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Home My WebLink About184-135 Image Project Well History File Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA [] Color items: [] Diskettes, No, [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) :'~ .,,,.~.~'f various kinds . ~ Other ' I$! Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: Isl Scanning Preparation x 30 = BY: BEVERLY BREN VINCENT SHERYLJrV]ARIA)LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ ~L PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~.YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO + -- TOTAL PAGES RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScan ne(].wpd Memorandum To: State of Alaska Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 Oil and Gas Conservation Commission This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to ddil. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddils and or multilaterais in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The AP! number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl numbering methods described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. Statistical Technician ARCO ALASKA, INC. Cook Inlet/New Ventures Engineering TRANSMITTAL TO: ~ FROM: COMPANY' IZ~ ~9 ~ d_~ d~ COMPANY' DATE' / -/~ --~ ~ WELL NAME' Transmitted herewith are the following' PLEASE NOTE' BL = Blueline, S = Sepia, F = Film, T = Tape, PC = Photocopy Receipt Acknowledgment' Date' Return Receipt to' ARCO Alaska, Inc. ATTN- Judy Boegler AT0-579 Po~t Office Box 100360 Anchorage, AK 99510 ' November 30, 1984 Mr. J. L. Weaver Area Operations Superintendent Chevron U.S.A. Inc. P. O. Box 107839 Anchorage, Alaska 995.10-7065 Re: Program Discrepancies Beluga River Unit Wells'No. 224-23, 232-9, 223-26, and 232-26. Dear Mr. Weaver: On November 28, 1984 our Petroleum Inspector, Ed Sipple, went to, your BRU 224-23 location to witness pressure testing of your 20 inch blowout preventer equipment (BOPE). As a result of this visit, we found that the installed BOPE consisted of an annular preventer and a single gate (blind ram). This did not conform to state regulations and appears to be significantly different than the approved drilling program submitted with your application for a Permit to Drill or Deepen. The applicable state regulation is 20 AAC 25.035(c)(1)(A). API 2M, 3M, and 5M stacks must have at least three preventers, including one equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, one with blind rams, and one annular type. Since the BOPE drawing you furnished with your application for a Permit to Drill or Deepen showed one annular preventer and a double gate with blind rams and pipe rams, we assumed you planned to comply with state regulations and we therefore approved your application for a permit to drill, Our on-site inspector did approve drilling below the cemented 20 inch casing in violation of regulation after first consulting with a member of the Commission. Considering all facets of the situation the consensus was that drilling ahead to the the next programmed casing point with the BOPE already installed did not constitute an undue risk and therefore the extended delay in operations required to change out the BOPE was not warrented. Please be aware that our action in this matter constitutes a one time exception only. .We have no intentio, n o.f letting the excep- tion establish a precedent for future drlllmng operations in the Beluga River area. Accordingly, you may wish to encourage your Mr. $. L. Weaver Page 2 November 30, 1984 drilling repres~.ntative and Contractor to become kn0wledgable of Alaska-law so these types of situations will not again be encoun- tered. It is our practice to administer violations of our regulations in accord with AS 31.05. 150. Should you have questions regarding the foregoing, please do not hesitate to let us know. Sincerely, C. V. Ch-~tt~er~o~ Chaiman be: 1. K. CH Attachment August 31, 1984 Mr. J. L. Weaver Area Operations Superintendent Chevron U.S.A. Inc. P. O. Box 107839 Anchorage, Alaska 99510-7065 Re: Beluga River Unit BRU 223-26 Chevron U.S.A. Inc. Permit No.~84-!35 Sur. Loc. 227!'E, 14!8'N of SW cr Sec. 26, T]3N, R10M, SM. Btmhoie Loc. S A M E. Dear Mr. Weaver: Enclosed is the approved application for permit to drill the above referenced well. If coring is Conducted, a~ one cubic inch chip from each foot of recovered core is required. Samples of well cuttings, a minimum of four tablespoons, and a mud log are required. An ~nclJnation survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all ]_ogs for copying except experimental logs, ve!ocit¥ surveys and ?ipm~ter ~rveys. ~_~n~ _~vers in A_a~ka ~J~d the,r drainage systems have been classified as important for the spa~ing or migration of · anadromous fish. ~erati~ns in these areas are subject to AS 16.05.870 and the ~e~lations promulKated thereunder (Title 5, Alaska A~inistrative C~-~), Prior to ~o~encing operations you may be contacted by the Habitat Coordinator' s Office, Department of Fish and Game. ' Pollution of any waters of the State is prohibited by AS 46, ~apter 3, Article 7 and t~ regu!~ions oro~lgated~ thereunder (Title 18, Alaska Administrj~i~e Cod~, Chapter 70) and by the. Federal %Tater Pollution Control Act, as amended~ Prior to co~encing operations vou~mav be contacted by a representative of the Department of EnvirOnmental Conse~atiop. / ~-~.r.J.L. Weaver Beluga River Unit BRU 223-26 August 3.~., !984 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~here a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testipg before drilling below the shoe of the conductor pipe. In the event of su. penslon or abandop~ent, please give this office adequate advance notification so that we may have a witness present. __truly yo.~oars, C. V.' '- -~ttert°n' Chai~an of Alaska Oil and Gas Conse~ation Co~ission BY ORDER OF ~ CO~4ISS~.ON ~ be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Chevron Chevron U.SA. Inc. P.O. Box 107839, Anchorage, AK 99510 · Phone (907) 786-6600 J.L. Weaver Area Operations Superintendent Produclion Deparlment 3uly 27, 1984 State of Alaska Permit To Drill BRU 22~-23, BRU 232-26, BRU 232-9 & BRU 223=26 Beluga River Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 Gentlemen: Chevron U.S.A. Inc., on behalf of itself, ARCO Alaska, Inc., and Shell Western E&P, Inc., proposes to drill BRU 224-.23, BRU 232-26, BRU 232-9, and BRU 223-26. BRU 232-26 is being permitted as a contigent well depending on the results of the first three wells. The subject wells are shown on the attached plats Nos. AB-139, AP-D~643, and AP-D-644. For your consideration and approval we submit, in triplicate, the State of Alaska Oil and Gas Conservation Commission Permit To Drill, Form 10-401 for each of the four subject wells. Also enclosed is our check in the amount of $400.00 for the four applications. As shown on the attached plats, the proposed wells lie within the following leases: Well BRU 224-23: Surface Location= + 2459 ' E. 667' N from the SW corner of Section 23, TI3N, RI0W. SM. Lease: ADL 21127. Bottom Hole Location: + 2350' E, 150' N from the SW corner of Section 23, TI3N, R10W. SM. Lease: ADL 21127. Well: BRU 232-26 Surface Location: + 2535' E, 580' N from the SW corner of Section 23, TI3N, RI0W, S.M. Lease: ADL 17658. Bottom Hole Location: + 3098' E, 1618' S of the NW corner of Section 26, T13N, RI0W~-SM, Lease: AOL 17658. R E C ElM E D Well: BRU 232-9 J U L 3 o 1984 Surface Location:_+ 2038' E, 296' S from the NW corner O~Alaska 0il & Gas Cons. Commission Section 9, TI2N, RIOW, SM. Lease: A-029656. Anch0rag0 Bottom Hole Location: + 3130' E, 2380' S from the NW corner of Section 9, TI2N, RIOW SM. Lease: ADL 17592. Alaska Oil & Gas Conservation Commission July 27, 198# Page Two Well: BRU 223-26 Surface Location: + 2271' E, 1#18' N from the SW corner of Section 26, TI3N, RIOW, SM. Lease: A-029657. Bottom Hole Location:+ 2271' E, 1#18' N from the SW corner of Section 26, TI3N, RIOW, SM Lease: A-029657. All the surface locations and bottom hole locations fall within the boundaries of the Beluga River Unit. Pursuant to the Alaska Oil and Gas Conservation Regulations and the applicable statutes of the State of Alaska, Chevron U.S.A. Inc., as Unit Operator, hereby requests the Alaska Oil and Gas Conservation Commission to issue an order allowing exception to Title 20, Alaska Administrative Code, Section 25.055 to permit the drilling of BRU 22#-23, BRU 232-26, and BRU 223-26. BRU 232-9 does not require a spacing exception as it is the first well on Section 9 and is more than 3000' from the nearest well. The spacing exception is needed to efficiently drain the Beluga Pool and to develop sufficient deliverability to meet the new Shell Western E&P, Inc./Alaska Pipeline Company gas contract. BRU 224-23 will be the second well on Section 23 but will be + #900' from the other well, BRU 221-23. BRU 232-26 will be the first well on Section 26. It will be + 1700' from BRU 224-23 but will be completed in different intevrals than BRU 224-23. BRU 224-23 will be completed in the upper three zones of the Beluga gas accumulation while BRU 232-26 will be completed in the lower six zones. Contingent well BRU 223-26 would be the second well on Section 26 and would be + 2550' from the other well, BRU 232-26. Again, however, these two wells would be c~mpleted in different intervals. BRU 223-26 will be completed in the upper three zones while BRU 232-26, as already noted, will. be completed in the lower six zones. Chevron U.S.A. Inc., ARCO Alaska, Inc., and Shell Western E&P, Inc., each owns an undivided one-third (1/3) interest of the subject leases and are the sole owners of all leases on the sections directly and diagonally offsetting the sections to where the wells BRU 224-23, BRU 232-26, and BRU 223-26, are to be drilled. ARCO Alaska, Inc., and Shell Western E&P, Inc. were notified of this application with a certified copy of this letter. There are no other working interest owners or operators which would be affected by granting the spacing exception on the subject wells: BRU 224-23, BRU 232-26 and BRU 223-26. Pursuant to the Oil ang Gas Conservation Regulation Title 20, Section 25.035, Chevron U.S.A. Inc., hereby requests the Alaska Oil and Gas Conservation Commission to issue an order allowing a waiver of the surface hole diverter system based on Chevron's experience in drilling at Beluga River. JUL 3 Alaska Oi~ & Gas Cons. commission Anch0rag~ Alaska Oil & Gas Conservation Commission 3uly 27, 19814 Page Three Below is list of the wells drilled at Beluga River and the conditions found while drilling the surface hole. .. Well Depth of Surface Hole Mud Weight Oil & Gas Shows BRU 232-14 302' 9.9 ppg None BRU 21414-14 310' 9.1 ppg None BRU 2214-13 1423' 9.5 ppg None BRU 212-18 1411' 9.7 ppg None BRU 221-23 # 114' 9.7 ppg None BRU 212-2# 365' 9.9 ppg None BRU 212-25 288' 9.9 ppg None BRU 233-27 303' 9.3 ppg None BRU 2141-3/4 1405' 10.0 ppg None BRU 212-35 129' 9.5 ppg None BRU 2114-35 1410' 10.14 ppg None Chevron U.S.A. Inc, as the Unit Operator, believes that the Permit To--.Drill Applications and the two exceptions that have been requested are necessary and desirable in order to efficiently drain the reservoir. The gas that the new wells will produce is needed to continue to meet our obligation to Chugach Electric Association, Inc., and to meet Shell's new commitment to Alaska Pipeline Company, a subsidiary of Enstar Natural Gas Company, which is building a 20" gas transmission line from Beluga River to Anchorage. The line should be completed this fall. :3AC:sj Very truly yours, ~.L. Weaver Attachments: (1) Four (14) AOGCC Permit To Drill Applications (2) One (1) BLM Permit To Drill Application (3) Drawings: AB-139, AP-D-6143, AP-D-6#14 CC: ARCO Alaska, Inc. (Certified Mail No. P 200 285 876) Attention: Mr. John C. Havard P.O. Box 100360 Anchorage, Alaska 99510 Shell Western E&P, Inc. (Certified Mail No. P 200 285 877) Attention: Mr. B. E. Barnard P.O. Box 527 Houston, Texas 77001 RECEIVED J LI L 3 o 1 184 Alaska Oil & Gas Cons. Gommissior~ Anchora§o STATE OF ALASKA THIRD 3UDICIAL DISTRICT ) )ss ) 3. L, Weaver, being first duly sworn, upon oath deposes and says that he is the Area Operations Superintendent, Production Department, employed by Chevron U.S.A. Inc., and to the best of his knowledge and belief that the facts stated herein and shown on the accompanying plans are true, and that the accompany!ng plats are drawn to scale and correctly reflect pertinent and required data. Subscribed and sworn to before me this · L. Wea[ver dayof ~] c.{.~ ,19g#. Notary Public in and..~or 'the State of Alaska RECEIVED J U L ~ o t91~4 Alaska Oil & Gas Cons. Commissiorl Anchorage STATE OF ALASKA ~- ALASKA C,_ AND GAS CONSERVATION CO~...~IlSSION PERMIT TO DRILL 20 AAC 25~005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [~ SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~ MULTIPLE ZONE [] 2. Name of operator Chevron U.S.A. Inc. 3. Address P.O. Box 107839, Anchorage, Alaska 99510 4, Location of well at surface ~ 2271'E, 1418'N from the SW CORNER OF Sec.26, T13N, R10W, SM At top of proposed producing interval Same as surface At total depth Same as surface 5. Elevation in feet (indicate KB, DF etc.) 75" G.L. 6. Lease designation and serial no. A-029657 9. Unit or lease name Beluga River Unit 10. Well number BRU 223-26 11. Field and pool Beluga River, Beluga 12. Bond information (see 20 AAC 25.025) Type AOGCC Blanket Bond Suretyand/ornumber U80-61-55-22 Amount $200,000 13. Distance and direction from nearest town Northeast 10 miles 16. Proposed depth (MD & TVD) 6600' and 6600' feet 14. Distance to nearest property or lease line 400 feet 17. Number of acres in lease 1274.00 19. If deviated (see 20 AAC 25.050) KICK OFF POINT feet. MAXIMUM HOLE ANGLE 20. Anticipated pressures (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed we~l BRU 212-35 3400 feet 18. Approximate spud date March 1. 1985 2500 psig@~ Surface 2800 . psig@ 6600 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole 30" 26" 17½" 12¼" 12¼" Casing Weight 30" 20"~, 94 13-3/8' 68 9-5/8" 40 9-5/8" 43.5 1 , wa 22. Describe proposed program: Grade 1 wel H40 K55 N80 N80 Coupling led Butt' Butt Butt Butt Length MD TOP TVD 80 0I 0 400 0I 0 3050 5OOO 1600 0 0 ~ ~ 0 5000 ~ 5000 I MD BOTTOM TVD 801 80 4001 400 30501 3050 50001 50O0 66001 6600 (include stage data) Driven 500 sx 2000 SX 800 SS 1st stage 400 SX 2nd stage See the attached drilling program., J u L 3 o 19Bt A~aska ui~ c, bas Cons. C0m~Ss Anchorage 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~~~/~.v~.kz~--~--~ TITLE Area Operations The space b(~4~/,~/~ '-' ~'or-C(~mmisSion use Superintendent CONDITIONS OF APPROVAL Samples required [~YES ~NO Mud log required I I-~YES ~i~NO Directional Survey required []YES ~'NQ APl number 50- '~8~ Permit number APPROVEDBY Form 10-401 ~ow 7-1 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE August 31, 1984 by order of the Commission Submit in triplicate PROPOSAL FOR WELL OPERATIONS PRO 316-1 PROPERTY AND WEIJ~ Beluga River Beluga River Well No. 223-26 SURFACE LOCATION: (Proposed) + 2271 feet east and 1418 feet north from the s-~uthwest corner of Sec. 26, T13N, R10W, S.B.&M. BOTTOM HOLE LOCATION: Same as Surface Location. ELEYATION: Estimated K.B. elevation of Brinkerhoff 58 is 93 feet. Ground level to K.B. is 18 feet. BLOWOUT PREVENTION CONSIDERATIONS: 1. Potential Problems i. Gas and water entries; No high volume gas flows are expected above 3000'. Coal seams can be encountered'anywhere from the surface to T.D. A controlled penetration rate and degasser should eliminate any gas encountered while drilling coal seams or through the productive interval. No water flows are expected. Be Lost Cireulation: Lost circulation is not expected with the programmed mud weights. C. Stuck Pipe: Coal seams should be drilled and reamed with care. D. Precautions: All kicks should be handled by normal procedures. Drilling crews should be made aware of these methods prior to spudding. Kick and BOP drills should be practiced at regular intervals and noted on the tour sheets. An adequate supply of weight materials should be at the well at all times. . . . Maximum Anticipated Formation Pressure: 1521 psi 9.2 ppg 0.48 psi/ft. 2789 psi 9.2 ppg 0.48 psi/ft. Maximum Anticipated Surface Pressure: 2500 psi. Blowout Prevention Equipment~' +3093'+ 5740' RECEIVED J u L 3 o ]984 Alaska 0il & Gas Cons. Commission Anchorage 20" casing - Class']] B 2000 psi BOPE with 3000 psi choke and kill llne. 13 3/8" and 9 5/8" easing - Class KI 3000 psi or higher rated BOPE (BSI Rig 58 has 13 5/8" 5000 psi BOPE as standard equipment). Nipple up and test as per AOGCC Regulations and API RP 53. BRU223-26 Section 26 T13N r--~W S.B.M. Beluga River, Ala~ ~ DIRECTIONAL CONb-'IDERATIOlqS: Single shot directional surveys are to be taken at 500 ft. and no more than 50(} ft. apart to the total depth. RECEIVED J U L ~ 0 ].984 Alaska Oil & Gas Cons. Commission Anchorage BRU223-26 Sect.26 TI~. R10W S.B.&M. Beluga Ri~ , Alaska PROGRAM . . . . Drive 30" conductor pipe as deep as possible (+ 80') Drill for 20" easing to + 400 feet. /{J'~/-~ A~. ~'/~s - Run and cement 20", 94#/ft., H-40,~easing as follows: A. Use a guide shoe with a stab-in duplex float collar one joint up. Be Co Thread lock the bottom two joints. Use three centralizers on bottom two joints and one every other joint to surface. De Circulate two hole volumes. Precede cement with 20 bbls. of fresh water. Mix and pump Class "G' cement with 2% pr,hydrated gel by weight of water (or 6% dry gel by weight of cement). a. Slurry weight - b. Mixing Water - c. Yield - d. Compressive strength - 13.9 ppg. 8.56 gal. water/SX cmt. 1.655 CF/SX cmt. 600 psi after 24 hours. F. Use 30% ex,ess cement. Perform a "top job" if cement returns are not obtained. Install a 20" - 2000 psi Class II B BOPE with a 3000 psi or greater kill line and choke manifold. Install and test per AOGCC Regulations and API RP 53. Give BLM and AOGCC 24 hour notice to witness BOPE test. Note: Burst pressure of 20", 94#/ft., H-40 casing is 1530. Test to-~6~ psi. Drill a 17~" hole to 3050' MD (-2957' VSS). Obtain a i gallon mud sample just prior to POOH for logs. Log and take SWS as per Formation Evaluation Program. This program to be provided. Wel]site geologist to witness logs and specify SWS depths. Run and cement~'13 5/8'i. 68#/ft., K-55 buttress casing on bottom as follows: A. Use a float shoe with a stab-in duplex float collar one joint up. B. Centralize the bottom 4 joints and at the 20" easing shoe. C. Circulate two complete hole volumes. Dm Mix and pump a pr,flush of 10 bb]s. fresh water, 20 bbls. of 2% caustic water (by weight of water), 5 bbls. of fresh water. RECEIVED JUL o .,~.~ r~il & Gas Co~s, Ee BRU223-26 Sect.26 T13~N~R10W S.B.&M. Beluga Riv( klaska Mix and pump Class G cement with 2% prehydrated gel by weight of water (or 6% dry gel by weight of cement). a. Slurry weight - b. Mixing Water - c. Yield - d. Compressive strength - 13.9 ppg. 8.56 gal. water/SX cmt. 1.655 CF/SX cmt. 900 psi after 24 hours. F. Use 50% excess in open hole section. . Cut the 13 3/8" casing and weld on a 13 5/8", 3000 psi X 13 3/8" SOW casing head such that the top flange of the tubing spool is 1" to 2" above G.L. . Install a Class l/I, 5000 psi, BOPE as per AOGCC Regulations and API RP 53. Give BLM and AOGCC 24 hour notice to witness test. Test to 3000 psi. 10. Install mUd loggers. 11. Drill to within 10' of the shoe. Test easing to 1500 psi. 12. Drill out the shoe plus 30'. Perform a leak-off test. 13. Drill a 12¼" vertical hole to 6600' + 40' MD (-6507' VSS). Obtain a ~ gallon mud sample just prior to POOH for logs. 14. Log and take SWS as per Formation Evaluation Program. This program to be provided. Wellsite geologist to witness logging and specify SWS depths. 15. Run and cement 9 5/8" casing on bottom as follows: i. Use 43.5#/ft., N-80, Buttress casing from 6600' to 5000', and 40.0#/ft., N-80, Buttress easing from 5000' to surface. B. Run a float shoe and float collar two joints apart and thread lock. Ce Run a cement stage collar in the 40#/ft. easing at + 3700' M.D. De Centralize the shoe, through the productive interval, and above and below the 13 3/8" casing shoe. Use one centralizer every one or two joints through these intervals. E® Circulate two complete hole volumes. Keep the mud plastic viscosity and yield point as low as possible. F. Cement 9 5/8" casing in two stages as follows: 1st stage: 1. Mix and pump a preflush of 20 bbls. of fresh water, 20 bbls of 2% caustic water (by weight of water), and 5 bbls. of fresh water. 2. Mix and pump class G neat cement with friction reducers, fluid loss additives, and retarders as needed. Volume to be calculated from caliper log to bring cement top to the stage collar (no excess). a. Slurry weight - b. Mixing water - e. Yield - 15.6 ppg 5.2 gal. water/SX cmt. 1.18 CF/SX cmt. RECEIVED J U L 3 01984 '~ska 0~ & Gas Cons. Commission ,~nchorage BRU223-26 Sect.26 TI.~-R10W S.B.&M. Beluga Riw Alaska 16. 17. 18. 19. 20. 21. 22. 23. 2nd stage: ® Drop bomb, open stage collar, and circulate a minimum of two hole volumes. Mix and pump pre flush as in 1st stage. Mix and pump class G neat cement as per 1st stage. Volume to be calculated from the caliper log plus 30% excess to bring cement top + 500' up in the 13 3/8" casing. Ge Work the easing throughout circulation and 1st stage cementing if possible. H. Keep the cement in turbulent flow, if possible, while pumping. Land 9 5/8" easing in the 13 3/8" SOW easing head. Install a 13 5/8", 3000 psi x 11", 3000 psi tubing head. Test secondary packoff to 3000 psi. Nipple up a Class III, 5000 psi BOP. Test to 3000 psi as per AOGCC Regulations and API RP 53. Clean out cement to the float collar using a bit and tandem scrapers. Test casing to 1500 psi. Run a gyroscopic survey from T.D. to surface. Run a cement bond, GR-neutron log from PBTD to the 13 3/8" easing shoe. .. Testing and/or completion program will be provided. JBL:mw M.K. Rieken ECEIVE JUL 0 i984 A~aska OiJ & Gas Cons. Commission Anchorage BRU223-26 Section 26 T13~_~ R10W S.B.&M. Beluga River, ~ska DRILIflNG MUD DET,~,HJ SHEET Lightly Treated Chrome-Free Lignesulfonate With K CL for Clay Inhibition Optimum Mud Properties Spud 17 ~" Hole 12 ¼" Hole Mud Type Gel- Water Density 8.6 - 9.2 9.2 - 10.2 9.2 - 10.5 Funnel Viscosity (Sec) + 35 + 35 Plastic Vis. (CPS) 6 - 12 6 - 13 Yield Point (#/100 ft.2) 21 - 8 2l - 7 Initial Gel (#/100 ft.2) 1 - 5 1 - 5 10 min. Gel (#/100 ft.2) 4- 10 4- 10 Ph - 9- 11.5 9.5 Ca. (mg/1) - 40 - 200 40 - 200 Cl. (rog/l) - 5000 + 30000 Fluid Loss (cc. API) - - 5-7 Optimum mud properties are not required until the cement in the 13 3/8" casing string is drilled and treated out. RECEIVED J U L 0 19 4 Alaska Oil & Gas Cons. Commission Anchorage 20" - 2000 pa i ANNULAR PREVENTER 20"' 2000 psi WP PIPE RAMS BLIND RAMS DOUBLE GATE KILL LINE 5000 psis, 20"-2000 W.P. 3"-5OOO psi 3"- 5000 psi TO MANIFOLD ~hevmn 20" 0 D CASING --.',ga '- ~"~ - --., ' ~ Il I . I' 36" CULVERT CEMENT ,.e, ~ '~, ;.,_,, o...,:,,. ! CLASS Tlr BOP (A) CHEVRON U.S.A. RECEIVED J U L ~ o 1984 Alaska Oil & Gas Cons, Commission Anchorage BRU 223 -26 NPB ANNULAR PREVENTER 13 '5/8"- 5000 psi ~."- 5OOO psi KILL LINE 2"-5000 psi 5/8"-5000 psi DOUBLE GATE i$ 5/8"-5COO psi PIPE RAMS BLIND RAMS MU'D CROSS SPOOL · --I~ 5/8"'5000 psi 3"- 5000 psi ~/,$"- 5000 psi TO M A NIFOLD BULL PLUG 5/8 "' 3000 psi ~,2 "-:5000 psi BLIND FLANGE SOW OteVmn CHEVRON . .' o. U.$.A. CEMENT e · I I e · o .'. o _...&.___J. __ · · I ~o,, ~ I I ~o" CLASS ]:[[ BOP BRU 22;5-;)6 RECEIVED JUL ~ 0 Anchorage NPB I · ANNULAR PREVENTER 13 5/8"- 5000 psi c 13 5/8"-5000 psi 13 5/8"- 5000 psi DOU8LE GATE 2"- 5000 psi KILL LINE 2"- 5000 psi BULL PLUG PIPE RAMS BLIND RAMS TUBING HEAD · -'"13 5/8"-5000 psi ~ 11"-5000 psi I I I I I 135/8%3000 psi psi BLIND FLANGE SOW $%5000 psi / TO MANIFOLD CEMENT '~-~=.-~--~: .- .~ ~ . :.-...-. ~; !, I ,:'" "' "' '' ~! ii ,.~o ~o" CLASS TTr BOP (C) RECEIVED JUL 3 0 19B4 Chevron CHEVRON U.S.A. BRU 223 -26 Anchorage WELL SURVEY Pro-312 !=3 · ~ .. I~ M.D.B. iN. 1 ~- ' ' A L'"~' E Ill A-T E O ff 8 U II ~' E Y E 0 L 0 ¢ A T I 0 II -- LOP. AT I 011 ..... OE81GIIATtOII ~ LOCATIOII- CO0110 111ATE8 NOV[ ............... Y'-' :~,.(~,.~-_,=7. ~/ X = ~O,z~3'.~/ . " .. . .... .. ~i , ,,' ~ ..... , , ~ ,! ~, ..-, . '~.~ , . ., ·.. , · . _ , . .,. . , . ,. · . I ,,.... ..- .: ,,.~.. r.. ... , ,, . . ,,, . , , ,. , · - i:..: :' .- _ . -. .~- .... :%-.- . · ITAT 01~ IIJ~.'~--. rz. j; ~ · ~OUTll E~aT W,,JT ~": ' . ~ '" -~' '~ ': %5' : . _ i _~, , . , p~, - . ' ~... .. ,.-. , - ~:..~..%~.- , ;~i. .............. ;- '7 -: 7' . . T. ?~ ' ~ 7.~=~-'~:. ': . _ _ . h_ . , , , ~t':" ~7.-1: ':" -' . ;" ':'- · ~ - ";- ~ ' , - _ , .. _ : . , . ~nchorage r ~':' .-.:.;: ..... ~':-? :.:.._ -.. . ~.. ::; ~. ..:{- ':'- ... ., - Form 3160--3 -. SUBMIT rlq TlR CATE, (November 1983) (Other Instruct,,..~ on (r .... l~, 9-331c) UN,, ED STATES re,erse si~e) DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL [] 2. NAME OF OPERATOR Chevron U.S.A. Inc. 3. ADDRESS OF OPERATOR P. 0. Box 107839, Anchorage, Alaska 99510 DEEPEN I-] PLUG BACK [] MULTIPLE [~ ZONE 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.*) At sur£ace + 2271'E, 1418'N from the SW corner of Sec. 26 At proposed prod. zone Same as surface 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 10 miles NE of Tyonek Form npproved. Budget Bureau No. 1004-0136 Expires August 31, 1985 5. LEASE D£/qlGNATION AND /~EHIAL NO, A-029657 6. IF INDIAN, AI,LOTTEI~ (lit TRIBE NAME 7. UNIT AGREEMENT NAM~ Beluga River Unit $. FARM OR LEASE NAME 9. WELL NO. BRU 223-26 I0. FIELD AND POOL, OR WILDCAT 11. sec., T., R., M., OR RLK. AND SURVEY OR AREA Sec. 26, T13N, R10W, SM 12. COUNTY OR PARISHI 13. ~TATE [Alaska DISTANCE ]'ROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drlg. unit line, if any) DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL, DRILLING, CO?,IPLETED, 0!~ APPLIED FOR, Obi THIS L~ASE, F~, 400' 3900' ]6. NO. OF ACRES IN LEASE 1274.00 I9. P,~OPOSED DEPTH --+' 6600' 17. NO. OF ACRES ASSIGNED TO THIS WELL 640 20. ROTARY OR CABLE TOOL8 Rotary 21. E~VATIO~S (Show whether DF, RT, GR, etc.) + 75' GR 22. APPROX. DATE WORK WILL STARTs March 1, 1985 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE 30t' SIZE OF CASING 30" 26" 20" SETTING DEPTH / V~'EIGHT PER FOOT [ 1".~T1--- ~-- ~-- 40 - 43.5~/ t 80 QUANTITY OF CEMENT Driven 400 500 SX 17½" i3-3/8" 3050 2000 SX 12¼" 9-5/8" 6600 800 SX 1st stage 400 SX 2nd stage See the attached drilling program. RECEIVED J U L 0 1984 Alaska Oil & Gas Cons. Commission Anchorage IX ABOVE SPACE DESCRIBE PROPOSED PROGRAM: I~ proposal ts to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen dlrectionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, if~any. 24. SIGNED TITLEArea Operations .qnparin~onden~TE ~/~/~Y · , ? ! (This spa ,~r Federal or State office use) PER.MIT NO. APPROVAL DATE APPROVED BY CONDITIONS OF APPRC;VAL, IF ANY : TITLE DAT~ *'See Instructions' On Reverse Side Title 18 U.S.C. Section 100l, makes it a crime for any person knowingly and willfully to make to any department or agency of the .......... CHECK LIST FOR NEW WELL PERMITS Company ..... ~--.,~.',.,,~,,'~'~-,.. Lease & Well No. : ~"~ ..... ', ITEM APPROVE DATE (1) Fee (2) Loc ,, >(/2 thru 8) (3) Admin ' l/~'/? ~9 thru TU (10 and lZl)/ ' ( 4 ) C a s ~ ,~ ~/afj~f (12 thru ~0)''~ ' (5) OPE '" (21 thrd 2'~) e 10. 11. YES NO REMARKS 1, Is the permit fee attached .......................................... 7~2 ..... ,, ,' 2, Is well to be.located in a defined pool ............................. .__ c,/~,~ ..... 3, Is well located proper distance from property line .................. 4 Is well located proper distance from other wells '"""~"~ · eeeeeeeeeeeeeeeeeeee 5, Is sufficient undedicated acreage available in this pool ............ 6, Is well to be deviated and is well bore plat included ............... - 7 Is operator the only affected party .................. · eeeeeeeeeeee~eee,~ 8. Can permit be approved before ten-day wait ........ ,, ,,, Does operator have a bond in force .................................. ~u-, Is a conservation order needed .......... Is administrative approval needed ........................................ .,, ....... 12. Is conduCtor string provided ........................................ 13. Is enough cement used to circulate on conductor and surface ......... 14. Will cement tie in surface and intermediate or production strings ... 15. Will cement cover all known productive horizons ..................... 16. Will surface casing protect fresh water zones .... ................... 17. Will all casing give adequate safety in collapse, tension and burst.. 18. Is this well to be kicked off from an existing wellbore ............. 19. Is old wellbore abandonment procedure included on 10-403 ............ 20. Is adequate well bore separation proposed ...~ ....................... 21. 22. 23. 24. 25. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... ~",~/ Does BOPE have sufficient pressure rating - Test Does the choke manifold comply w/API RP-53 (Feb.78)...~'. ............. Additional requirements ............................................. Additional Remarks: Geology: Engineering: HWK ,-- LCS ~ BEW WVA' J AL~ JKT~~JH rev: 12/08/83 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE .. ~ ~"~ ~ O.,~_,.~ I i ....~ ~ ,5-.~ ~--,.,,oo,,~ ,d