 21 TESTING 2 TESTS @ $ 2,500 PER TEST 5,000 • WIRELINE TESTS @ $ PER TEST 22 LOGGING WIRE LINE 2 RUNS @ $ 2,500 PER RUN 20,000 25,000 i 23 LOGGING MUD DAYS @ $ 250 PER DAY 11,000 • i 24 TOTAL FORMATION EVALUATION SERVICES (20 THROUGH 23) S 25,000 $ 36,000 $ 30 CASING. TUBING AND RODS 20"CONDUCTOR 400 FT. @ $ 30.65 PER FT. 12,260 13-3/6" SURFACE 2600 FT. @ $ 13.57 PER FT. 35,280 1 9-5/6" PROTECTIVE 5800 FT. @ $ 9.91 PER FT. 57,480 7" LINER • 5200 FT. @ 5 5.91 PER FT. 30,731 ` I Ei OILSTR1NG FT. @ $ PER FT. ff; I 2-7/8" TUBING 9000 FT. @ $ 1.69 PER FT. 15,210 2,000 '' ! 1. ' 2-3/6" TUBING 5500 FT. $ 1.31 PER FT. 7,205 I ! RODS Csg._ Crews & m Xx4 Tuboscope PER FT. 8,565 4,269 ' I _____:] • RODS _ FT. @ S PER FT. ! 1 _ TOTAL _ 136 ,000 37,000 •• i; ` f *Includes plug back to 5,800' Pao-316-C PAGE 1 (1500-CD-8.68) j PAINTED IN U.S.A. i +I **Difference in cost between 2 strings of 2 7/8" tubing (9000') compared to 10,000' j 'f of 3 1/2" 9.3#/ft. , N-80, buttress tubing. t �' I PAGE 2OF2 . r WELL COST ESTIMATE WORKSHEET Pro-316-C . . • C-946-2 DESCRIPTION 5,800' 5,800 to 1 Add'l to Com 1 I TEht No. Producer 10,800'&PB at 10,8001 31 SUBSURFACE PRODUCING EQUIPMENT CASING HEAD 1900 . TUBING HEAD 3300 CASING SPOOL . XMAS TREE 15000 i PACKERS 20,000 . WELL PUMP i SLIDING SIFEVES. SIDE DOOR CHOKES. ETC. 3,000 43,200 i , 32 CONTRACT CEMENTING SERVICES . CONDUCTOR YDS. @ $ PER YD. I j 20"SURFACE 680 SACKS S_3,400 PUMP TRUCK $ 600 I PROTECTIVE 2200 SACKS $ 11,000 PUMP TRUCK $ 800 i HI OIL STRING 1300 SACKS $ 6,500 PUMP TRUCK $ 1,400 • 7"LINER 2000 SACKS $ 10,000 PUMP TRUCK $ 1,500 SQUEEZE JOBS300 SACKS $ 1,500 PUMP TRUCK $ 2,600 i "- OTHER SACKS $ PUMP TRUCK $ CEMENT BOND LOG RUNS CO $ in #14 PER RUN WATER SHUT OFF TESTS 2 TST. @ s2,500 PER TEST TEMPERATURE SURVEY 32,800 6,000 11,500 ii I40 FISHING l 41 TOTAL SUBSURFACE WELL COSTS r 661,500 $ 288,500 I$ 51,900 51 SITE PREPARATION - LAND ( 31,000 I 52 SITE PREPARATION - WATER 1 53 ARTIFICIAL LIFT EQUIPMENT . PUMPING UNIT.$ - PRIME MOVER $ 54 TANKS. TRAPS.CAISSONS & OTHER SURFACE EQUIPMENT TANKS IN $ EACH . (To be detailed on informational 1 SEPARATORS @ $ EACH - GO-36B after authorization) ,-, FLOW LINES FT. @ 8 FT. I ' I , ELECTRIC LINES FT. @ $ FT. GAS LINES FT. @ $ FT. WATER LINES FT. @ $ FT. MISCELLANEOUS 220,000 55 TOTAL SURFACE WELL COSTS $ 251,000 $ -0- $ -0- I 56 TOTAL DIRECT WELL COSTS $ 912,500 $288,500 8 51,900 i ` 61 DISTRICT AND DIVISION EXPENSE at 4% 36,500 11,500 2,100 62 GENERAL AND ADMINISTRATIVE EXPENSE 63 WELL CONTRIBUTION CREDITS ' 64 TOTAL WELL COST 949,000 300,000 54,000 ` TOTAL TANGIBLE (TOTAL OF LINES 30. 31 . 53 & 54) s 399,200 $ -0- $ 37,000 ' r TOTAL INTANGIBLE (LINE 64 LESS TOTAL TANGIBLE) _S 549,800 s 300,000 $ 17,000__) 'I Prepared by B. E. Wondzell • District Engineer J.W. Walker kW/Will-0_07Lt Area Supervisor J.J. Drev6 .02_ Di trict Drilling Supervisor T.E. Faughn I , 1 . Approved C. V. Chatterton 0 ..3 72 Date May 1, 1972 • i D trict Su erintendent t' � ( PRO.316.0 PAGE 2 (1500-CD.8-681 P INItO IN U.S.A. �, 1 I . I ' DISCUSSION PROPOSED WELL BELUGA RIVER UNIT 241-34 Proposal: The drilling of well Beluga River Unit 241-34 (crestal location) is proposed for the following two reasons: 1. Evaluate potential additional gas reserves. 2. Provide back up productive capacity at Beluga in order to meet contractual commitments to Chugach Electric Association in the event of a failure of an existing facility at this remote location. The surface location of proposed well 241-34 is approximately 900' South and 1400' West of the Northeast corner of Section 34, T. 13 N. , R. 10 W. , SB&M. Refer to Exhibit #1. This location has been selected to give the maximum structural advantage for all potential horizons, especially the lowermost objective "D" sands of the Tyonek formation. Justification: The potential reserves to be evaluated in the proposed crestal test are located in the following stratigraphic sequences (these intervals have not been found,productive to date at Beluga) : 1. In Sterling formation sands located stratigraphically above the present known productive intervals. The potential reserves in this interval are 55.0x106 MCF at 500 psig abandonment pressure. Refer to Exhibit 2. 2. In the lower Beluga River formation sands located stratigraphically below the present known productive interval. The potential reserves assigned to this interval are 116.0x106 MCF at 500 psig abandonment pressure. Refer to Exhibit #2. 3. In the "D" sand interval of the Tyonek formation at a depth below-9100' . The potential reserves assigned to this interval are 100.0x106 MCF at a 75% recovery factor. "Refer to Exhibit 2. The two highest structural wells at Beluga, 233-27 and 212-35 are located on the western and eastern flank, respectively, of the Beluga River structure. Well 212-35, which was the original discovery well, was a deep exploratory test drilled to 16,428'. Neither well, however, is located along the structural crest. Present structural mapping indicates that at the crestal location herein proposed approximately 200' of addi- tional advantage can beigained over these wells at the A-2 (shallow) contour horizon and 200-300' of advantage at the "D" point (deep) contour horizon. Refer to Exhibits 2 and 3. Comparisons of the Beluga River Field to the North Cook Inlet Field indicate that the productive section is directly related to the structural position. DISCUSSION • PROPOSED WELL BELUGA RIVER UNIT 241-34 -2- For example, at the North Cook Inlet Field the Sterling formation is crestally gas productive some 400' stratigraphically higher in the section than on flanks. Likewise, crestally the Beluga River forma- tion appears productive several hundred feet stratigraphically lower in the section. Refer to Exhibit 4. By analogy it is reasonable to expect that the maximum structural advantage afforded at the crestal position at Beluga will provide a similar maximum productive interval and, accordingly, upper Sterling and lower Beluga sand production. Though many of the lower Beluga sands in the BRU 212-35 well were tested tight and impermeable, improved winnowing during sand deposition over growing structures often provides improved reservoir character at the crestal position. (For example, improved "D" sand development at the Kenai Field) . At BRU 212-35 (original discovery well) some 300' of permeable but wet "D" sands were penetrated below the "D" point. (Refer to the type log on Exhibit 2) . These sands are the lowermost objective of the proposed well 241-34. Potential "D" sand production can be related to the Kenai and McArthur River Fields where similar "D" sands are found productive at an analogous crestal position, with similar structural advantage. Economics : the economics for BRU 241-34 based on an initial production rate of 8000 MCF/D ("D" sands) , indicate a payout of 4.3 years, a rate of return of 30.6% on a 20 year life and a 7.5% DPI of 2.7. In the above economics Well 241-34 is not producing at capacity for approximately 2 years due to the existing sales contract with Chugach Electric Association. Hazards : None, for completion in known Sterling and Beluga reservoirs. Risk of new reserves is dependent on coexistence of sufficient structural advantage and improved reservoir character to provide added entrapment. PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM FIELD: BELUGA RIVER PROPERTY AND WELL NO. : BELUGA RIVER UNIT 41241-34 LOCATION: Approximately 900 ' South and 1,400' West of the Northeast corner of Section 34; T. 13 N. , R. 10 W. , SB&M. ELEVATION: Estimated K.B. is 100' . BLOWOUT PREVENTION CONSIDERATIONS: 1. Potential Problems: Gas: The proposed well is a crestal test in a known gas field. Numerous gas sands will be penetrated during the course of drilling this well to total depth. Gas entries into the mud columns can cause serious problems. Care must therefore be exercised at all times to prevent gas entries by either swabbing the well when pulling pipe or hydraulicing the formation (with associated lost circulation) on trips. Rapid penetration rates cause an increase in mud weights and increase the risk of lost circulation and subsequent kicks. Penetration rates will be restricted. Coal beds at Beluga can cause serious problems. The beds contain some gas, slough readily, and drill rapidly. If thick beds are encountered, reduce the penetration rate and/or circulate bottoms up. Extreme care must be exercised in the drilling of these beds since they slough, and cuttings tend to pack off around the bit. This pack-off can cause lost circula- tion, kicks and a stuck drilling string. Lost Circulation and Water Entries: Lost circulation is believed to have been the cause of the blowout at BRU 212-35 (411 discovery well.) Too rapid a penetration rate caused an overloading of the mud column with cuttings followed by lost circulation and gas entry. The most recent well drilled at Beluga, South Beluga River Unit 4114-3, was drilled to 10,000; , with 76-78 pcf mud and from 10,000' - 13,000' with 80-82 pcf mud. There were no gas kicks, lost circulation zones or zones of water entries. Penetration rates were limited in the top hole. Precautions : Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at all times by every member of the crew. The hole must be kept full at all times. PROPOSAL FOR WELL OPERATIONS PRO 316-1 BELUGA RIVER UNIT . DRILLING PROGRAM #241-34 -2- 2. Estimated Depths and Formation Pressures: (Base on 0.47 psi/ft gradient) Drilled Subsea Estimated Zone or Marker Depth Depth Pressure psi Top potential Sterling Production 2290' -2190' 1075 Top Sterling "A" Gas Interval 2890' -2790' 1360 Top Sterling A-2 Contour Horizon 2945' -2845' 1390 Top Beluga River Formation 3400' -3300'. 1600 Base Known Production 5000' -4900' 2350 Base Beluga Formation and Top Tyonek Formation 7800' -7700'. 3675 "D" Point 9200' -9100' 4330 "D" Sands 9250' -9150' 4350 T.D. 10,800' -10,700' 5075 3. Maximum Anticipated Surface Pressure: 3,000 psig. However, if discovery is made in "D" sands and casing is set, surface pressure with gas column could be + 4,500 psig. 4. Blowout Prevention Equipment: A. 20" - 2,000 psig, Class II B on the 20" casing. B. 12" - 3,000 psig, Class III & Shaffer Rotating Blowout Preventer on the 13 3/8" casing. C. 10" - 5,000 psig, Class III & Shaffer Rotating Blowout Preventer on the 9 5/8" casing. D. Installation and testing of the above equipment is outlined in Operating Instructions D-17. OBJECTIVES: Sterling, Beluga River and Tyonek formation "D" sands. PROGRAM 1. Cement 36" corrugated culvert pipe at l0'+ below the base of the cellar floor. 2. Drill for 20" casing to 400'. Maintain drilling .fluids per attached Drilling Fluid Program. 3. Cement 20", 94#, H-40, casing with Vetco couplings at 400' as follows: ' A. Cement with 680 sacks of Class "G" cement treated with 3% calcium chloride. This provides a 33% excess cement volume. If cement does not return to surface in the annulus , do a top cement job. PROPOSAL FOR WELL OPERATIONS PRO 316-1 BELUGA RIVER UNIT DRILLING PROGRAM #241-34 -3- B. Use a Baker Duplex shoe, C. Baker lock casing and shoe. D. Centralize casing over the entire 400' . 4. Install Class II B BOPE on the 20" casing per attached Figure 2. Nipple up blow and kill lines, and manifold for 5000 psi service. A Class III, 12"-3000 psi BOPE with a Shaffer Rotating Blowout Preventer will be installed later. Test BOPE per Operating Instructions D-17. NOTE: Burst pressure for 20" 94#, H-40 casing is 1530 psi with no safety factor. Do not exceed a 1000 psi test. 5. Drill out cement and drill ahead in 17 1/2" hole to a dull bit near 2100' . Reduce hole to 8 5/8" and rat hole ahead to 2350' , depth equivalent to 2580' : in BRU 212-35. NOTE: A. Limit penetration rates as necessary to maintain optimum fluid weight and solids content. B. Install Mud Logging Unit at approximately 1000/_ 6. Run and tape the following logs using Schlumberger equipment. All logs are to be run from total depth to the shoe of the 20" casing. Take a 1/2 gallon drilling fluid sample immediately prior to pulling drill pipe for logging. A. Dual Induction-Laterolog. Use linear scale for the 2"=100' and logarithmic scale for the 5"=100'. B. FDC-Compensated Neutron Log with Gamma Ray. 7. Based on formation evaluation techniques : A. If sand interval equivalent to 2520'-2580' in BRU 212-35 appears to be gas bearing: E 1) Lower 8 5/8"x17 1/2" shoulder to a depth equivalent to 2510' in BRU 212-35, now estimated at 2280' . 2) Cement approximately 2280' of 13 3/8", 68##/ft. K-55, 8rd, LT&C casing on the 8 5/8"x17 1/2" shoulder with 1900 sacks of Class "G" cement. This provides a 33% excess volume and should circulate cement to the surface. If returns do not reach the surface, do a top job. 1 a) Run a Baker Model "B" Triplex Shoe and Triplex Baffle Collar. b) Baker lock the bottom 5 joints of casing. c) Centralize the casing above the shoe. d) Treat the final 400 sacks of cement with 3% calcium chloride. 3) Run CBL and test for WSO as required. j� 4) Cut off the 13 3/8" casing below the top of the cellar to allow the top flange of the tubing head to be above ground level after completion. E ' PROPOSAL FOR WELL OPERATIONS PRO 316-1 BELUGA RIVER UNIT DRILLING PROGRAM #241-34 -4- 5) Install 13 3/8" SOW , 12"-3000 psi top flange casing head. Test welded laps to 2000 psi. 6) Nipple up and test per Operating Instructions D-17, a Class III, 12"-3000 psi BOPE and Shaffer Rotating Blowout Preventer on the 13 3/8" casing head, per the attached Figure 2. Pressure test to 2500 psi. 7) Drill out cement in the 13 3/8" casing to within 10' of the triplex shoe. Pressure test to 2500 psi. 8) Drill out 13 3/8" casing shoe. Open en the 8 5/8" hole to 12 1/4" from the shoe to a depth of 2350' , equivalent to 2580' in BRU 212-35. 9) Make a drill stem formation test of the open hole interval from the shoe of the 13 3/8" casing, approximate interval from 2280'- 2350' . Equipment and test periods are as follows: a) Make up Halliburton tester with 2 inside and 2 outside BT recorders. Run 1-12 hour clock and 1-24 hour clock inside and outside. Use jars, VR safety joint, and back- scuttling port. Use no water cushion. Set packer in 13 3/8" casing shoe with a tail to + 2350' . b) Open tool for an initial flow period. Flow period to be determined after the tool is opened. If gas is produced, obtain a stabilized rate and pressure. Do not allow well to produce over 3000-4000 MCF/D. If test interval does not produce gas and there is little indication of fluid entry, forego FSI. If gas productive, obtain a 1 hour FSI. Collect a 1 gallon sample of any water produced on • the test. Retain for geochemical analysis. 10) Proceed to Step #8 if commercial production is indicated. 11) If test does not indicate commercial production, drill ahead in 12 1/4" hole to 2600' . Reduce hole to 8 5/8" and rat hole ahead to 2815' . Make an open hole formation test of the interval from 2815'-2600' . Set packer on the 8 5/8"x12 1/4" shoulder. Equipment and test periods are the same as indicated in Step #7A. , 9)a) and b). Open 8 5/8" hole to 12 1/4" from 2600' to 2815' and proceed ahead to Step #7B, 8). Test interval equivalent to 2830'-3045' in BRU 212-35. B. If sand interval equivalent to 2520'-2580' in BRU 212-35 appears not to be gas bearing:. 1) Open the 8 5/8" hole to 17 1/2" from near 2100' to 2350' and • drill ahead in 17 1/2" hole to 2600', depth equivalent to 2830' in BRU 212-35. PROPOSAL FOR WELL OPERATIONS PRO 316-1 BELUGA RIVER UNIT DRILLING PROGRAM 4241-34 -5- 2) Consideration will be given to running logs as per Step #6 from 2600' to overlap last log run. 3) Cement 2600' of 13 3/8", 68#/ft. , K-55, 8rd, LT&C casing on bottom with 2200 sacks of Class "G" cement. This provides a 33% excess volume and should circulate cement to the surface. If returns do not reach the surface do a top job. a) Run a float shoe and float collar. b) Baker lock the bottom 5 joints of casing. c) Centralize the casing above the shoe. d) Treat the final 400 sacks of cement with 3% calcium chloride. 4) Run CBL and test for WS0 as required. 5) Cut off the 13 3/8" casing, install 13 3/8" casing head, nipple up, install Class III BOPE with Shaffer Rotating Blowout Preventer, and pressure test the casing per Steps 7A,4) ,5) ,6) , and 7) above. 6) Drill ahead in 12 1/4" hole to 2815' , a depth equivalent to 3045' in BRU 212-35. 7) Make a drill stem formation test of the open hole interval from the shoe of the casing at 2600' to 2815' . Equipment and test periods are the same as indicated in Step 7A,9) ,a) and b). 8) Suspend mud logging activity until Step #15. 8. Drill ahead in 12 1/4" hole to a dull bit near 5800' . NOTE: A. Consideration will be given to spot coring selective intervals in the Sterling and Beluga sands. B. Limit penetration rates as necessary to maintain optimum fluid weight and solids content. 9. Run and tape the following logs using Schlumberger equipment. All logs are to be run from total depth to the shoe of the 13 3/8" casing. Take a 1/2 gallon drilling fluid sample immediately prior to pulling drill pipe for logging. A. Dual Induction-Laterlog. Same scales as before. B. SP-BHC Sonic log. C. FDC-Compensated Neutron Log with Gamma Ray. D. Consider running a 4 ARM, High Resolution Dipmeter if structural information is required. • PROPOSAL FOR WELL OPERATIONS PRO 316-1 BELUGA RIVER UNIT DRILLING PROGRAM #241-34 -6- 10. . Cement approximately 5800' of 9 5/8", 43.5#/ft., N-80, 8rd, LT&C casing on bottom in two stages as follows : A. Run float shoe &float collar with a stage collar placed at the base of the lowermost productive Sterling sands. B. Cement around the 9 5/8" shoe with 620 sacks Class "G" cement. Volume indicated is sufficient to reach the stage collar with no excess. C. Cement through the stage collar with approximately 650 sacks of Class "G" cement. This volume is sufficient to fill 1000' into the 9 5/8"x13 3/8" annulus with a 33% excess . D. Baker lock bottom 5 joints, _ E. Run centralizers at and above the shoe joint, and above and below the stage collar. F. Run "short" marker joints of casing near the top of the Beluga River formation and above the uppermost productive Sterling sands. 11. Land the 9 5/8" casing. Install a 12"-3000 psi bottom flange x 10"-5000 psi top flange tubing head. Test secondary seals to 5000 psi. 12. Nipple up 10"-5000 psi, Class III BOPE and Shaffer Rotating Blowout Preventer on the 10"-5000 psi tubing head, per attached Figure 2. Test BOPE, kill, flow, and manifold lines to 5000 psi. 13. Drill out 9 5/8" stage collar and to within 10' of the 9 5/8" casing shoe. Pressure test stage collar and 9 5/8" casing to 3000 psi. 14. Run CBL and test for WSO in the Beluga and Sterling sands as required. 15. Drill out 9 5/8" casing shoe and drill ahead in 8 5/8" hole to a dull bit near 10,800' , a depth equivalent to 11,125' in BRU 212-35. NOTE: A. Consideration will be given to spot coring selective intervals as directed by the Development Geology Group. B. Reinstate mud logger at 5800'. 16. Run and tape the following logs using Schlumberger equipment. All logs are to be run from total depth to the shoe of the 9 5/8" casing. Take a 1/2 gallon drilling fluid sample immediately prior to pulling drill pipe for logging. Use same logs and scales as indicated in Step #9. 17. Based on formation evaluation analysis a detailed program will be provided to either complete in the "D" sands or salvage the well in the productive Beluga River and Sterling sands. V . AUER os: JOK dflpirr tot,: ,31n- DRILLING FLUID PROGRAM BELUGA RIVER UNIT 241-34 BELUGA RIVER FIELD Basic System Lightly treated Lignosulfonate mud. • Optimum Properties Value Range To 13 3/8" 13 3/8" Csg. Below Csg,,,, Point Pt. to 9,000' 9000' Weight, pcf 73-75 76-78 80-82 Viscosity, sec/qt, API 38-45 38-45 42-45 Fluid loss, cc, API 20+ 4-6 4-6 Plastic Viscosity, CPS2 10-15 10-15 Yield Point, lb./2100 ft. - 5-10 5-10 Gel, lb./100 ft. -10 min. - 10 max. 10 max. ph - 8.5-9.0 8.5-9.0 Calcium, ppm - 50 max. 50 max. Solids Content, % volume - 8-10 8-10 Diesel Content, % volume - 6-8 6-8 REMARKS: 1. Chemically disperse mud with chrome lignosulfonate. 2. Treat calcium out as required. 3. Maintain adequate supply of lost circulation material and barite at the location. 4. Run desander and desilter to keep solids at a minimum while drilling. 5. Increase viscosity while drilling surface hole as required to control gravel. 6. Limit dry jobs to 20 sacks of barite or as directed by Drilling Foreman. ..... .. ,ea,,..q'o-Pur'..4,... ..:. -. ..."EV"^sA","",�'!sM1x.+!q'svRe•Rr_a'�"n'.,- .... .. ... ....."'YaG:7..°Bi+3P.A: '. -., ., �-:#`S.";XirTj'v:v.'�AtEi1'{,F:2t'.ALC =3.._" ^.3€3•N+L^,f"..t.»...: .... ,.•:. .':. ..._s. .. 2:.'w`#"SE1- 02" __l_ Lg.R 2/2-25 02) 'r /star'OR/G/NAL 6.45/NG se 72/8/4/6'DETA/L h Cl.. I L.m 0 F,. Z e,k •-2%8"f/eater Shing 000 os w/lupnal Do'✓a C'o//ars %•y6'6'dts.-20/6.64' g i- k • L foe its c'''Tubiny-.9-30E.27' h f4PS%'cB. � � ' h I Q '4'4 f4C6 it'n ti A J DYCo//ai@/469' /320'xe.. 'PI \L .. 82.7'0.CP" + ..411. 2364" MI 3370.30' j--2J/8"C'd.r,00 S/idrn9 8/eeve Ya/v'-270' 3354..3/' �-Z%8'5rci CC Sdf1, /c/t --75' —2-re"1°up ,./7` -800- 3363.07" 7-(2./a'6i-own//3-/6-/PdcRer-6.00' It IN 2dts 2Ye-7-44b/n9-�.9oe' 4-9420'SQuo-ted :-3437' 3432.11' ,..'---2249'.C.7")700O'iYipo%-.93' * ii 9458' ti 9CS0' —ICC 9' 3732"-34'Spaeesed U 4008' —22 dts 2%®-77.16/,757-672.20' 0 -4014' D—. 44:720• 4024" U_—f056' a 0 ¢060" —4968" ri-4076.' O y=4705' 4/O5B4' lienti/ri Shoe-•s8' —4///' 0 x x ,� —¢/SO'E{fective Depth x x O X,. ,. —OM!{eta/nerQ 4200' 4 - —4246=48'//CT''2-No Entry —GM Ret.7ii/e,P 1270' 4281'..8 h 4-4280"Spt/eese ' 1 4327'165. to A 0,0 b Sc92'x.8. e,. 4—SSOC-Spueezed i":1/4 x x x —T p of P1vag mS722' ism k x £770' Norf.—Aft Tub/179 is 2 "4.7 W-8O 8R Rse A r TQ Sa00' v „fis'i+'.4':.'zer.."u.-warA.satura7o::A:14...4„,..uk.gFenow.„^„-• ••.¢aL .g,„':'L.....s=wmt :„,,,m'I,SS aktar....),Aav-utwA.•twA.':,.euo.!r,as.:+,1.'.:ssi.o.,,,,,,..raw.o.lsr..us-haft j_ --- PAGE I OF 2 WELL COST ESTIMATE WORKSHEET Pro-316-C PROPERTY AND// WELL NO. keic ya Pic, Pi '1-1 I - J Li DISTRICT � FIELD )P(u y 12,'a€f SEC. T R ESTIMATED TOTAL DEPTH ESTIMATED DRILLING DAYS OR TOURS pPepe fa C-946-2 DESCRIPTION 513t7(31well EXPLORATORY 1°4'1° DEVELOPMENT I TEM NO. IMOSOLE -PRODUCER PRODUCER I CONTRACT DRILLING DAY RATE 3S- DAYS @ $ ,...?000 PER DAY /DS OC' D 9O�top @ le,/800 1 /0 O PER DAY CXfYG( 7G�d 1' ES DAYS @ $ .'.3 aD 3100!) CONTRACT DRILLING FOOTAGE FT. @ $ PER FT. 2 DAYS @ $ PER DAY 3 COMPANY DRILLING LABOR DAYS @ $ PER DAY 4 COMPANY DRILLING SUPERVISION Lfs DAYS @ $ Lf 0p PER DAY ; 0O IR 1 coo 5 COMPANY EQUIPMENT USAGE DEU DAYS @ $ PER DAY DERS DAYS @ $ PER DAY 6 FUEL AND UTILITIES 2.5- DAYS @ $ GO U PER DAY r,,,I, 0001 I8)000 7 SUB TOTAL (1 THROUGH 6) $ IY 7,S06 $ $ 8 RIG UP AND TEAR OUT/MOVE IN AND OUT1ACL r-KO'1'itf. y,. 'Y14tVt 5.510C90 9 DRILLING FLUIDS +0 B ,cjq L/a UQ 6 3O/SO0 10 WELL SUPPLIES AND NON-SALVABLE MATERIALS (CEMENT BASKETS, /s DUO #/5-O O FLOAT EQUIPMENT, CENTRALIZERS-SCRATCHERS) . 11 TRANSPORTATION 5331 a•a 30/6p p �� DO O CONTRACT SERVICES AND RENTALS 12 DIRECTIONAL, TOOLS , SURVEYS & SERVICES (MONEL COLLAR, MULTI -SHOT INST. , SERVICEMAN, SURVEYS , ETC. ) 13 DRILL PIPE. BITS . REAMERS & OTHER TOOLS #5, 000 '1SCril-Ci' (HOLE OPENERS, STABILIZERS, REAMERS, DRILL PIPE & DRILL a 01!ltJtl- COLLAR RENTAL, ETC. 14 OTHER SUB SURFACE CONTRACT RENTALS & SERVICES _57, 490/9 /8,0U(1 - 6, 000 (WIRELINE PERFORATING,FORM,STIMULATION ,CASED HOLE LOGS ,ETC. ) 15 OTHER SUB SURFACE COSTS 5, 00 0 (SWABBING, WASHING PERFORATIONS, CHANGE OVERS, ETC. ) 16 SUB TOTAL (1 THROUGH 15) $ 144,56)() $ $ 20 FORMATION EVALUATION CONTRACT SERVICES CORING FT. @ $ PER FT. SIDEWALL SAMPLES @ $ PER SAMPLE CORE ANALYSIS 21 TESTING 2. TESTS @ $ 25-00 PER TEST .S,UC 0 WIRELINE TESTS @ $ PER TEST 22 LOGGING WIRE LINE ._ RUNS @ $ PER RUN 7..016V[' 24,rw0 23 LOGGING MUD DAYS @ $ PER DAY IIf O p U 24 TOTAL FORMATION EVALUATION SERVICES (20 THROUGH 23) $ ?j UOn $ .3c./0OO $ 30 CASING, TUBING AND RODS Z011CONDUCTOR L( 00 FT. @ $ .1 �r PER FT. 12/�(OO 137gSURFACE 26,0(9 FT. @ $ 1 ?. S-7 PER FT. S? `�Q 95/PROTECTIVE ...5-/: 00 FT. @ $ 4). 91 PER FT. LINER FT. @ $ PER FT. .5-7 u 0 OILSTRING FT. @ $ PER FT. 27/BTUBING '9000 FT. @ $ 1.(4 9 PER FT. )5 ,2►6 Z3/9 TUBING 54OO FT. @ $ 1.3) PER FT. 7, 2- 04 RODS FT. . $ PER FT. SGS RODS CAS 1/V6 Crews $ 1460*CO PER FT. TOTAL 13 4, 600 • 3)000_ PR0-316-C PAGE 1 (1500-CD-8-68) PRINTED IN U.S. A. PAGE 2 OF 2 WELL COST ESTIMATE WORKSHEET Pro-316-C C-946-2 DESCRI PTIO N EXPLORATORY DEVELOPMENT ITEM NO. DRY HOLE PRODUCER PRODUCER 31 SUBSURFACE PRODUCING EQUIPMENT CASING HEAD / 900 . TUBING HEAD 3360 CASING SPOOL , XMAS TREE lS`Q U` 0 PACKERS 240060 , WELL PUMP SLIDING SLEEVES. SIDE DOOR CHOKES . ETC. .?, Icy 0 6/.j/366 32 CONTRACT CEMENTING SERVICES CONDUCTOR YDS. @ $ PER YD. SURFACE �, SACKS $ 3, 4Or)PUMP TRUCK $ taco PROTECTIVE ?L'IC)QSACKS $ /1, 00 O PUMP TRUCK $ Roo 0I L STRING Iia O SACKS $ 6),S00 PUMP TRUCK $ /L 00 LINER _ SACKS $ PUMP TRUCK $ SQUEEZE JOBS 300SACKS $ / .700 PUMP TRUCK $ 2 CO CD OTHER SACKS $ PUMP TRUCK $ CEMENT BOND LOG RUNS @ $ in A/9 PER RUN WATER SHUT OFF TESTS 2 TST. @ $ 2S-00 PER TEST TEMPERATURE SURVEY 3 21000' 6,000 II, 5-00 40 FISHING 41 TOTAL SUBSURFACE WELL COSTS $ ‘,6 Irl v $ 29?,.cb ,Sr o $ 1, O-D- SURFACE WELL COSTS 51 SITE PREPARATION - LAND jV,00 b 52 SITE PREPARATION - WATER 53 ARTIFICIAL LIFT EQUIPMENT PUMPING UNIT $ PRIME MOVER $ 54 TANKS, TRAPS,CAISSONS & OTHER SURFACE EQUIPMENT TANKS @ $ EACH SEPARATORS @ $ EACH FLOW LINES FT. @ $ FT. ELECTRIC LINES FT. @ $ FT. GAS LINES FT. @ $ FT. WATER LINES FT. @ $ FT. MISCELLANEOUS 2201(;OCM 55 TOTAL SURFACE WELL COSTS $ 251 I O0 O $ $ 56 TOTAL DIRECT WELL COSTS $ CI/f, r E) $ ?.�$,SOp $ Sh soo 61 DISTRICT AND DIVISION EXPENSE p /f1, 3 6,.51 o 1(, S'bo 2, 6 vd 62 GENERAL AND ADMINISTRATIVE EXPENSECcJ,1,7Cr o 2, •roj� __ � - r- 63 WELL CONTRIBUTION CREDITS ?ea) Sle,d-c. 64 TOTAL WELL COST ' " , 19 0 + TOTAL TANGIBLE (TOTAL OF LINES 30. 31 , 53 & 54) $ 397,3(; O $ $ 37, n-o-rr TOTAL INTANGIBLE (LINE 64 LESS TOTAL TANGIBLE) $�,',?^ e4 J $ $ Prepared by District Engineer Area Supervisor District Drilling Supervisor Approved Date - District Superintendent rjoGC3 Sa,wey it)ch imp- 13.509 2,44 en.;) PRo-316-C PAGE 2 (1500-CD-8-68) 64 TOTIN U.S. .Q55- J \ 313,Sv0 . • 4 .6764-06,4 R►u er 2(-11 .- prr/l Savo // cord vac/ cJr2 )€. 'ay� �7c .10410 j Ex Ire_ La.o r , e)/dc �) Con-Jrcid Jr/,//; ► Sct�eiu[ e) egoo/do 7 Ca) [7,e/ � 0/(1/i, - Scyltic)) _ �c0/4ct 8/ Ri y M o u G /4-An fi GI/� u, crt zr �c .S = 3C� cTo-rr J 5-S,vary P, Mdue_ />j fief. 25; arra- & bvr!//nyaS /dU'CT f (S o k Z/d s) = 4 J,IS-0 — SQ y 1-/ J) 0'-C)'e-r- lo) welf Sapp/e5 4 nori So%Jo )j/e 2d" Rake/ Pub,/P„ Shoe -/[033 2o" - Ceolidlizers f to e 48 = 42,0 024 - paler 0 51toe 9.5-c 7r 1px Conor 9s-0 ►3 c-Peq-rr/P-tor - Say 3c) c'34 1020 So3,3 Soy ] xr y78 F/cal SA e 3.7) F/)4" colic_✓ 3_6z 610.9e «liar 1&30 Cen�ice�L��S _ -ya E'2,G= 520 7e, rf • 1l. TrcPrt,gip v_r /cP li a r? Le v Z - C rec.J diat7C 2- /rii9,5/45o 2 a_c_ 1_ 1-rr715- /day y sQ y L/ Ar 447 a r/264 r J a dq X 33—days 17, ro a //lc/4 (led f;,e/ pY / .3 '2 G - 4 u u' A 9 4-4" - li c row ekles : C cptr/ID /,1/ -2C G D X 8 zt- 17 6, 8oO HG co Ung/ P 54 3 u, 30,crozy /4) 600 Q`6d4 `Fift Tu 22447(-5.7av .�Bdv 4,,r0Q 1avofl) y3, 4luo Add d 't✓l✓ CP f-,-,e r] /J d d sic & /0 O e_a chi___ 15`c) off' 490,2vo 0r 1 Sb -tors ear) e c ,,a4- z I 1 O far, d4-1 S d ) S`oy .7 G@eyes duet f/ b ack, l a � �� 3 ora- = /2, coo Truck1 +rt�t S s r' 3 D0 oma- A /• 3 mo - 14-1(00o l (o, c-ou- 4 dr1` t /s-d�c/aC X 3 clgr./S 5) 2C0 5c 7.50 _says a 13 r Or fl')je L d51 YC�R�►-�9�✓ z Co,t /70/. 4 406' ) /s''6,-4 - 7� /-24" Acip ovene/ 16c0o E a ' 1./ 1ga 710 2G00' c-17k 5 7zo hip 40 5u66' 6 -l2 '4 " "c3 ____ oGo 4'0 : Its) (3. 3,41) 0 60 ty f Jars e is c yc l XJ 6, 1/4-0 12144" -6-.we tr coo �' P a-r�v r o v o C orhl, 2 01 v c� / 21 / /0 say S, �� 4S, cao • r 4,,I OMC r 5- S . Can/rae.I rPn/teej$- SerUrcrS M,z. c. ,-/y � �,'p P/_ Sh o P.S-0 .be C90 5 se.( ?Q evz4)-04.t c/olo [ 1 0 Pu -r 2� Sud,QK4o4 4'6— S my ?� a /c/ctyx �s Jo 7,s3 50 pa Ren /0l 0411s /1-{v �..1 C a I.Pvc 42 k Z '2"- 3, 25-0 J U - pY i Vin - ._ 3 U c.) /141 a >e t 2 T1s Sip 1--Cw,d /Sod 1 H-t v X I /y -S-c3 ocher efuip -fry,, l0 Iso ldi ,p/ /07s ,: perfrtd,�y 2Cp0o ' UD2 ) �o�' 9 e _ ' C_lR-/u� z `i 2a) 2� ` / 1 c,a 18 2 S e1 G(/),S @ �/O cT 2aec Sao e ,5--a)001 vD- cuLC! �.��) s-Bdot 2 vLi ) 7---o//7 x 4ht<s gCo o J8-51.01-f. . Pei `1crc' e 40o ' to _ X30 /6 4C) h.0/e.s ")v@ 18.50 = !co (o4 to c)0 s -foo 19 lor o C' 6D /z.s o _ to) , r" / ..57 6)19 SAY /� J oG,0 lJ O 71Aer S f, cc,s4s //�-1c�rc I s � Soty ID �r r 0 4 on / 2- 2 C20 = 4 4D cys "E-Y2 r 91'. e ao / a c7 13 � a eAoi Je Over d0 2,6 4 0 d .s`Q O p Z ope6 hole. - 2 5el-- 7.5 0 o v et:cc/4 d o 23c_43• Q!< (2.1-1- -4 ,20) '7-3c, c7' lol -Z Fl2c N t.-116 R_ FOC Cp.Co4f•sZ.o) 0 27( o 1,10 920u S-Lou .r,)L (Saoo)r(20 3c-oo) 04_‘:, X36 58C Srnc osut39� 1S/'D C24 x S'6 )4+.1 )47,f 2 t t"- F t7 c 407 • L c�,`cr Y (!o'/ n 3�o u)f 0-6 x a) ,sG 7-? .)77 h-,e)Ler �3 x-5e00) f I12s 4622x35-4? 2C 14 C pez f`ir 2 2/Oa ` J( 3 = 77 � T 7 / 07s x.04 n 1oic,00' = 74y 1 ,53 S a 2-of qtr 7 r1- 05—/ 7" O ��P/�C'r) Seo -- / a, E vv` /. Ccnfrdc_J Pr/y days Q ..?o co go/et-0-- c c/, Lc A r 3 0 too 3, cy-o-z,- 41 , Co br/y Sup2r uo i 9, 9r11Ji31 r/ui'c1<-• 2& x // Q c a, ace 30 4 t,— 11) Tr o 3 s �'�v = 151 c1 t ,r Trc tc s V e 3 a vv (r , c'�'<< � Sa s , .5-c) c.) 12 0-"-e-pz____ o d 13. Or-0 /!ne 6r Is Yea,-,AAAL '7 X211 6,' 1S 40 p = /0) CTa-Cl- L S kJ, C1.6--44-y JarJ /S-o/duy /2I.SlC 2 � � U 20 / JT�"'�t,`_ 5 G� 2 f p or► Q 3 GYiry 2 v vrtcr 14 • t%$'I!'f ren I a. (5 I Dlecc K ,?d `) G o p H0 ,-A--)co 13 od + Sos 3acc, = 43o c� Picky'," e Fo vd / o Soo 5�� 18) Ocnc s ,c-ea c) - l 0, e DD = S o cJ 0/).e4- .1-1.44k -474, I L )4'00 Pc _cG,,,,, N w/G R 6 y ip ,2,2 •7z I. 29 xSoc0' = ��I�v /. 3, ,X. /0/ 660 Rfri j ¢Z 7'°o 3-a / t o 0 Tone /4,7j .0 1.4 x t of - 90 232? 3 Secy 25; ocr V Foy D(lc?.3 Sitvi .5oo Sxs 25- U = � gao #0(4-.) /110 lnto # .9zo = 3 o S 3 7 a 5�y � v'�-r1— 2 3 / /67 T'' ' Ayy� ny 25 a ,L 2Q 3 _ 6250 let 0 EA 2 3 s 2-SO 6 Q // S 8 920 V•17 e 75- X (o 75--o IO) r 7 d Scy /(i troty 7-0- zpi p 1I, 5Co0 Q S -/- /D� eId) /Lima z6 F. "- 2 - /OUCH 16 f o GOI‘/Pe /u , /20 77 1c„ci- Ye0U e Zo / OU 4, SQU-- moi) Tr 2_ l () Uco-U- �� oma, S�s� .1G.coL, . Gf2-N c p Sb vo 92..to, X-.3 9 ' 19 Sa 5-e 60 iv J(. � � = 2143a 4toc � Perfr(' - SO©c orctif pecr�49e 2 2-5- ' yr foo h /Ps 25-0 J 30) n ! 7 0) 727. 7 ' 77 - ub�� Sao - 2 a x I � �9 - 6545-0s-Soo' -. Wiz " V 4. 49 = i3 (09S 3-0c901 - 7/911 X 1 ' 3l = 2 o 24,;765- - -2-1-1 (-1c) 0 ±31 citzr s r' C r w S Tu/"....> coke q1 croz -- Add '/ es-/- /co, ged e crr+-+7 32, 2- ,c '4° -47c- 140) ar-rtr- /I) ccrCr- o-ten- -(AL ) �t 5 Rove a 2 4 (-34 /2, rr Caor rjey- • rt5j 0 C.)C C/L2p• 14-60.2 heScVve.) 2 od Zr100 ! I 4 6 Kn(s1,Lry, by-Lew, Ire vve-o) 2 0 01 .= 33 001 I00I ± S Lo 0 — OIL FD c - C [az. [c, Rx))0)11-r STS/),/)-e/ 01 seed` 0IL 5 - l3l7tca ISL ^ Nf- w/C9- wS6 GQL (cue c Fl) 6 - Corti. F,i aJPJ /Ll/GQ c 2 r � . 7h„�ys 1a d o C o j'/ p-�YrU Pr7 - CGA-A_Abe i-f T1-Gc.Ar,-te n7S )lete".•--e-te /S/ uz>-o- -za d v-u- (45-0 d-?-1 ,Ar / r /5— POJ S 14 le cti fi Gf S e Q37 Pi2 a 9 i;-2.,1.„a0._ I . J - ad Ll • h 4113 "7"1--6?"-j4,111,6"-e- /.s C/% �J r 7e2Gkei-3 -''20/ eti- Feie/ — -u,Y� vN gG.r► Clew,./ e 40 '/0/ of 1- P/c,Q R,` /"?ooe 7-o field S/, 97 y f0 q 8, o a o - (d cfr. o- /i7 1i6,14 GAS,oozy— ] zy - /y� J 1 4 u 0 ,1 Cla v f� "IAA. / -/J Cof Taj' Qfb 1 I P) crr it -' )4 IA;v Cep /C'8o # (d 7-o Iso c) 2 r a o 4 C.-- %,z.I 4 Po 1-3 .Cal.` 0,acv Fac.A n , Q—e/Q � J/dt�)-- -)....4.....4._ -1. dye l rM,7 )v o i,, rRu 3c.,0J 1..c,- (4.9 ,-7.--,-...4. Jri ciee "`f c-'/Icoy 1'r /i /ir 5 a r7ra..E ( ) "2-y - 30,uv-rr- Say r3 U, reora 2 C O. 42r/y .7cPr-.a cr -76-i-,,,t„..„.. -, 4(o -._ l.iC, /Lir — ,-00 oy f:),,. e cc.-) Le &lc, cia..,/Sny • • . . , i 1 r.;tr.r,••••r ,....--...f.:•rt r•-•- '..•, 1 (.` CU \'E . ,.,•t I...i N.3 4....-....,..,---....,.•.......,..-..........-7:. ..ta 4 I...Wm a no Ii i r am.•••.1.1.414 $ i •4.) ',.. ••••.‘t...1-0 ,.,..1.--.. 't...C' I, I) "1 . . •. 1 / '.%.l••.. ,.......1..........yrsay....r.esimmereanaa...........nelea.•••••01•0 r? t- tti . . . .i ,_.,„„.,_i , .., I -1- . r---------4-- -7-77-71--77- rci-i-1 i , .7-1-7-_-,--.77--- --:-,--17-17,111---17-:. --T.Tr • ; 1 ;-.-" 1 .4 -- ... - -• - - ;-1• ; • -H. 1 1 - ,•, - •, 1 . I , .. il . , ; '.. . .r,i .1 : . 1111 : - Hit "t-f •-1-1 •1- _I 1 I I ! I 1 • 11 ; IP I - u _. . . . . _! ._, IA.1 Cr 4(.?. 6 (.1 Fi it/51h;;.,1 '.1012i.6.:. j 11.1-.1.1 : ',-1 I It : I I i " I.! '11L: ,J,. 1::. ' ,.' , ••-i-II : 1.-,--L. • ; ; ' i r ) . ' . , -;-. ' 4 ' '. I 1.-11 . 1 .._. • ; , . 7.... 1_,_7 1 ; . ,. , ' 1 3 t , 1 . I.1-3.1 • : ' : • • ' $ 1-1 i 3 I Li 71 '1 1.1-1 . ---7I ' ll 11111-1-1- 7. 177- 1 ' " 1- • 1111H1•11 I..; 1 : ...i. 3.3 ; • t /-; I. I-1-1 j 1 1- .7,3 ; 77-. •••i •1 ; 1-• 1- - t-I 1 1 -1-1-7 r 1 i' •• •i•- • ••. I-• ; • "1 ii.1, ,, H.... ! pi , { ; , { { 1 ... :.1 . .1 { •_LL, if ; .{ { till . 1_. • 11- 11 . ....11., -I ; ... , • 1, .. , , i . 1 ._ , I • • 1 '''''i-• '-•-•-:-' ' -L-11 • 11 : -1 ! •-; 1 2 ' •''-!, I .,-I, ', i • • . i-I : : i ; I ! I -- • •-t 1 - : '-• H., -; ,--I ' 1 • I. ,.. , . .-I-•-.: ; ;.;.t '.. , i 1 . i I ' • • ' I . . • , .. • -•-t •" •-; i t'.": 7- -1--• 1-1-I 1 I t • 7--I---'--• I • • 7 I i : : I 1" • • • -•- • -71 7 1 • . . . I . . . 1 I 7! 11- -: -1 71- 1 : 1 . ; ; 1 1 .-I ,.1., , 7 ' , .31 ; , 1 : 1"1 1-1 ' "•1 t I III '1-7-1 '.I 3-• I I •-1 • I.-1 • -1-1 1-1-1-•-'-1 1 ' I , i ,.1 .i _1.3 7 1. . .. _I 3-1_1,, 1_ - -7.. . 1.4-1 ' -1 • •-, 1--.-1 . •-1 •, • .3 1 j 1 I . . 1 . I 1 I 3-• •-- 1 ; - „ . i . 1 7 _7_7,4 i_ , •-I , 44-, r f• ip.1 , ., , . :_•. •,,, 4-4, , I -ii , . . "12, ; ; ! H-1 -'- -1-: -' I ' -,' I '-' -' i -I 1 ' , . I I I-i ' i-] 1- -' , i-----1. - ' - : Tiii , j , : ; . ; : , ',- -il-i-r i-• ; ; - , ; ; ; ' I. 1.LI 1 .; - . '.;-:. , '.. 1 . --;-; ! -1••••- '' , ' , ; ' 1 I , '•1•I /-" • "-' ' ' • •-; -, 1 ''-• [-I i ,-•-• • I I .. I ._,. .4.__•_. .71 ...•_1 ._.......', 1 i.4 : ',...._ : • • .---1-,-,-. - - - ; 4-1 • • .-. I-; •-;-..- .-,-. I I-2, --. 1 ,---! -I '---; '•-' --.--; -, l '• ' : 4 1-4 • ' 4 1 . ' ' , " . 7 : 1 . 7.1 : 3.: 3 ' 1 ' t..7.__':/_1_ .7.1__1_: 1.1.7 1_. -t ' 1 ' ' ..3.' : ' 4 I-•.1.• . 1 !..! 4 ! • • • , i .; '._- • 1 ' ' 4 ', - 4 • ] ; '! 't ; 1 ' ' ;_i., ', :_ 1 , 111 Iiii • 2:0 0 0 ------ ----1-1- • ' -1 •I -----t• 7- ' : ' • , , Tk ... N f ../ •,,,,-....,-• ,--T ti,,r 1-; ;_,,-• • -, ..,...._;_. . i • ---,-- --: ; ; :- I I Ohl,C•110?,13-.•••t l• li LI rot 1-:). -'?: 5c,- - ,un (1-P L - - 1)1S-1; r f.?!-'-i ;-, • ;-• •-- •-, -; --i-t -,--- ,-' • '-` 1,•)- 7; . L'' ) • ) - r ' -I 4-!-1-1 -7 !-,-- ' T 7--:-';' 11-1 1-1 17 1-' 1 .1 I .I i : • !-\. , 1.-1 ..J ' 1 A ,.--i..../.:11 n , 1_, r;-,,,• , '--,, 1 7_ 1 . , 7 . . ., ,' t , •-1 :1 '. ,' . . • ', ! - I-, , ! i Li ir , . . Cm4 1 n /•?!, (....:.-sici t, Kcy,r) 0 1-')E__, , -:, 7 ', i ' • ' ! • 1 . • . 1_, 1---. . . . . -1---. , 1-: Li . • , •----:---',- ! " , , -. 1 . , 1 l I 1., : • • . 1 , , . :_:,.-, ',.Ti !' ', Li , • '. ; 4 -! ! -, , - f-• -; ,. . . 17-1 -, , ,--! ; . . 7 •-• I-•-•` 1 1 1 '-,,--Irr•---: :-I- H-' 4 ' -"'- ' -',-'-I-'- 1-:1-; 1- ,-..- •-•--r-i-, . - - -:-t -, .- 1--] !--', 1-;-;-:;-; ; ; • - ; •-- :A ; - , • " t 1-I 1-r-1-:-'• ; -• 4-,--,-,.1 7-- ' 1 3130 0!----.---7-'----•'---- , ' i I , ; ' • ; , --T-• ' ' : !-- : : • . . ' ,-; ' ' ' 1-• 1- : -r--, i i i : •••1 . ; 4 , - . --, , 4, ,-!--;-, I 11 1, i , --;-' , ' ; • ,-- ; I , I , ; ; ; i .1, 4. , 11 I- I : 7, : -7 7. • 1 / 1 , 114-13 ' : 1 I I -. ii-11.,-..-I ., , 1, ' i ; ',. • ! .,--, ; : I I ! .._, 4._. I.7 1.4 ',L.: ,.. ---j--1 • ' •-1 '- t '-1I '•; '-,• ' ',--•,-11 !, i----i-i- 4- ------ ,-,.- ; ; 1 ;-; - , , 11;; r 'll-f , H , 1 . 1-1 , I ' , , ii, , 1 ,_ __ . 1 h. , , . i ', i;1-1-,-`•;-•- -.--',-4-; , ;.1 , ; r; , , ;.-7 , ;---1 - ,--; -- ritHf : I • , ,-, . , • , , • , -: ri . -1 ,, --'-, 1 , i ; • 1 1 ' r . 1 'l t ..• -i . 4 ".,1 . , . • 'i .I.1-.1-; I I 1. .' ' ' i-r 1 1 4 1 ; '• ' : 1 1-44 -7 • -; : i : 1 ; • 7'71-1 77--17 1 ' 1 1 , ,1 : - - -_,‘1 '..•:_; -.._-'-_ -:.J._ •.1.1.4, ; .',..I . , • i I : . I • • .1--:- ! : •.-, , , . , ,1, , . Oa _ •,,, ,., . .... i : 1 1_4.-I I ... I • 4,-2. ' . ' . 4 4 '. ! ,--2, ' . , 3.1 j 1 • ' -•' t 1 , , , I ' • <1.00Cr_t_i_j_. __3---.-_,- _._3_,-.3_ k V.___L •_,..... .. _e. _Iy€____,-....).pu_ _.........:__,,__;_ _;___,.__.;__;___,__ , _____,_,....__• , ,_______; ---i : . T . -F • 4 , • 4- •,-,- • - 4 --1 1 ! _ III 4 •- . ? FI -:-1 --i-,--!- ; ---,--t- • - ; ,---r;- .!_,. 1 LI i : i I • : 4_1..,..-;-4-.1 - 4 ,--: ;-4-L I t 7 3J-4-4 -• ; • I s -4-' 1- ' 1 "7" 7 ' • : ' ' 7 • . -,..orSt••••)-'AN!\'‘.0%. ' !. : :.! : I. , ,.!, i_;...i_L__I r, ; ' !, ' r 1 1 1 , 1 ; r , I ' I " , , 1_1 !--i ! I- 1.-1--I . •-; .; , -1 .-. . ; • . 1 1 1,-1 , 1 1,_• ' 1 , . \ ! , , 1 • -I, . %,: - I ; I 4 • 1 I .1... .. i .... • „- ! W1-1-1 . 1- 1 ' I ' . 1 . 11 . I . . 1 1I1-; ; ; ;-: . ; 1 1 / • 11 '' • • 11 '1' 11-:-1: 11 i ;i1-1. -I : ' i ..-• 1 1. 1! ' 11- i 11't 1 .1 . „ n . 111 , 11-, ! , J. H . 1 1--' • -.--1 1 1-71 ' I i •••,y, „„, . • , :,,_„, i , , . , . , :_,_ • ,, , ,.., : . " _,•••,,,_.., , , ..,_•,.._,. : Li: •, • . , , ....: . . . ., , • . ...• .., .. , 3 ' 1 ,-.• , -I--. J ' -14 , -7 1 , . 7 , 1 " f --1 , • , „ .-.-' -11-, 7 7 3-• . . . I I , . -1 , , -t ' --j •-, •- 7 , 7 ' ' , 1 ; I L! ! ! .: I , I. '...I.: I 1 I-I.I 1 I ,.1_1_I •.1 1 t 4 • ; r r ... 1. I I •-! •-; 4-1 . ; . : ' I. ' r-T-L ' Hi'f ! iI . i4-1.--! ! '• 11i : ' ; ; '' ' • ,,,,„.._,,., . , •:.7A1 Ulr.J-----!--".----.--r--'.-----1---r-1°- --77-'-`7:---" I •-•'-'- ,----- ---. .4.- , . ,-;--r----,-,-:---7------1-±"-'-' I 1_1 i .11 1 3 1 11 ' : 1 -• I --7--7. t 7 3., . , 7 ; 7 I-1 " I „ , i • 7 - I 4 . • • . • 4 , , • L.4 i ' ' ' : ,_, .I j• 1 1 11 7- -'-! :-' • ' • • , 7 ••, • ••'t ;-' , I-i-1-7, .,; .; , 1 , , 1 • raj li , , , , , . , . , . , :-. • 1 . ; , 1 , r , , . rrf :--i : , 1 ' . , . „ , ' !t !;! ; 1 1 ! I-II • .t. I_; . I • I- •• !-- -. i I • , ••., t.---I .- ,--, t t , , .-a s I f . ' ; , I ' ' ; i 7 : -.L' , .--'1 : '. .:"-I 1 '/-'1 r. i-...-"'11,---,? .... L: C•72- '\ . .11 I t '1.-- t`'I' - .A r `J''1 '•a- - ;-.'-otT,'..)..t.•?)..T......- 1 ,- i ' '2-1 1-1 7 3 1 ,-• 3 ' ' , T 4, -, ii:, • .. , . / ,i.! .1 ., ! , ; L • .1 ;_;.,: :._: : I ; ; ; , ; ; ; ; , .., . J.:. ,. •Lak 1 1 • . , • , • ' TI.,.. . t , ! . '_I . , r ' ' r ;_ '• ,. . ' _'.1." ./-' 1,)_I __ ' 1 G000-':-'7-; !----' • -1 '1".• lr..i)r) ..,..0 ii- ----- ' -, ''' . ' , ; ii I • . ',- , 4 ' . / I- '' •-, . . , • i ..,1 '7' 1 -• -: 7 .‘, ; tI1I-1-'-' -71 ; ' 1 1 1 - • • - 31 ! !"1'I- , '1; "71 .1•1-F 1-• ' I ; •'; 11 I 1 1. ''• -.1-'7.4" 11 :•'•i 1- '; -1-I 1 • " I • 1,'-' • __,_, A. \71, , 7 -7 I ' I 1 •-- ' -• 1 • .-. 1 ' I 1 " I , „ 7 s , • rr..i -- '-1 '---L4•-•tli. • i' J, 1 ' '• .• H-1 1 1 tl ' Fl ' -; -I ! . • ' -is'- I- I '•i ' !.! ' ' `-1 ••-1 ' ! • ' I l•-• IT.; 1-, '•: ' ; , . . ! ; •-, , .:-!•-•1 . •",•,'I • , : I • . (I • ii I 1 i ; ' . r r . 1 ' 1 , I '- '-. -` ' ' -'"!r--!--- ,--. ;--: ! r :-1-- -i--•--•-; kaS -,. i -.- • :,1 1,-' ' ,., : : f- I ' - FF - -! 11 TIT'r1,....I....f., • , .i ! I --1-' V- , 1 ; . , . ' ! , • 1-. , 1 ; ; ' i .. QI_. I 41,-1 '' •: .41•-I,Jj . I 1 i i ; I .1-1 !, ' 1 i-i-.1 1 ' ! '. , ' •!•-! •,••'• ' 1 - . 1 . . . ,,.....• --L------L---- .2--..---,________:_i..._. ' .-:11____ __(.1_. 0.;1- \11,C,- -P r ; • 4 • ' ;- • ; ' ' .-• • - - __..._ _,_.._ •, .-, :- -, ..,._ . . ,._, ......H , ;,‘.1 , ; • -i-: : +-. i ,.. --• _ 7 .' I ." ' ; ' :• •-•“ r • x -.-! . • -• = il , , . . . , . i-4- ; , : '-• 7 -' 1 1 . '.1 106e17''' ; "" -I": • I-1 7 • '• 1 • . IA 71 • 1 i-I. I . ,_ , ,.•,.. }...; L.1 ; ; f.,t I I-- ri , I •+,__1.1 , I.; r ..i . ,: , ! 1 -1--,. , • • j ' : ' Ir.: I, : ; r, ,-, :4_, .. . , 4. . , ;- \ , .', , , ; i , ; 4 I : 1 .; ., . , i ; ,.!.1 : .1 i-_, . ...,.. , , , ; El -,-;.--.---. -..-- -i -..-1---! 1-,- -; ,-- -. 1 , \ , L-- ' 11 L. i 1 1-= i . 1 t- 1 i- • • 4-1, 1 --•-4 ;-, , . : •-'- -I--1-1 LI -• .: : ',.-'-: --i-1- -i-1--:-ri-1- , ,-I-;- T - ; , ;. 4 1 ' • ' ' . ; 1 r ! ; 111 :•• , • ; • , ' •••, -1 -• : j ' ,.! ! !--", CI l-1--1 . . Ii--I ; ' -,--!-, : 'ILI . I I h! ••1 , ' : 1 ; 1_ i -! j-I • !--!•1.1.• ' !_•:-.1- -! :!_i-.•_;',--_,' ;72:; . -'1:-'-'.-- -H i ! ..I i / !--, , ;-:- L... ! - ---1-]_' -- - -• !.--- , -- •--- ! , , • . . • . 0003-----------.; •,-- ; -- !---H--; ; --;-:-••---.--------•-.--' •• -..-;------.4 -4-------,---•,-.-------__.._ .-r:_...,-- ___....-- t1 •-{ - • 1- . --,--; • ' -, i : •-•-• • ; '-'• .1 ••• ' , , „ . I , 1 1 r-S. . i 1:-.1 .-i- -.. ". • i-‘. 1 1-.".'.-1--. --ri---; 1-' ;-;-:-;-; '-:- 1 "• ;V ! j -; i---:--I L -,4,1.1-- , . , I , : : -: r • . • -. , , -, -r r.r. • --r, r r - I.r i. r , I: •--r. 1-, ,-i-- FT 1 I : "--. • ' -'• ' . ' ' • 1 1- 1'. 1""" I • r; - -ti I- • -.,, ;.:--,,-.1_,:-.T _I. -,- _12 , , •_' , ..ji‘..;'_' .,!-,, .,'.--_-r.',1-: .. ,.. 1_.• _:. .,___L._ , . : _, : i_. I ._,_ ._•- • 1 ,, !-• Ii,2 ..; :_,,_ ; :.. '___11...!„. ,_J.. __, ,.:_i__._.,.., ' , __.,_.:_ , ,........ , .._ ; : ,,..., ....' ; ..: . .., ' 2_1 ' L. L • '. ` i r I-, , ' • 1 I ", • . ' .'`';, . .,_ . ._, , i _ ',--, ji ,, 1 - • • I -•,-•-'- -;-, •--4'• -\ r : •,- -- ,- I 1-. • ' I-1 1--'. 1 7•-•• 1- • •-- •.-'-r-,-,-,, .'-,,' -.. 1-'.. • "! , I-7. :. III -.,-1 '-- : ,,' ._•_. !_. . . . L .i_!r'., L. . E : _,.`,._. • ;.,. , , ,„ _ ; , ..„ . : - c•c,-. . t :._;. . . : 1 . ; ; _., . . , •.;_: ...... ., • . • .. . . . . . • - : , : • - - 1 - -, -,_ .: , .1 , .), r--.-. _; _1_, , , ..._. . .: I ,,..I_i ..1 , , IA _.. . ...J. : . • :„.., 1 : .,.,.. , : 11 t , . . C , -4-1-- ' - "-- -"- ' •-• ' • ' 7 •--77 ' 1 - '\•-7- "-I '-• ' ••• 1 ; ' 7 : • 1-' • •- • i ''''- !-! : ; I • : 4' ; , "1 i --i ' . ' • ,- '!-- - . 1,-; '-• ' r ••^1-.- ' • -- : , ' 1--• '''. '`, •\ - 4---i 1 ' ' 1 : " .' "-; ', .. ' '. '-', 1- • i i '-h--, 2" ' -I :-1. i i... 1-... i • ..... . . : , i • , , . • • , .. _!_.. . . i.. : i.I t 1. ',.. , ,_.. ..L.: ....; t ; J._._: , , :,..,., ..4 1 . - 7,--. •-t-,-1.1 , j -7-1--j 7•, '-I,•- • • • -.1 -.4 1 j,1 , ;,_,_7 .,_7 I ,_. _ ..,_ . _...1 1-' I • -I-, 1,.1-I -.. --:-.--i •,;-/ .. 1 1 i. . 7.1 - . • , • . • 7 i . i 1 , 1 • -; 1-11 7' LI 1-." - -1 ' I-1-'71 ' I ,-• • 7 ' 7 1 ' 1 / 7.' ....1 7 , . • 1 .., -LI': ;• • ' • • ' I . • -• I--, 1.I ' - :---I I I 7•.7:-I, • 1 -N-.,. .--. ...•.. ,-•-i 10;300- --,- ---, - - ----• --, , ---, - - - ---, --- -. , „-- -------- ; . . , „.. ..., : .. ., ••, , ,_• . ••• , . r•• • • i- ; I - : i .: • •N. .., : . : , 171- , 7 •-•;-:• • • 7 • •• • 1 • • '"-• ' • " -i . . . .- 1 7 , 3_1 .. -I 1.1 i ..,-. !.. '-. ,.r , , , .., . .. ., . . , .. ,• ...• ., r , r., i •-, • I .-1,-• :- • 1 • -• , • i • • • I-I : ..• • ' 4 •, '-' ; - 1 I ; • ; ; . • ' • ' • I 1.' i ,, L ' • • I : 4 I . ' • . .1 •,-1, •.:-: : 1 ‘i' I I.'1 1, -1'!-r- r 1, ., 1 , loir•• , • • -• 11-11..`111 11 , 1-1 ., I ; •\• , 1 , - -1 t' t•Ii .," ; ; ' : ••-•`;')• . . . • { ; i , . .., ; . , . .- . . . . ;. 1 I 1 1 ' )•;{ •.1,C.:15:-.;_11.:.,I LI ,-CVY)A -- - - - --- - - - - - - - - - - - - - - - - - - - ---- - - • ..; : : 11 , ! . . • 1Iiipit6 . .! . ' i ' - • : : • 1 • I i ! i •-, ; ji . • ; . • /- . • : , . . . . • , , , ,. I 1 ............ ._____ 1' i i00.0 . • - '- •i • i • , • , • , • : , 1 .--1-:-7 ,._,_s. • ,.... -.if- ---.---r).-- -10-z , . . .... I i ! • • , , . . . • ••, . , . . . . , • , ,._._ • 1 I Y1"/-, K:1-1i1 1 '4)(....., (I „ . I . l a . . :. , 1 1 r . 1-‘,.. • t . r ... ..,• . l' i , : . ; ' , . . : . ,-I • . .. : '. i . ,.. I ! , - ' 1 , 4 4 ! 1 ' ' . f 'r : : ' " 1 ; 1 ' : " ' 7 • " • ' 7 • I • • 1 • , 1 I • 1 i 1 . : 7 ' ' 7 7 I 1 • 4 , . • . , • , , ; , I . •.1 . . • ; r " ', I * • I ' „ : I .. '• •• 11 ; . ' , 1i ! : '. i ., • I rr • • ti 1 . . ; . ,C:f•'-) ..).1‘.., ..•4 C-....' • • • • • • • • • • -• i i ! : i ., ‘ •• . . . ! • • • . I • ! • . . , • . , • • ' . . . . I • . I • . I I ', I . . . . . ' i ., • ! • : • , • , . 4 ' , , : . . • ji .L . . . . 7 • • • • • 1 1 1 • 7 • 7 ' • 1 i 1 , ; • I I , 1 , 4 . . • . , . -, ; , ; . • • • 1. : i . : : . : ,, ; I : , , . , . , , ; . ; 1..1 .-...-00.;,, L.L......2_,_,....:.,__. _.„..., 1,,.._ _ . .___...., ...1 . ..:._._:-..--- :-., -......-:.-_,.-_- . ---,-. . ..... --.... ,, •_......•-. ............ ,.._,...........-______._ ., 10 20 .' ,%0 •,0 60 t U .1 0 80 • . • . • . . •. . 20 " F 44/ 13941 " 2(a00 ' 68% l<-SS LT,<< L✓/2'2Up S 9/ s c.)1 1/3.S #/4 ,' — 1-15'(c 4-)/13d 6 f v 9 1 0o S x - 270 o @ 1E . x Lys % / ud ' L7 / L 0-1-7 13/9 ' , / 00 0` 7- 3 6 o 3 ! Z p i 57- /11 2 JL 7 I Sct� �cdv 9 / rc 5 d0 ` (ft- ) d ,er Co 7s9 sd LO-O 0 2E e 0 0 :Beluga River alt 24t-34 $.fandard Ot i' ~my of iai t for~t a Parrot t H'c~ 72-16 Standard gl t ~¥ of Cai I torn i a P. O. t~x 7-8~9 Anchorage, Alaska 99~i0 A~tn: C. V. ~atfe.rton Gen~t~: Enclosed t s the approved app I i cart on for peril t to drl t I the above referenced ~ell on or a~od June 1, 1972, at a location tn Section 34, Ta~$hlp 13 N, certified s~rveyor*s plat ts required, he~eve.r. Pursuant fo 11 ~ 206t, ne-ttt~r the bottaa hole location of r~r any pay opened to the ,ell bore in the ~RLf ~. 241-34 eett shal I be nearer than 3~000 feet to the BP~ ~. 2f2~-:~5 ~elt or am/ other ~elt,. unless (a) an exception to II AA(; 2061 Is granted by the Committee, or (b) ~be ~ Noo 241-:~1 ~ell, roi lowing a pool rule hearing, Is determined to be completed, suspended or abandoned In a poot separate from that in which l~e B.P~J-- No. 2t2-35 is complel~do A pool rule hearln~ for the Beluga River ~ Field wi Il be cai led upon metton of the Cammlttee roi Io~lng com- pletion, amspenslon or abandonment of the ~ No. 241-~4 eel 1. l~any rivers in Alaska and their drainage systeas have been ctasslfled as Impor- tant for the spa~nlng or migration of anadrom~as flsh. Operations In these areas are se jeer to AS !6.05.~ and the regulations promulgated ?hereander (Title 5, Alaska Administrative, Code). Prior to o0mmenctng operations you may be contac?ed Dy the Hablt~ Coordinator's office. Department of Ftsh ,and Game. tn the event of s~spenston or abandona~nt please give ?his office adequate advance re>ti ficetlon so that we may have a witness present. truly ~o~r L. ~rrell~ Chairman Alaska 011 and Gas i~onserva*ton Comatttee Eric t os ute cc: Department of Fish and Game, Habitat Section e/o anti. DepOt of Env!~?al Conservation ~/o enct, Por~ P~I (Other mstructlo, reverse side STATE OF ALASKA APl NO. 50-283-20038-00 6. LEASE DF2S1C;NA'rIoN A3qD SIU{IAL NO. OIL Al'ID GAS CONSERVATION COMMITTEE APPLICATION FOR' PERMIT TO DRILL, DEEPEN, OR° PLUG BACK A029657 ~l~. ~t~'~]}'{{ OF WORK DRILL ~ DEEPEN [] PLUG BACK [] 7. IF INDIAN. ~. TYP~ OF WIILL OIL [~] O&8 ~] IJINGL{~[:] MUI.TIPI,E[] ~gLL WILL OTHER ZON~ ZO~l 8. UNIT~FARM Ol( LEASE N~ME NA~'iE OF oP~TOR Beluga River ST~DARD 0IL C0~ 0F CALIF0~, WOI. ~, ~L~O. AD~ ~' o~,~'ro~ ' BRU 241-34 P ' O. Box 7-839 Anchorage, Alas~. 99510 .,. FIELD AND POOL, OR WIIA)CAT LOCAT~ONO~ WZUL ~ ~ ~ ~n ~ ?~ ~m [~]~m R]vmr mt~Aoorox 900' South and 1.400' West of Nor~~ ~=he~ '~?/ ~~%r]~q A~-~ S%%~'as surface O~- 'o~')J ~,.~c. 34,T13N, R10W SB & M Approx. 40 miles West of Anchorage ~,~,,~.~>~ ,.~ <,,~,, -,;,...-~J~ ,-:.~.- /' "'~ ii. BOND INFOrmATION: ,%2~(,~(,.~,. ..... ,,,,,o,=,t $150 000 NO. ACRES ASSIGNED TO THiS WELL 640 20. HOTARY OR CABLE TOOLS Rotary 22. APPROX. DA'IE WORK WILL S'I'AR'F* June 1972 wYr~Nation W__ij_~.u,'ety and/or No. S_I~'205862 15 DISmANC~ FROM. PROPOSED* ~- .. . ~ ~ __.. __~1~ NO. OF ACR~ IN LEASE (Also to nearest drig. unit, if any) ~-, J ~' ) ~ ac ~ O~ APPLIED FOR, ~. / Approx. 2,:].00' See attached Plat [ + 10,800' 21. ELEVATIONS (Show whether DF, RT, GH. etc.} Approx. 110.' K.B. 23, PROPOSED CASING AND 9 # o 1- ~~~' 43,.5#, -'IN-S0 IN-80 ;EM ENTING PROGRAM + ,4_00 ! ,.3oo' +~00' + 10,800' .-,~_ j ' QUANTITY OF C~:MZN~ I + 700 sacks '' 4~!'~r~ ,l sge-~e:~w* ' fl ~':,, Either 6 5/8" or 7" liner will be run if lower objective is found productive. Cement volumes will be dete~nnined after productive interval(s) determined. Ail productive zones will be cemented across and the Liner Lap will be cemented. NOTE: The subject well is proposed aS a crestal test of the Tyonek fro. "D" sands at Beluga. If productive this will be a new pool discovery. If not productive, the subject well Will be salvaged in known productive Beluga River Unit sands. Should salvage be necessary a variance to the spacing pattern and distance between producing wells of less than 3,000' is required. A variance is in preparation. We have requested USGS 'Approval subject to variance approval. It is proposed that this well be drilled per the attached drilling program. 11~ ABOV~ SPAC-~E D~BE ~OPOS~ PR~R~I: If ~1 1~ to dee~n or plug ~ck, give ~ on present p~uc~ive zone ~d pro~ new produ~ive ~ne. If propel is W drill or d~n d~ect-onally,, give pe~tnent. ~Uq on subsu~a~ l~t~ m~d meas~d and ~ue ve~ic~ dcP~. Give bl~ut preventer program. 24. 1 hereby ce~tIy~at~e F6r~ging ia~Thn~ ~rre~ S}O~ ' ~"/¢~'' ~ -~'/~]~:f'¢ /(%' DA~ ..... rI~ District Superintenden (This space f~t S~e office use) CONDITIONS OF ~PBOVJ~, ]F ANY: SAMPLE, S AND CORE CHIPS [] YES ANO [DI RECTIONAL SURVEY RF,~UII~cED [3 YF~s ~, NO tOTI{]/~ ItEQUI IIF~MF~NTS: SEE TRANSMITTAL LETTER A.P.I. NUMiERICAL CODE ~ROV~D^'~ Mo£ch 29. 1972,, maws March 29, !9.72 PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM FIELD: BELUGA RIVER PROPERTY AND WELL NO.: BELUGA RIVER UNIT # 241-34 LOCATION: Approximately 900' South and 1,400' West of the Northeast corner of Section 34; T13N, R10W, SB & M. ELEVATION: Estimated K.B. is 110' BLOWOUT PREVENTION CONSIDERATIONS: 1. Potential Problems: Gas: The propOsed well is a crestai test in a known gas field. Numerous gas sands will be penetrated during the course of drilling this well to total depth. Gas entries ~nto the mud column can cause serious problems. Care must therefore, be exercised at all times to prevent gas entries by either swabbing the well or hydraulicing the formation (and associated lost circulation) on trips. Rapid penetration rates cause an increase in mud weights and increase the risk of lost circulation and subsequent kicks. Penetration rates will be restricted. Coal beds at Beluga can cause serious problems. The beds contain some gas, slough readily, and drill rapidly. If thick beds are encountered, reduce the penetration rate and/or circulate bottoms up. Extreme care must be exercised in the drilling of these beds since they slough, and cuttings tend to pack off around the bit. This pack-off can cause lost circulation, kicks and a stuck drilling string. Lost Circulation and Water Entries: Lost circulation is believed to have been the cause of the blowout at BRU 212-35 (#1 discovery well). Too rapid a penetration rate caused an overloading of the mud column with cuttings followed by lost circulation and gas entry. The most recent well drilled at Beluga~ South Beluga River Unit #14-3, was drilled to 10,000', with 76-78 pcf mud and from 10,000' - 13,000' with 80-82 pcf mud. There were no gas kicks, lost circulation zones or zones of water entries. Penetration rates were limited in the top hole. Precautions: Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these methods. Care should be exercised at all times by every member of the crew. The hole must be kept full at all times. Proposal For Well Operations PRO 316-1 Drilling Program -2- March 17, 1972 2. Anticipated Formation Pressures: (based on 0.47 psi/ft, gradient') Zone Drilled, Dep_t_h Approximate Pressure, Top Sterling "A" gas interval Top Beluga River fmo Base known production Base Beluga fm. "D" Point "D" Sands T. 'D~. 3,000 ' 3,400' 5,200' 7,900 ' 9,300' 9,600 ' + 10,800' 1,400'!" 1,600~/ 2,450~" 3,700? 4,400? 4,500f 5, lO0# 3. Maximum Anticipated Surface Pressure: 3,000 psig. However, if dis- covery is made in "D" sands and casing is set, surface pressure with gas column could be ! 4,500 psig. 4. Blowout Prevention Equipment: a. 20" - 2,000 psig, Class II B on the 20" casing. b. 12" - 3,000 psig, Class III & Shaffer Rotating Blowout Preventer on the 13 3/8" casing. c. 10" - 5,000 psig, Class III & Shaffer Rotating Blowout Preventer on the 9 5/8" casing. OBJECTIVES: Sterling, Beluga River & Tyonek formati.on "D" sands. PROGRAM: 1. Cement'36" corrugated culvert pipe at 10' +_ below the cellar floor. 2. Drill for 20" H-40 casing to 400'. Cement 20" casing on bottom with sufficient Class "G" cement to reach the surface. 3. Install Class II B BOPE on the 20" casing. Test as directed. _ 4. Clean out cement and drill 17 1/2" hole to dull bit near 2,150'. Reduce hole size to 8 1/2" and rat hole ahead to ! 2,400'. 5. Run and tape the following logs using Schlumberger equipment. Ail logs to be run from T.D. to the shoe of the 20" casing. a. Dual-Induct ion-Lat erolog b. FDC-C~mpensated Neutron with Gamma Ray. 6. Based on formation evaluation techniques: a. If sand interval equivalent to 2,520' - 2,580' in BRU 212-35 appears to be gas bearing: 1) Lower 8 1/2" x 17 1/2" shoulder to a depth equivalent to 2,505' in BRU 212-35. ~ Proposal For Well Operations P}LO 316-1 Drilling Program -3- Ymrch 17, 1972 2) Cement 13 3/8" casing on 8 1/2" x 17 1/2" shoulder, through a triplex shoe set in the shoulder with sufficient Class "G" cement to reach the surface. 3) Install Class III BOPE and Shaffer Rotating BlOwout Preventer on the 13 3/8" casing. Test as directed, the BOPE and casing. 4) Drill out the 13 3/8" casing shoe. Open the 8 1/2" hole to 12 1/4" from shoe of 13 3/8" casing to a depth equivalent to 2,580' in BRU 212-35. 5) Make a drill stem test of the open hole from the shoe of the 13 3/8" casing. 6) Proceed to Step #7. ' '. b. If sand interval equivalent to 2,520' - 2,580' in BRU 212-35 appears not to be gas bearing: 1) Open the 8 1/2" hole to 17 1/2" from near 2,150' to 2,400' and drill ahead in 17 1/2" hole to 2,600'. 2) Cement 13 3/8" casing on bottom with sufficient Class "G" cement to reach the surface. 3) Install Class III BOPE and Shaffer Rotating Blowout Preventer on the 13 3/8" casing. Test the BOPE and ~casing as directed. A/ T~r'~ll ~h~=a -;n 12 !//''' ~O1= tO ~- O ~/,5' - ~-*x ..... ~---~ to 3,045' in BRU 212-35. 5) ~ke a drill stem test of the open hole interval from the shoe of the 13 3/8" casing. Drill ahead in 12 1/4" hole to dull bit near 6,000'. 8. Run and tape the following logs using Schlumberger equipment. Ail logs to be run from T.D. tO the shoe of the 13 3/8" casing. a. Dual-Induction-Laterolog b. SP-BHC Sonic log c. FDC-Compensated Neutron log wit~ Gamma Ray 9. Cement 9 5/8" casing at effective depth in two stages using Class "G" cement. Cement through shoe with sufficient cement to reach the stage collar. Place the stage collar at the base of the lowermost productive Sterling sands. Cement from the stage collar into the lap of the 13 3/8" x 9 5/8" annulus. 10. Install Class III BOPE and Shaffer Rotating Blowout Preventer on the 9 5/8" casing. Test BOPE and casing as directed. Drill out stage collar. 11. Run CBL and test for WSO as directed. 12. Drill out casing shoe. Drill ahead in 8 1/2" hole to dull bit near 10,800', a depth equivalent to 11,125' in. BRU 212-35. Proposal For Well Operations PRO 316-1 Drilling Program -4- March 17, 1972 13. Run and tape the following logs using Schlumberger equipment. Ail logs to be run from T.D. to the shoe of the 9 5/8" casing. a. Dual-Indu ct ion-Lat erolog b. FDC-Compensated Neutron with Gamma Ray c. Four Arm High Resolution Dipmeter. d. SP-BHC Sonic Log 14. Based on the formation evaluation analysis, consideration will be given to cementing a 6 5/8" or 7" liner in place or abandoning the lower portion of the hole. 15. A detailed completion program will be provided after the final log run. The proposed salvage completion for this well will be a triple string with the long string to produce the Beluga River formation and the two remaining strings to produce the Sterling sands. Should the "D" sands be productive, they will be produced from a single or dual~ tubing string(s) . zz 'W. R. TINKER/W..D~ SAUER 1. Is well to be located in a defin~.J pool .... . ......... · 2. OD statewide rules apply ..... . .................. ~J~q 3, Is a registered survey plat attached .................. 4. Is well located proper distance from property line ........... ~,~, Is well located proper distance from other wells ............. 6. Is sufficient undedicated acreage available in this pool ...... 7. Is well to be deviated ......................... ® Is operator the only affected party .................... g. Can pemtt be approved before ten-day wait ........ ...' ..... lO~ Does operator have a bond in force ............ , ...... ,~11. Is conductor string provided ...................... 12. XS enough cement used to circulate on condUctor and surface ....... ~i~~; Will cement tie in surface and intermediate or production strings Will cement cover all possible produc'~f~e~horizons ........ 15. Will surface casing cover all fresh wa'~er zones ......... ....16. Will surface csg. internal burst equal ~,, p~i/ft~ to next string 17. Will all casing give adequate safety in collapse and tension ...... 18,~ Does BOPE have sufficient pressure rating ., ............. Addit$0nal Requirements: ~o/~ ~.~ .o/'m~.~>z.mo/- ~o~.~..~ ~ ~ Approval /~ HWK LCS 1 I0.0 8 2 3 4 5 6 7 8 91 2 3 4 5 6 7 8 91 2 3 4 5 6 7 8 91 2 3 4 5 6 7 8 91 2 3 4 5 6 7 8 9 · :''; *;; t;' X ..... +: .:.; _ ~ .... : .... !_ -4- ..~.x ; .;. ~ ~X- ; ~= - ~= ~+4--t-++ ~4;-i ..... i - $-~ -; -: : : ....... :~-' ~'i .... ~ ..... ;-::- ;4+-4:; a:-~ ;; H ~ ..... f-~ ..... ~*- h~q-~¢~'~ 4*~[HH ~ ~! -~-* *.+4 '4i .... : ; , , i-.~ '; : · ': ~ ;J ~ ' ' / ..... ' ..... t ..... '::-: .4-.'.--: ..... ':-~ ........ :: :--~ ..... % ~ :-:-..-J :-: ~-H-~ ,,,~ :t: ::':~ T'-t:~-:: f ?:i , : : .......... -, :: :* : ' ' ::i;t:::: i?T"~:': ¢: : :?::[?T:? :*?:Th:F I : t : ~ :: : 't-T?:'~r ~ ' ~'I='If ,: :t-i :T~.:'t1' t : i'~ : ' : i :[ : : · : '.:~.::: :{:::?: ::Ii: ::S[,i:'~ '.~: :~:: : i .J .: : t: ; : : , ',', ::it+::!:!': t!::[~:M ~HI L::: ',.',::~',?:; :::;:M:h .' : i : J: ' ::: l: t-:I:., 't::,'l' ;: ::: :;.:- :;;:::::::~' ::::L~: ~::~:U:! L:~t]::: : ; ;:l ~.:.:;.~;;::;:::::;',:;:::'.:;:~:'::::,!:;y;.;, :;~.?,~ : : :: ~ ::, ';:: :',::::;:: :,j:;: ;~; ....l ; : ~:: : ......]~ : ~. : . ; ~.,.; :, .:, ;:,;:; ~; .: ::!;..~,; ;:~ , ; ;. :.. , . !. : ;; .- :.:; ;..::,;: : ;. . ::~:j::::~:::: x. :::::::::x.:::: ::4:~::: : ::::J : : : :- : ::~:::~ :: : ::::::::::::::::::::::::: :::: ::::F: : -: : : :-: : : -~:-::::: -: ~:~: ~ :::: .... ::~: :.::: : .:::::: :.::::: : : j : .... ~: ......... J..::,;.J ......... : .................................................... :. :::::::::::::::::::::::::::::::::::::::: ===================== :,;=: ::::-:::: :::.::.---:-:-.:--: :-:-:-:: . ~'-- : ....... j .......................... ~ .... ~ - * ; ' ': -J ~"','~ ..... :'-,h ........ ~ .............. : .......................... {:;: ::::: ::::,~::::: :: :~:: :::' :::: :':::. : : : : J : : ; : :: :::: ========================== ':: :::::~::::g::: :'::, · . . . ~ : ~ .... ....... ~.:.. ,~ ,i ' ' ' ~ ~ / ' ~ : ~ ', , , ~ , j., ;~ i , ~ , . , ...... - . - :;:::::: :::;:::,: :: : :: ::::J:::: ::::: : : : : :: : :::::;: : ::: '::::::'::: : -- ::::;: ' :J::::::.:: ::':~::::~::::::: ::::J::: ::::':: ~-::: ::: ::::!:::: ::::::::: ::F:: ::::'~::m :::::::::::::::::::::::::: ::.::.:::::::,:::: :. ::: 5:-:::::, - . BELUGA' -~ ~ .... ~-.~ .................. ~ ............... ~.: ...... ~ .... :.~ .... ~ ....... ~:~, RIVER UNIT · ~ .... ~ .... ,~.I ...... ~.-~ ....... ~..~ .... ~ .... ~:-~.~ .... ~:~-.~ .... ~-..:~--.~-.-~ ..... :,.~--- STRING ~ ; ~ i I I i" ~ : ~/ : j'; : .:', ' ENGR. T.B. D~fE 4 3 2 1.0 8 7 .I 2 3 4 5 6 789 2 3 <- 5 6 789 2 I0,000 I00,000 Q .01 I000 3 4 5 6 7 8 9 2 3 4 5 6 7 8 9 2 3 4 ~ 6 7 89 1,00 0,000 I0,000,000 ,