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Home My WebLink About197-238 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg S L A V E D AUG 0 7 2012 Alaska Oil and Gas Conservation Commission � 3 � 333 West 7 Avenue 1 1 q 1 " 1 Anchorage, Alaska 99501 1 — 0 Subject: Corrosion Inhibitor Treatments of GPB GNI Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB GNI that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) GNI Date: 03/06/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date --, GNI -01 1972380 50029228450000 0.7 NA 0.7 NA 5.1 3/6/2012 GNI -02A 2061190 50029228510100 5.0 NA 5.0 NA 30.6 3/6/2012 GNI -03 1971890 50029228200000 5.8 NA _ 5.8 NA 35.7 3/6/2012 GNI -04 2071170 50029233670000 2.3 NA 2.3 NA 13.6 3/6/2012 I Page 1 of 1 0 • Maunder, Thomas E (DOA) From: Bill, Michael L (Natchiq) [Michael. Bill @bp.com] Sent: Tuesday, November 16, 2010 4:48 PM To: Maunder, Thomas E (DOA) Cc: Engel, Harry R; AK, D &C Well Integrity Coordinator Subject RE: GNI -01 (197 -238) Tom, Thanks for the question about the condition of Class II disposal well GNI -01 and the plans to use it for injection. The last MIT -IA in well GNI -01 was performed on 7/04/08. We did not perform the 2010 MIT -IA. Wellbore conditions require setting a plug in the tubing and imposing tubing back pressure as the annulus, consequently we decided to defer the MIT until we actually had plans to use the well. The well is listed as "Not Operable" in our Well Integrity system due to the expired MIT -IA. We plan to keep the option of using the well if needed, subject to completing an AOGCC witnessed MIT -IA. Let me know if you have additional questions, Mike Bill Well Integrity Group Drilling & Completions 907 - 564 -4692 Office 907 - 564 -5510 Fax From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, November 16, 2010 2:35 PM To: Bill, Michael L (Natchiq) Subject: GNI -01 (197 -238) Mike, AOGCC has recently received the annual GNI report. In the course of reviewing the report, I have referenced the well files and in particular GNI -01 the remaining Class II disposal well. Based on the most recent information available in the well file (attached), it appears that BP did not perform the biennial MIT this past summer as described in the message trail between you and Jim. If an MIT was conducted, I have not been able to find a copy or transmittal. While there doesn't appear to be a violation here since the well has not been in operation since May 2007, it does appear that your intent to keep the well regulatorily qualified to be employed at short notice is no longer valid. Call or message with any questions. Tom Maunder, PE AOGCC 11/17/2010 by • "7(, sa v s 46 44.• R BP Exploration (Alaska) Inc. � ��>< fl 900 East Benson Boulevard � "'+' P.O. Box 196612 k. f' ' i' Anchorage, Alaska 99519 -6612 (907) 561 -5111 i 64113 CMS. CanllitiOn s November 15, 2011 Commissioner Dan Seamount, Chairman ''` � N \ Alaska Oil & Gas Conservation Commission �� Z —10 �G - 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Reference: Grind & Inject Project Annual Performance Report Dear Mr. Seamount: Enclosed is the Annual Performance Report for waste slurry injection for the Grind and Inject project located near Drill Site 4 in the Prudhoe Bay Unit. This report is submitted to satisfy the requirements of Area Injection Order #4E, Rule 10, as modified by Administrative Approval No. A1O 4C.001 and an Erratum Notice dated July 17, 2009. This requirement is very similar to an EPA report requirement regarding Prudhoe Bay Unit UIC Class I injection wells contained in EPA permit AK- 11008 -A. The report covers the period from October 1, 2010 through September 30, 2011 and was structured to satisfy both the AOGCC and the EPA requirements. Should you have questions concerning the contents of this report, contact me at 564 -4692. Sincerely, �/ - I Michael L. Bill Senior Staff Engineer • • Cc: A. Cooke MB 4 -3 C. Burgh MB 4 -3 R. Daniel MB 7 -1 K. Fontaine MB 11 Harrington /Cantrell PRB 42 Collver /Srock PRB 42 Winkel /Reyes PRB 42 M. McAnulty 223B, 3000 C Street Well Integrity Coordinator PRB 7 M. Nelson, ConocoPhillips P. Bennett, ExxonMobil • • Prudhoe Bay Unit, Grind & Inject Project, Surfcote Pad Injection EPA UIC Class 1 Permit AK- 11008 -A Area Injection Order #4E, Rule 10 Annual Performance Report October 1, 2010 through September 30, 2011 This Annual Performance Report documents waste slurry injection on the Surfcote Pad near Drill Site 4 in the Prudhoe Bay Unit for the period October 1, 2010 through September 30, 2011. This report is submitted to satisfy the requirements of both EPA UIC Class 1 permit AK- 11008 -A, Part 11 3 c 7 and AOGCC Area Injection Order (AIO) #4E, Rule 10, as modified by Administrative Approval AIO 4C.001 and Erratum Notice dated July 17, 2009. Additional information requested in a letter from the AOGCC (Regg to Bill 12/22/03) is also included. The report contains a brief description of the current project status, a summary of the disposal well performance data acquired during this period and operational plans for the next year. Project Status The Grind & Inject (G &I) Project at the Surfcote pad was undertaken in 1998 by the owners of the Prudhoe Bay Unit, Initial and Lisburne Participating Areas, and the Kuparuk River Unit to dispose of drilling muds and cuttings stored in reserve pits. Other non - hazardous wastes processed through the G &I Plant included those referenced in AIO #4E, Rule 2 as Class 11 wastes, consisting of RCRA- exempt drill cuttings and oily solids from pipeline pigging, vessel cleanouts and well workovers, and RCRA- exempt liquid wastes such as used drilling mud from on -going North Slope drilling operations. EPA issued Class 1 UIC permit AK- 11008 -A for the Grind & Inject Project effective • September 1, 2007. Authorizations to inject Class 1 substances were received on January 18, 2008 for wells GNI -02A and GNI -03 and on May 6, 2008 for GNI -04. Well GNI -01 remains a Class 11 only disposal well. All non - hazardous wastes injected for disposal in the GNI wells during the report period are within the description of wastes referenced in EPA UIC Class 1 Permit AK- 11008 -A, Part 11 C 3 7, the UIC Class 1 permit application, or in Area Injection Order 4B, Finding 7 as incorporated in AIO #4E. Several Tined pits comprising the "material transfer station" (MTS) at DS 4 were operated to temporarily hold ongoing drilling and oily solids when necessary. On an infrequent basis, flow back liquids from new wells drilled with oil -based mud (OBM) or other wastes were injected directly into G &I wells using temporary equipment staged on the Surfcote pad. As of September 30, 2011, project injection has included 46.1 MM barrels of water, 84.9 MM barrels of slurry containing 5.2 MM tons (5.8 MM cubic yards) of excavated reserve pit material and other waste solids, and 6.5 MM barrels of fluid from ongoing drilling operations. Exhibit 1 summarizes this data. 1 Operations Operations during the year were affected by seawater supply interruptions due to high winds, power outages and maintenance work at the Seawater Treatment Plant and the Seawater Injection plant. G &l maintenance activities included an extensive inspection program of the piping and processing equipment within the plant and the pipelines to the wells. Solids processing in the G &i plant was shut down during the 2010 summer until mid January 2011, and from early June through the present. Major repairs included replacement of process and valves and well piping, as well as repairs to the slurry tank, ball mill, conveyor belt, shakers (screens), metering and to electrical systems. Disposal of ongoing liquid drilling wastes and water from pit dewatering operations continued during much of the summer shut down period. Solid wastes accumulated during the summer were stored at the MTS and processed when the full plant was in operation. The pace of excavation from the production reserve pits was reduced in 2010 with the concurrence of the Alaska Department of Environmental Conservation and batch processing of solids rather than continuous processing was used again in 2011. Well Operations and Monitoring The four GNI disposal wells are located on the Surfcote pad and continue to be available for disposal. Well GNI -01 has been shut -in due to tubing damage since May 2007, but it could be available for Class 11 direct injection pending current mechanical integrity testing or for observation purposes if needed. #t was replaced for Class I waste and slurry injection by well GNI -04 which began in May 2008. Well GNI -02A was sidetracked to a new bottom hole location in November /December 2006 and is an active Class 1 waste and slurry injector. Existing Class I well GNI -03 is also active after a workover in December 2009 to replace damaged tubing. Each well is perforated in the Ugnu formation between 6400 and 6600 ft TVD. GNI plant discharge rate, temperature and slurry density, along with injection well pressure and temperature and annulus pressures are continuously monitored in the G &I Plant control room. Injection takes place into one well at a time on a rotating schedule. After each injection cycle, the newly shut in well is flushed with water and freeze protected with new product methanol mixed with water. Exhibit 4 lists the injection cycles and the well work and surveillance activities during the report period. The injection history and performance for each well is shown in Exhibits 1, 2, 3, 5, 6 and 10. Peak slurry injection rates are normally between 25,000 and 35,000 barrels per day with between 1,500 and 3,000 cubic yards per day of solids processed. Injected slurry density averaged about 9.5 ppg when solids were being processed (Exhibit 6). Surface injection pressure is heavily influenced by the slung injection rate, slurry density and to some extent slurry temperature due to viscosity dependence on temperature and the impact of injection temperature on formation stress. Daily average surface injection and calculated bottom -hole injection pressures (BHIP) are shown in Exhibit 6 for each well. BHIP is calculated to account for the effects of the hydrostatic head and fluid friction of the slurry column. The calculated bottom hole injection pressures in each well have shown relatively stable injection pressures over the last year. All three active wells have maintained good formation injectivity with no sign of formation plugging. 2 • • By design, the outer annulus (OA) of each GNI well is in weak pressure communication with the formation adjacent to its surface casing shoe set at about 4000 ft TVD (GNI -03 and GNI -04) and about 2800' TVD in the GNI -02A sidetrack. The surface pressure in each outer annulus is monitored as potential indicator of any significant fluid movement above the approved injection interval. The OA pressure is also quite sensitive to thermal expansion or contraction of the annulus fluids resulting from the injection cycle and injection fluid temperature variations. The inner and outer annuli of each well are closely monitored during a well swap and periods of higher temperature injection and the annulus pressures are bled as necessary. Due to the communication with the formation, OA pressure changes related to thermal effects begin to dissipate within a short time. There have been no significant sustained pressure increases adjacent to the surface casing shoe and no abnormal or unexplained annulus pressures observed during the report period. Each GNI well is equipped with control line tubing open ended within the inner annulus (IA) to about 1000 ft. This line allows several hundred feet of nitrogen cushion to be maintained in the inner annulus (IA) to dampen the pressure changes due to thermal expansion or contraction of the annulus fluid. There has been no indication of tubing or packer leakage observed in any of the GNI wells, although the IA pressure may need to be bled during periods of high temperature injection and re- charged during cooler injection periods. Exhibit 10 contains daily average tubing, IA and OA pressures for each of the wells. Dates when the annulus pressure was bled or re- pressured are also indicated. EPA witnessed mechanical integrity tests of the inner annulus are required annually under the Class I permit. The AOGCC requires an MIT -IA every two years in slurry injection wells under AIO 4E, Rule 6. Successful MIT -IA tests were performed in GNI wells 02A, 03 and 04 on September 22, 2011. EPA representatives witnessed each of these MIT -IA tests. Memory caliper Togs were run in GNI wells 02A, 03 and 04 to inspect the 7" tubing strings in 2011. GNI -01 has remained shut -in since May 2007 due to the level of tubing damage. The following table lists the observed maximum metal loss in the tubing and the casing below the packer from the caliper logs run during the report period. Well Date Max Pit Penetration Max Cross - Sectional Wall Loss _Tubing Casino Tubing Casino GNI -02A 09/23/11 33% 26% 24% 15% GNI -03 06/29/11 19% 52% 3% 24% GNI -04 07/11/11 33% 30% 15% 15% Due to a smaller volume of solids injected during the period, none of the Christmas trees were replaced due to erosion /corrosion damage during the report period. 3 • • Well Surveillance and Testing The cycling of injection to the wells generally allows well surveillance and maintenance activities to be scheduled with little disruption to G &I plant operations. To minimize freeze protection concerns, repeat well tests and Togs are usually scheduled in the summer. The shut in temperature /pressure survey results for 2011 and prior years are shown in Exhibit 7. Repeat shut -in temperature /pressure logs were run in the wells in June, July and October. Based on the fill tags and the temperature profiles, all injection continues to exit each wellbore through the perforated intervals. The temperature logs have very similar character to the previous logs in each well. Consistent with the 2010 results, the temperature logs have shown less than 500 feet TVD of vertical fluid movement. Since the GNI well bores are deviated and the effective depth of investigation of temperature logs is limited, the full extent of injection through vertical fractures may not be detected by the temperature logs. Observed static reservoir pressures obtained with the GNI -02A, 03 and 04 shut -in temperature /pressure logs were slightly lower than the 2010 measurements: -41 psi in GNI -02A, -41 psi in GNI -03, and -99 psi in GNI -04. Repeat step rate tests (SRTs) were performed in wells GNI -02A, 03 and 04 in June and October. The repeat SRT procedure included both a step up portion and a step down portion. Each SRT was analyzed using two methods to provide additional insight, a conventional analysis and a superposition method. The step rate test in well GNI -02A exhibited an unusual character with no specific fracture opening /propagation pressure indictated. This has been interpreted as injection into a pre- existing fracture or fracture network possibly held open by injected solids. Exhibit 8 discusses the 2011 step rate test data and analysis results. As in the past, SRT's confirm fractures are the primary disposal mechanism. Repeat surface pressure falloff (SPFO) tests were run in wells GNI -02A, 03 and 04 in June and September. Surface pressure falloff tests were run in the summer to avoid rate fluctuations due to freeze protection immediately prior to shut in. Also, since a well cannot be shut in while injecting slurry, each repeat SPFO test is run after a period of water injection containing only a small amount of mud liquids. No drilling mud was injected in the 24 hours prior to shutting in the well and the injection rate was stabilized. Normally, the SPFO tests are run after a period of seawater slurry injection however, seawater was unavailable for most of the summer. Modeling was undertaken and verified that consistent SPFO results could be expected after a period of produced water slurry injection. The SPFO tests should be viewed as representing a snapshot in time that may not completely reflect the downhole flow conditions present due to the differences with fluid rheology under actual slurry injection. As with past tests, calibrated surface memory gauges were used to record the pressure falloff data. 4 • • Exhibit 9 discusses the 2011 SPFO test analysis results. Several reservoir flow models were used in an attempt to obtain a type curve match of the data. The SPFO data from well GNI -02A was best matched using a radial composite double - porosity (RCDP) reservoir model. The data from GNI -03 was best matched using an infinite conductivity vertical fracture (IVCF) model. The data from GNI -04 was best matched using a radial composite double - porosity (RCDP) reservoir model. The tests from wells GNI -02A and GNI -03 showed evidence of a "boundary" or damaged zone some distance from the wellbore. Storage Mechanism and Disposal Domain As reported in the past, a number of industry studies have been conducted to understand the downhole storage mechanism in slurry injection operations. These include two major industry studies: the Drilling Engineering Associates (DEA) 81 Joint Industry Project (JIP) laboratory study and the Mounds Drill Cuttings Injection JIP field pilot study. Individual operators have also reported monitoring and well testing programs to delineate the storage mechanism and geometry. Many of these studies and monitoring programs agree that multiple fractures are created during periodic injection operations. Step rate tests and pressure falloff tests of the GNI wells have also showed signatures of multiple opening or multiple closure events, indicating multiple fractures from GNI operations. The result is likely a complex disposal domain consisting of a series of fractures developed over time with different orientations. Branching fractures may also be a part of the storage mechanism. This disposal domain allows for the storage of large amounts of solids. Grind and Inject fracture modeling was updated in 2006 using a modified conventional hard rock fracture simulator adjusted for soft rock behavior and assuming the disposal domain described above. The layer description was extended upward and downward to include 22 layers. The updated model runs predicted fractures to be contained below 5900 ft TVD at that time, about 600 ft above the perforations in the original GNI completions. At some point the increasing stress due to solids storage in the fractures of the disposal domain will create conditions resulting in possible additional upward fracture extension. The model results indicate fracture growth to near 5000 ft TVD at some time beyond the year 2020, still well below the top of the approved interval at about 4500 ft TVD. While the primary G &I surveillance techniques (temperature Togs, step rate tests and pressure falloff tests), the results from a prototype bore hole gravity meter reported in 2010 and the model results provide differing inferences as to the size of the fracture system (partially due to the specific conditions of each test), all indicate limited upward movement of the injected material and confinement well within the approved interval specified in AIO #4E, Rule 2. Well Plans Well GNI -01 has significant tubing damage and has injected over 1.6 MM cubic yards of waste drilling solids. Well GNI -01 could be available for occasional direct injection of Class II materials pending current mechanical integrity testing, and to observe various facets of the slurry injection process if needed. Routine waste injection is expected to continue to be cycled between the three Class 1 disposal wells. 5 • . Operational Plans The operational plan for the next twelve months will involve similar activities to those in recent years. Discussions are ongoing with Alaska Department of Environmental Conservation concerning the scope of the remaining production reserve pit closeout activities required by the State of Alaska's Inactive Reserve Pit Closure Regulations. While a significant feed for the G &I plant will be excavated drilling mud and cuttings from exploration reserve pits and well sites, the pace of excavation from the production reserve pits will likely remain reduced. As was the case in 2010, solid waste material will be processed in batches rather than continuously, except when the mill is shut down for maintenance, during well switches and for brief periods due to weather or utility outages. Class II liquids and solids from on -going drilling operations will be processed at the G &I plant on a periodic basis determined by the drilling and well workover schedules. Oily solids will be accepted at the material transfer station and processed at the G &I plant during winter months when the material can be handled in a frozen state and mixed with reserve pit wastes. Non - hazardous Class 1 materials will be processed and injected in the three active GNI slurry injection wells, GNI -02A, GNI -03 and GNI -04. Direct injection of crude oil contaminated with oil based drilling mud from the initial production from new wells and of other wastes will be utilized when necessary. Snow melt accumulating in reserve pits will be injected by the GNI plant in the summer as needed. Each of the three active GNI wells will be used for injection on a rotating schedule as described above. Anticipated major repairs in 2011 include replacement of the mill liner and various piping segments. 6 Exhibit 1 G &I Injection Summary Cumulative Thru September 30, 2011 Total GNI -1 GNI -2 GNI -02A GNI -3 GNI-4 Shut -In P &A Active Active Active Water Injection (MM Barrels) * 46.1 10.2 8.3 7.9 14.4 5.2 Slurry Injection (MM Barrels) ** 84.9 22.6 18.4 9.6 29.3 5.1 ill Total Injection (MM Barrels) * ** 131.0 32.8 26.8 17.5 43.7 10.3 Solids Injected (MM Tons) 5.2 1.5 1.2 0.5 1.8 0.2 Solids Injected (MM Cubic Yards) 5.8 1.6 1.3 0.5 2.1 0.3 Drilling Fluid Injected (MM Barrels) 6.5 1.3 1.0 1.2 2.3 0.7 Direct Injection (M Barrels) * * ** 173 38 28 8 99 0 • * includes bypass sea water and produced water injected during plant outages and upsets ** includes all fluids pumped from the G &I plant * ** includes slurry, water and direct injection * * ** Includes oil based mud, contaminated crude, other waste and flush water pumped at the well site by 0 4:1 BP Exploration (Alaska) Inc. j 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519 -6612 I (907) 561 -5111 November 15, 2010 1, 2a Commissioner Dan Seamount, Chairman Alaska Oil & Gas Conservation Commission ' 333 West 7 Avenue, Suite 100 ov 201® Anchorage, Alaska • 99501 qij & j Reference: Grind & Inject Project Annual Performance Report .t�i1Q�1Qt�� Dear Mr. Seamount. Enclosed is the Annual Performance Report for waste slurry injection for the Grind and Inject project located near Drill Site 4 in the Prudhoe Bay Unit. This report is submitted to satisfy the requirements of Area Injection Order #4E, Rule 10, as modified by Administrative Approval No. AIO 4C.001 and an Erratum Notice dated July 17, 2009. This requirement is very similar to an EPA report requirement regarding Prudhoe Bay Unit UIC Class I injection wells contained in EPA permit AK- 11008 -A. The report covers the period from October 1, 2009 through September 30, 2010 and was structured to satisfy both the AOGCC and the EPA requirements. Should you have questions concerning the contents of this report, contact me at 564 -4692. Sincerely, Q3 Michael L. Bill Senior Staff Engineer Cc: A. Cooke MB 11 -6 M. McAnulty 2238, 3000 C Street C. Burgh MB 11 -6 H. Engel MB 7 -5 K. Fontaine MB 11 Harrington /Cantrell PRB 42 B. Collver PRB 42 Fagerland /Gogart PRB 42 Winkel /Reyes PRB 42 Well Integrity Coordinator PRB 7 S. Kenshalo, ConocoPhillips P. Bennett, ExxonMobil • Prudhoe Bay Unit, Grind & Inject Project, Surfcote Pad Injection EPA UIC Class I Permit AK- 11008 -A Area Injection Order #4E, Rule 10 Annual Performance Report October 1, 2009 through September 30, 2010 This Annual Performance Report documents waste slurry injection on the Surfcote Pad near Drill Site 4 in the Prudhoe Bay Unit for the period October 1, 2009 through September 30, 2010. This report is submitted to satisfy the requirements of both EPA UIC Class I permit AK- 11008 -A, Part II 3 c 7 and AOGCC Area Injection Order (AIO) #4E, Rule 10, as modified by Administrative Approval AIO 4C.001 and Erratum Notice dated July 17, 2009. Additional information requested in a letter from the AOGCC (Regg to Bill 12/22/03) is also included. The report contains a brief description of the current project status, a summary of the disposal well performance data acquired during this period and operational plans for the next year. Project Status The Grind & Inject (G &I) Project at the Surfcote pad was undertaken in 1998 by the owners of the Prudhoe Bay Unit, Initial and Lisburne Participating Areas, and the Kuparuk River Unit to dispose of drilling muds and cuttings stored in reserve pits. Other non - hazardous wastes processed through the G &I Plant included those referenced in AIO #4E, Rule 2 as Class II wastes, consisting of RCRA- exempt drill cuttings and oily solids from pipeline pigging, vessel cleanouts and well workovers, and RCRA- exempt liquid wastes such as used drilling mud from on -going North Slope drilling operations. EPA issued Class I UIC permit AK-1 1008-A for the Grind & Inject Project effective September 1, 2007. Authorizations to inject Class I substances were received on January 18, 2008 for wells GNI -02A and GNI -03 and on May 6, 2008 for GNI -04. Well GNI -01 remains a Class II only disposal well. All non - hazardous wastes injected for disposal in the GNI wells during the report period are within the description of wastes referenced in EPA UIC Class I Permit AK- 11008 -A, Part II C 3 7, the UIC Class I permit application, or in Area Injection Order 46, Finding 7 as incorporated in AIO #4E. Several lined pits comprising the "material transfer station" (MTS) at DS 4 were operated to temporarily hold ongoing drilling and oily solids when necessary. On an infrequent basis, flow back liquids from new wells drilled with oil -based mud (OBM) or other wastes were injected directly into G &I wells using temporary equipment staged on the Surfcote pad. As of September 30, 2010, project injection has included 41.8 MM barrels of water, 81.4 MM barrels of slurry containing 5.1 MM tons (5.6 MM cubic yards) of excavated reserve pit material and other waste solids, and 5.9 MM barrels of fluid from ongoing drilling operations. Exhibit 1 summarizes this data. b, t� c S-1� 's , \ �M �a • • Operations Operations during the year were affected by seawater supply interruptions due to high winds, power outages, supply pipeline problems, and maintenance work at the Seawater Treatment Plant and the Seawater Injection plant. G &I maintenance activities included an extensive inspection program of the piping and processing equipment within the plant and the pipelines to the wells. Solids processing in the G &I plant was shut down in 2009 during the summer until late December and in 2010 from mid May through the present. Major repairs included replacement of process piping and valves, as well as repairs to the slurry tank, ball mill, metering, and pump electrical systems. Disposal of ongoing liquid drilling wastes and water from pit dewatering operations continued during much of the summer shut down period. Solid wastes accumulated during the summer were stored at the MTS and processed when the full plant was in operation. The pace of excavation from the production reserve pits was reduced in 2010 with the concurrence of the Alaska Department of Environmental Conservation and batch processing of solids rather than continuous processing was used during part of the winter. Well Operations and Monitoring The four GNI disposal wells are located on the Surfcote pad and continue to be available for disposal. Well GNI -01 has been shut -in due to tubing damage since May 2007, but it is available for Class II direct injection and observation purposes. It was replaced for Class I waste and slurry injection by well GNI -04 which began in May 2008. Well GNI -02A was sidetracked to a new bottom hole location in November /December 2006 and is an active Class I waste and slurry injector. Existing Class I well GNI -03 is also active after a workover in December 2009 to replace damaged tubing. Each well is perforated in the Ugnu formation between 6400 and 6600 ft TVD. GNI plant discharge rate, temperature and slurry density, along with injection well pressure and temperature and annulus pressures are continuously monitored in the G &I Plant control room. Slurry is injected into one well at a time on a rotating schedule. After each injection cycle, shut in wells are flushed with water and freeze protected with new product methanol mixed with water. Exhibit 4 lists the injection cycles and the well work and surveillance activities during the report period. The injection history and performance for each well is shown in Exhibits 1, 2, 3, 5, 6 and 10. Peak slurry injection rates are normally between 25,000 and 35,000 barrels per day with between 2,000 and 3,000 cubic yards per day of solids processed. Injected slurry density averaged about 9.5 ppg when solids were being processed (Exhibit 6). Surface injection pressure is heavily influenced by the slurry injection rate, slurry density and to some extent slurry temperature due to viscosity dependence on temperature and the impact of injection temperature on formation stress. Daily average surface injection and calculated bottom -hole injection pressures (SHIP) are shown in Exhibit 6 for each well. BHIP is calculated to account for the effects of the hydrostatic head and fluid friction of the slurry column. The calculated bottom hole injection pressures in each well have shown relatively stable injection pressures over the last year. All three wells have maintained good formation injectivity with no sign of formation plugging. 2 • • By design, the outer annulus (OA) of each GNI well is in weak pressure communication with the formation adjacent to its surface casing shoe set at about 4000 ft TVD (GNI -03 and GNI -04) and about 2800' TVD in the GNI -02A sidetrack. The surface pressure in each outer annulus is monitored as potential indicator of any significant fluid movement above the approved injection interval. The OA pressure is also quite sensitive to thermal expansion or contraction of the annulus fluids resulting from the injection cycle and injection fluid temperature variations. The OA of each well is closely monitored during a well swap and periods of higher temperature injection and the annulus pressure is bled as necessary. Due to the communication with the formation, OA pressure changes related to thermal effects begin to dissipate within a short time. There have been no significant sustained pressure increases adjacent to the surface casing shoe and no abnormal or unexplained annulus pressures observed during the report period. Each GNI well is equipped with control line tubing open ended within the inner annulus (IA) to about 1000 ft. This line allows several hundred feet of nitrogen cushion to be maintained in the IA to dampen the pressure changes due to thermal expansion or contraction of the annulus fluid. There has been no indication of tubing or packer leakage observed in any of the GNI wells, although the IA pressure may need to be bled during periods of high temperature injection and re- charged during cooler injection periods. Exhibit 10 contains daily average tubing, IA and OA pressures for each of the wells. Dates when the annulus pressure was bled or re- pressured are also indicated. EPA witnessed mechanical integrity tests of the inner annulus are required annually under the Class I permit. The AOGCC requires an MIT -IA every two years in slurry injection wells under AIO 4E, Rule 6. Successful MIT -IA tests were performed in GNI wells 02A, 03 and 04 on September 26, 2010. EPA representatives witnessed each of these MIT -IA tests. Memory caliper logs were run in GNI wells 02A, 03 and 04 to inspect the 7" tubing strings in 2010. GNI -01 has remained shut -in since May 2007 due to the level of tubing damage. The following table lists the observed maximum metal loss in the tubing and the casing below the packer from the caliper logs run during the report period. Well Date Max Pit Penetration Max Cross - Sectional Wall Loss Tubinq Casino Tubinq Casing GNI -02A 06/30/10 29% 26% 20% 16% GNI -03 05/26/10 <10% 42% <3% 24% GNI -04 06/12/10 22% 30% <13% 18% After isolation of the tubing with bridge plugs and /or back pressure valves, the trees on each of the wells were replaced and inspected for erosion /corrosion damage. Well Surveillance and Testing The cycling of injection to the wells generally allows well surveillance and maintenance activities to be scheduled with little disruption to G &I plant operations. To minimize freeze protection concerns, repeat well tests and logs are usually scheduled in the summer. The shut in temperature /pressure survey results for 2010 and prior years are shown in Exhibit 7. Repeat shut -in temperature /pressure logs were run in the wells in June and July. Based on the fill tags and the temperature profiles, all injection continues to exit each wellbore through the perforated intervals. The temperature logs have very similar character to the previous logs in each well. Consistent with the 2009 results, the \400�M00— temperature logs have shown less tha 500 feet TVD of vertical fluid mo vement. Since the GNI well bores are deviated and the effective depth of investigation of temperature logs is limited, the full extent of injection through vertical fractures may not be detected' by the temperature logs. Observed static reservoir pressures obtained from the GNI -02A, 03 and 04 shut -in temperature /pressure logs were slightly higher than the previous measurements: 38 psi in GNI -02A, 11 psi in GNI -03, and 83 psi in GNI -04. Repeat step rate tests (SRTs) were performed in wells GNI -02A, 03 and 04 in July and August. The repeat SRT procedure included both a step up portion and a step down portion. Each SRT was analyzed using two methods to provide additional insight, a conventional analysis and a superposition method. The step rate tests in wells GNI -02A and 03 exhibited an unusual character. This has been interpreted as injection into a pre- existing fracture or fracture network possibly held open by injected solids. Later in the test, the flow appeared to be dominated by a period of pressure dependent leak off from a non - propagating fracture. In the case of GNI -04 with less slurry injection prior to the test, there is a less complicated fracture network due to the lower cumulative solids injection. Exhibit 8 discusses the 2010 step rate test data and analysis results. As in the past, SRT's confirm fractures are the primary disposal mechanism. Repeat surface pressure falloff (SPFO) tests were run in wells GNI -02A, 03 and 04 in July and August. Surface pressure falloff tests were run in the summer to avoid rate fluctuations due to freeze protection immediately prior to shut in. Also, since a well cannot be shut in while injecting slurry, each repeat SPFO test is run after a period of water injection containing only a small amount of mud liquids. No drilling mud was injected in the 24 hours prior to shutting in the well and the injection rate was stabilized. Given these factors, the SPFO tests should be viewed as representing a snapshot in time that may not completely reflect the downhole flow conditions present due to the differences with fluid rheolo under actual slur injection. As with past tests calibrated 9Y slurry J p surface memory gauges were used to record the pressure falloff data. Exhibit 9 discusses the 2010 SPFO test analysis results. Several reservoir flow models were used in an attempt to obtain a type curve match of the data. The SPFO data from well GNI -02A was best matched using a radial composite homogeneous (RCH) reservoir model and GNI -03 was best matched using an infinite conductivity vertical fracture (IVCF) model. The data from GNI -04 was difficult to match with a single model. To gain insight into this well, the early period data was matched with the IVCF model and the late time data was matched using the RCH model. The tests from each well showed evidence of a "boundary" or damaged zone some distance from the wellbore. In general, the reservoir parameters derived from the tests were similar to those from 2009. A prototype bore hole gravity meter logging tool was run in well GNI -03 in July. The tool was developed by Scintrex Ltd and was run by Schlumberger. The tool was designed to 4 • • measure the gravitational field surrounding the wellbore at various depths and can potentially detect very small changes in formation density as a result of changes in fluid saturation or the accumulation of injected solids. Well GNI -03 was chosen for the test of this tool due to its high cumulative solids injection. A comparison of the results of the log with the original open hole density log showed good agreement except just above the perforated interval. These preliminary results appear to confirm the solids placement in or near the primary disposal injection interval with little upward movement of injected solids. Storage Mechanism and Disposal Domain As reported in the past, a number of studies have been conducted to understand the downhole storage mechanism in slurry injection operations. These include two major industry studies: the Drilling Engineering Associates (DEA) 81 Joint Industry Project (JIP) laboratory study and the Mounds Drill Cuttings Injection JIP field pilot study. Individual operators have also reported monitoring and well testing programs to delineate the storage mechanism and geometry. Most of these studies and monitoring programs agree that multiple fractures are created during periodic injection operations. Step rate tests and pressure falloff tests of the GNI wells have also showed signatures of multiple opening or multiple closure events, indicating multiple fractures from GNI operations. The result is likely a complex disposal domain consisting of a series of fractures developed over time with different orientations. Branching fractures may also be a part of the storage mechanism. This disposal domain allows for the storage of large amounts of solids. Fracture modeling was updated in 2006 using a modified conventional hard rock fracture simulator adjusted for soft rock behavior and assuming the disposal domain described above. The layer description was extended upward and downward to include 22 layers. The updated model runs predicted fractures to be contained below 5900 ft TVD at that time, about 600 ft above the perforations in the original GNI completions. At some point the increasing stress due to solids storage in the fractures P P 9 9 of the disposal domain will create conditions resulting in possible additional upward a d fracture extension. The model results indicate fracture growth to near 5000 ft TVD at some time beyond the year 2020, still well below the top of the approved interval at about 4500 ft TVD. While the primary G &I surveillance techniques (temperature logs, step rate tests and pressure falloff tests) and the model results provide differing inferences as to the size of the fracture system (partially due to the specific conditions of each test), all indicate limited upward movement of the injected material and confinement well within the approved interval specified in AIO #4E, Rule 2. Well Plans Well GNI -01 has significant tubing damage and has injected over 1.6 MM cubic yards of waste drilling solids. Well GNI -01 will be available for occasional direct injection of Class II materials and to observe various facets of the slurry injection process. Operational Plans The operational plan for the next twelve months will involve similar activities to those in recent years. Discussions are ongoing with Alaska Department of Environmental 5 Conservation concerning i closeout the scope of the remaining production reserve t e 9 P 9P p activities required by the State of Alaska's Inactive Reserve Pit Closure Regulations. While a significant feed for the G &I plant will be excavated drilling mud and cuttings from old exploration reserve pits and well sites, the pace of excavation from the production reserve pits will likely remain reduced. As was the case for a portion of last winter, solid waste material will be processed in batches rather than continuously, except when the mill is shut down for maintenance, during well switches and for brief periods due to weather or utility outages. Class II liquids and solids from on -going I r I n on a periodic basis determined b drilling operations will be processed at the G& plant 9 p p p p Y the drilling and well workover schedules. Oily solids will be accepted at the material transfer station and processed at the G &I plant during winter months when the material can be handled in a frozen state and mixed with reserve pit wastes. Non - hazardous Class I materials will be processed and injected in the three active GNI slurry injection wells, GNI -02A, GNI -03 and GNI -04. Direct injection of crude oil contaminated with oil based drilling mud from the initial production from new wells and of other wastes will be utilized when necessary. Snow melt accumulating in reserve pits will be injected by the GNI plant in the summer as needed. Each of the three active GNI wells will be used for injection on a rotating schedule as described above. Anticipated major repairs in 2010 include replacement of the mill liner and various piping segments. 6 0 0 Prudhoe Bay Unit, Grind & Inject Project, Surfcote Pad Injection EPA UIC Class I Permit AK-1 1008-A Area Injection Order #4E, Rule 10 Annual Performance Report October 1, 2009 through September 30, 2010 List of Exhibits 1. GNI Surfcote Injection Summary 2. GNI Injection Bar Graph 3. a,b GNI Solids Injection Bar Graphs 4. GNI Surfcote Well Surveillance Activities 5. a,b,c,d GNI Wells Injection Bar Graphs 6. a,b,c,d GNI Wells Daily Average Data Plots 7. b,c,d GNI Wells Temperature Logs 8. GNI Wells Step Rate Tests 9. GNI Wells Pressure Falloff Tests 10. a,b,c,d GNI Wells TIO Pressure plots 7 Exhibit 1 G &I Injection Summary Cumulative Thru September 30, 2010 Total GNIA GNI -2 GNI -02A GNI -3 GNI-4 Shut -In P &A Active Active Active tU tl e. Water Injection (MM Barrels) * 41.8 10.2 8.3 6.6 12.7 4.0 Slurry Injection (MM Barrels) ** 81.4 22.6 18.4 8.2 28.2 4.0 Total Injection (MM Barrels) * ** 123.2 32.8 26.8 14.7 40.9 8.0 Solids Injected (MM Tons) 5.1 1.5 1.2 0.4 1.8 0.2 Solids Injected (MM Cubic Yards) 5.6 1.6 1.3 0.5 2.0 0.2 Drilling Fluid Injected (MM Barrels) 5.9 1.3 1.0 1.0 2.1 0.5 Direct Injection (M Barrels) 169 38 28 4 99 0 * includes bypass sea water and produced water injected during plant outages and upsets ** includes all fluids pumped from the G &I plant includes slurry, water and direct injection " * ** Includes oil based mud, contaminated crude, other waste and flush water pumped at the well site by • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519 -6612 (907) 561 -5111 November 13, 2009 Commissioner Dan Seamount, Chairman N J ' > Alaska Oil & Gas Conservation Commission 333 West 7 Avenue, Suite 100 lAlaska 'll . 53 Cana a1 v'M miss c €l Anchorage, Alaska AnchuRgs 99501 Reference: Grind & Inject Project Annual Performance Report Dear Mr. Seamount: p Enclosed is the Annual Performance Report for waste slurry injection for the Grind and Inject project located near Drill Site 4 in the Prudhoe Bay Unit. This report is submitted to satisfy the requirements of Area Injection Order #4E, Rule 10, as modified by Administrative Approval No. AIO 4C.001 and an Erratum Notice dated July 17, 2009. This requirement is very similar to an EPA report requirement regarding Prudhoe Bay Unit UIC Class I injection wells contained in EPA permit AK- 11008 -A. The report covers the period from October 1, 2008 through September 30, 2009 and was structured to satisfy both the AOGCC and the EPA requirements. Should you have questions concerning the contents of this report, contact me at 564 -4692. Sincerely, - C ) ; - Q ( a° `� Michael L. Bill Senior Staff Engineer - -- Vri Cc: A. Cooke MB 11 -6 R. Bullock MB 11 -6 M. McAnuity MB 11 -6 C. Burgh MB 11 -6 A. Chow MB 3 H. Engel MB 7 -5 Harrington /Cantrell PRB 42 Ohnemus /Fagerland PRB 42 Collver /Dawley PRB 42 Well Integrity Coordinator PRB 7 GPB Environmental Team Leader PRB 7 S. Kenshalo, ConocoPhillips P. Bennett, ExxonMobil Prudhoe Bay Unit, Grind & Inject Project, Surfcote Pad Injection EPA UIC Class I Permit AK- 11008 -A Area Injection Order #4E, Rule 10 Annual Performance Report October 1, 2008 through September 30, 2009 This Annual Performance Report documents waste slurry injection on the Surfcote Pad near Drill Site 4 in the Prudhoe Bay Unit for the period October 1, 2008 through September 30, 2009. This report is submitted to satisfy the requirements of both EPA UIC Class I permit AK- 11008 -A, Part II 3 c 7 and AOGCC Area Injection Order (AIO) #4E, Rule 10, as modified by Administrative Approval AIO 4C.001 and Erratum Notice dated July 17, 2009. Additional information requested in a letter from the AOGCC (Regg to Bill 12/22/03) is also included. The report contains a brief description of the current project status, a summary of the disposal well performance data acquired during this period and operational plans for the next year. Project Status In 1998, the Grind & Inject (G &1) Project at the Surfcote pad was undertaken by the owners of the Prudhoe Bay Unit, Initial and Lisburne Participating Areas, and the Kuparuk River Unit to dispose of drilling muds and cuttings stored in reserve pits. Other non - hazardous wastes processed through the G &I Plant included those referenced in AIO #4E, Rule 2 as Class 11 wastes, consisting of RCRA- exempt drill cuttings and oily solids from pipeline pigging, vessel cleanouts and well workovers, and RCRA- exempt liquid wastes such as used drilling mud from on -going North Slope drilling operations. EPA issued Class I UIC permit AK- 11008 -A for the Grind & Inject Project effective September 1, 2007. Authorizations to inject Class I substances were received on January 18, 2008 for wells GNI -02A and GNI -03 and on May 6, 2008 for GNI -04. Well GNI -01 remains a Class 11 only disposal well. All non - hazardous wastes injected for disposal in the GNI wells during the report period are within the description of wastes referenced in EPA UIC Class I Permit AK- 11008 -A, Part 11 C 3 7, the UIC Class I permit application, or in Area Injection Order 413, Finding 7 as incorporated in AIO #4E. Several lined pits comprising the "material transfer station" (MTS) at DS 4 were operated to temporarily hold ongoing drilling and oily solids when necessary. On an infrequent basis, flow back liquids from new wells drilled with oil -based mud (OBM) or other wastes were injected directly into G &I wells using temporary equipment staged on the Surfcote pad. As of September 30, 2009, project injection has included 36.2 MM barrels of water, 77.8 MM barrels of slurry containing 4.9 MM tons (5.5 MM cubic yards) of excavated reserve pit material and other waste solids, and 5.3 MM barrels of fluid from ongoing drilling operations. Exhibit 1 summarizes this data. 1 Operations Operations during the year were affected by seawater supply interruptions due to high winds, power outages, supply pipeline problems, and maintenance work at the Seawater Treatment Plant and the Seawater Injection plant. G &I maintenance activities included an extensive inspection program of the piping and processing equipment within the plant and the pipelines to the wells. Solids processing in the G &I plant was shut down from late May through October for inspections and maintenance. Major repairs included replacement of process piping, as well as repairs to the seawater heater. Repairs were also made to the ball mill, feed hopper, conveyor, slurry tank and injection pumps. Disposal of ongoing liquid drilling wastes and water from pit dewatering operations continued during much of the summer shut down period. Solid wastes accumulated during the summer were stored at the MTS. Well Operations and Monitoring The four GNI disposal wells are located on the Surfcote pad and continue to be available for disposal. Well GNI -01 has been shut -in due to tubing damage since May 2007, but it is available for Class II direct injection and observation purposes. It was replaced for Class I waste and slurry injection by well GNI -04 which began in May 2008. Well GNI -02A was sidetracked to a new bottom hole location in November /December 2006 and is an active Class I waste and slurry injector. Existing Class I well GNI -03 is also active. Each well is perforated in the Ugnu formation between 6400 and 6600 ft TVD. GNI plant discharge rate, temperature and slurry density, along with injection well pressure and temperature and annulus pressures are continuously monitored in the G &I Plant control room. Slurry is injected into one well at a time on a rotating schedule. After each injection cycle, shut in wells are flushed with water and freeze protected with new product methanol mixed with water. Exhibit 4 lists the injection cycles and the well work and surveillance activities during the report period. The injection history and performance for each well is shown in Exhibits 1, 2, 3, 5, 6 and 10. Peak slurry injection rates are normally between 25,000 and 35,000 barrels per day with between 2,000 and 3,000 cubic yards per day of solids processed. Injected slurry density averaged about 9.5 ppg when solids were being processed (Exhibit 6). Surface injection pressure is heavily influenced by the slurry injection rate, slurry density and to some extent slurry temperature due to viscosity dependence on temperature and the impact of injection temperature on formation stress. Daily average surface injection and calculated bottom -hole injection pressures (BHIP) are shown in Exhibit 6 for each well. BHIP is calculated to account for the effects of the hydrostatic head and fluid friction of the slurry column. The calculated bottom hole injection pressures in each well have shown relatively stable injection pressures over the last year. All three wells have maintained good formation injectivity with no sign of formation plugging. By design, the outer annulus (OA) of each GNI well is in weak pressure communication with the formation adjacent to its surface casing shoe set at about 4000 ft TVD (GNI -03 and GNI -04) and about 2800' TVD in the GNI -02A sidetrack. The surface pressure in each outer annulus is monitored as potential indicator of any significant fluid movement above the approved injection interval. The OA pressure is also quite sensitive to 2 thermal expansion or contraction of the annulus fluids resulting from the injection cycle and injection fluid temperature variations. The OA of each well is closely monitored during a well swap and periods of higher temperature injection and the annulus pressure is bled as necessary. Due to the communication with the formation, OA pressure changes related to thermal effects begin to dissipate within a short time. There have been no significant sustained pressure increases adjacent to the surface casing shoe and no abnormal or unexplained annulus pressures observed during the report period. Each GNI well is equipped with control line tubing open ended within the inner annulus (IA) to at least 1000 ft. This line allows several hundred feet of nitrogen cushion to be maintained in the IA to dampen the pressure changes due to thermal expansion or contraction of the annulus fluid. There has been no indication of tubing or packer leakage observed in any of the GNI wells, although the IA pressure may need to be bled during periods of high temperature injection and re- charged during cooler injection periods. Exhibit 10 contains daily average tubing, IA and OA pressures for each of the wells. Dates when the annulus pressure was bled or re- pressured are also shown. EPA witnessed mechanical integrity tests of the inner annulus are required annually under the Class I permit. The AOGCC requires an MIT -IA every two years in slurry injection wells under AIO 4E, Rule 6. Successful MIT -IA tests were performed in GNI wells 02A, 03 and 04 on October 7, 2008 and in wells 02A and 04 on September 28, 2009. EPA representatives witnessed each of these MIT -IA tests. Memory caliper logs were run in GNI wells 02A, 03 and 04 to inspect the 7" tubing strings in 2009. As noted in previous reports, a significant amount of erosion /corrosion related metal loss has been seen in well GNI -03. Due to the unknown rate of metal loss, the operator specified maximum IA pressure has been reduced to 1000 psi. A rig workover to replace the tubing string in GNI -03 is planned for 4th quarter 2009. GNI -01 has remained shut -in since May 2007 due to the level of tubing damage. The following table lists the observed maximum metal loss in the tubing and the casing below the packer from the caliper logs run during the report period. Well Date Max Pit Penetration Max Cross - Sectional Wall Loss Tubinq Casinq Tubin Casing GNI -02A 07/01/09 26% 24% 19% <14% GNI -03 11/13/08 60% 34% 49% 20% GNI -03 04/13/09 60% 33% 52% 20% GNI -04 01/27/09 19% 31% 12% 18% After isolation of the tubing with bridge plugs and /or back pressure valves, the trees on wells GNI -02A and 04 were replaced and inspected for erosion /corrosion damage. Well Surveillance and Testing The cycling of injection to the wells generally allows well surveillance and maintenance activities to be scheduled with little disruption to G&I plant operations. To minimize freeze protection concerns, repeat well tests and logs are usually scheduled in the summer. 3 • • The shut in temperature /pressure survey results for 2009 and prior years are shown in Exhibit 7. Repeat shut -in temperature /pressure logs were run in well GNI -04 in January, GNI -03 in June and GNI -02A in July. Based on the fill tags and the temperature profiles, all injection continues to exit each wellbore through the perforated intervals. The temperature logs have very similar character to the previous logs in each well. Consistent with the 2008 results, the temperature logs have shown less than 400 feet TVD of vertical fluid movement. Since the GNI well bores are deviated and the effective depth of investigation of temperature logs is limited, the full extent of injection through vertical fractures may not be detected by the temperature logs. Observed static reservoir pressures obtained from the GNI -02A and 03 shut -in temperature /pressure logs were slightly lower (20 psi) in GNI -02A and slightly higher (5 psi) in GNI -03 than observed in 2008. Repeat step rate tests (SRTs) were performed in wells GNI -02A, 03 and 04 in May through August. The repeat SRT procedure included both a step up portion and a step down portion. Each SRT was analyzed using three methods to provide additional insight: conventional analysis, multi -rate pressure transient analysis and a superposition method. The step rate tests in all three slurry injection wells exhibited an unusual character. This has been interpreted as injection into a pre- existing fracture or fracture network possibly held open by injected solids. Later in the test, the flow appeared to be dominated by a period of pressure dependent leak off from a non - propagating fracture. In the case of GNI -04 with less slurry injection prior to the test, there may be some connection to the mature fracture network established in offset shut -in well GNI -01. Exhibit 8 discusses the 2009 step rate test data and analysis results. As in the past, SRT's confirm fractures are the primary disposal mechanism. Repeat surface pressure falloff (SPFO) tests were run in wells GNI -02A, 03 and 04 in June through August. Surface pressure falloff tests were run in the summer to avoid rate fluctuations due to freeze protection immediately prior to shut in. Also, since a well cannot be shut in while injecting slurry, each repeat SPFO test is run after a period of water injection containing only a small amount of mud liquids. No drilling mud was injected in the 24 hours prior to shutting in the well. Given these factors, the SPFO tests should be viewed as representing a snapshot in time that may not completely reflect the downhole flow conditions present due to the differences with fluid rheology under actual slurry injection. As with past tests, calibrated surface memory gauges were used to record the pressure falloff data. Exhibit 9 discusses the 2009 SPFO test analysis results. Various reservoir flow models were used in an attempt to obtain a type curve match of the data. The SPFO data from wells GNI -02A and GNI -03 were best matched using fractured reservoir models while the data from GNI -04 was best matched using a homogeneous reservoir model, although there was indication of a small fracture. The tests from each well showed evidence of a "no flow boundary" or damaged zone some distance from the wellbore. In general, the reservoir parameters derived from the tests were similar to those from 2008, but there was no evidence of multiple fractures evident in the 2009 tests. 4 • Storage Mechanism and Disposal Domain As reported in the past, a number of studies have been conducted to understand the downhole storage mechanism in slurry injection operations. These include two major industry studies: the Drilling Engineering Associates (DEA) 81 Joint Industry Project (JIP) laboratory study and the Mounds Drill Cuttings Injection JIP field pilot study. Individual operators have also reported monitoring and well testing programs to delineate the storage mechanism and geometry. Most of these studies and monitoring programs agree that multiple fractures are created during periodic injection operations. Step rate tests and pressure falloff tests of the GNI wells have also showed signatures of multiple opening or multiple closure events, indicating multiple fractures from GNI operations. The result is likely a complex disposal domain consisting of a series of fractures developed over time with different orientations. Branching fractures may also be a part of the storage mechanism. This disposal domain allows for the storage of large amounts of solids. Fracture modeling was updated in 2006 using a modified conventional hard rock fracture simulator assuming the disposal domain described above. The layer description was extended upward and downward to now include 22 layers. The updated model runs predicted fractures to be contained below 5900 ft TVD at that time, about 600 ft above the perforations in the original GNI completions. At some point the increasing stress due to solids storage in the fractures of the disposal domain will create conditions resulting in additional upward fracture extension. The model results indicate fracture growth to near 5000 ft TVD sat some time beyond the year 2020, still well below the top of the approved interval at about 4500 ft TVD. While the primary G &I surveillance techniques (temperature logs, step rate tests and pressure falloff tests) and the model results provide differing inferences as to the size of the fracture system (partially due to the specific conditions of each test), all indicate limited upward movement of the injected material and confinement well within the approved interval specified in AIO #4E, Rule 2. Well Plans Well GNI -01 has significant tubing damage and has injected over 1.6 MM cubic yards of waste drilling solids. Well GNI -01 will be available for occasional direct injection of Class II materials and to observe various facets of the slurry injection process. Well GNI -03 has significant tubing damage and has injected about 2.0 MM cubic yards of waste drilling solids. A rig workover to replace the tubing string in GNI -03 is planned for 4th quarter 2009. Operational Plans The operational plan for the next twelve months will involve similar activities to those in recent years. Discussions are ongoing with Alaska Department of Environmental Conservation concerning the scope of the remaining production reserve pit closeout activities required by the State of Alaska's Inactive Reserve Pit Closure Regulations. While a significant feed for the G &I plant will be excavated drilling mud and cuttings from reserve pits and from old exploration well sites, the pace of excavation from the 5 • 0 production reserve pits may be reduced. This winter solid waste material may be processed in batches rather than continuously, except when the mill is shut down for maintenance, during well switches and for brief periods due to weather or utility outages. Class II liquids and solids from on -going drilling operations will be processed at the G &I plant on a periodic basis determined by the drilling and well workover schedules. Oily solids will be accepted at the material transfer station and processed at the G &I plant during winter months when the material can be handled in a frozen state and mixed with reserve pit wastes. Non - hazardous Class I materials will be processed and injected in the three active GNI slurry injection wells, GNI -02A, GNI -03 and GNI -04. Direct injection of crude oil contaminated with oil based drilling mud from the initial production from new wells and of other wastes will be utilized when necessary. Snow melt accumulating in reserve pits will be injected by the GNI plant in the summer as needed. Each of the three active GNI wells will be used for injection on a rotating schedule as described above. Anticipated major repairs in 2009 include replacement of the mill liner and various piping segments. 6 9 0 Prudhoe Bay Unit, Grind & Inject Project, Surfcote Pad Injection EPA UIC Class I Permit AK- 11008 -A Area Injection Order #4E, Rule 10 Annual Performance Report October 1, 2008 through September 30, 2009 List of Exhibits 1. GNI Surfcote Injection Summary 2. GNI Injection Bar Graph 3. a,b GNI Solids Injection Bar Graphs 4. GNI Surfcote Well Surveillance Activities 5. a,b,c,d GNI Wells Injection Bar Graphs 6. a,b,c,d GNI Wells Daily Average Data Plots 7. b,c,d GNI Wells Temperature Logs 8. GNI Wells Step Rate Tests 9. GNI Wells Pressure Falloff Tests 10. a,b,c,d GNI Wells TIO Pressure plots 7 Exhibit 1 G &I Injection Summary Cumulative Thru September 30, 2009 Total GNI -1 GNI -2 GNI -02A GNI -3 GNI-4 SAPN 11 :67= 5, 10 - 1 Water Injection (MM Barrels) * 36.4 10.2 8.3 4.3 11.7 1.9 Slurry Injection (MM Barrels) ** 77.8 22.6 18.4 6.8 27.2 2.8 Total Injection (MM Barrels) * ** 114.2 32.8 26.8 11.1 38.8 4.7 Solids Injected (MM Tons) 4.9 1.5 1.2 0.4 1.8 0.1 Solids Injected (MM Cubic Yards) 5.5 1.6 1.3 0.4 2.0 0.2 Drilling Fluid Injected (MM Barrels) 5.3 1.3 1.0 0.7 1.9 0.3 Direct Injection (M Barrels) * * ** 169 38 28 4 99 0 * includes bypass sea water and produced water injected during plant outages and upsets ** includes all fluids pumped from the G &I plant * ** includes slurry, water and direct injection * * ** Includes oil based mud, contaminated crude, other waste and flush water pumped at the well site ~ ~~~~ • To: JimRegg `C~ p ~`~l~Gnc'i P.I. Supervisor ; `fi`r I FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 08, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC GNI-01 PRUDHOE BAY UNIT GNI-Ol Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv -1~~- Comm Well Name• PRUDHOE BAY UNIT GNI-O1 API Well Number: 50-029-22845-00-00 Inspector Name' Bob Noble Insp Num: mitRCN0 80704 1 82 93 9 Permit Number: 197-238-0 Inspection Date: 7l4~2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I GNI-O] Type In]. N ~ TVD ~ 3982 IA ~ 70 ~ 1600 1550 1550 ~ P.T. I 1972380 TypeTest SPT Test psi it 1600 / OA 210 ~ 460 450 ~ 430 Interval OTHER p~F, P / Tllbing I 1200 1430 ~ 1430 1420 j Notes' MIT-IA for 2 year slurry injection compliance. 1250 psi held on tubing to prevent collapse. I ask Josh Moralas if we could put more than 1600 psi on the IA for needed DP for tubing. He said he was instructed to put 1600 pis on the IA. I saw a paper in the wellhouse stating MAX IA pressure to be 1000 psi. ~~~N~E~ AU G ~ ~ 2t~ Tuesday, July 08, 2008 Page 1 of l PBU GNI-O1 Change of Service • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, May 08, 2008 1:53 PM To: 'Bill, Michael L (Natchiq)' Cc: DOA AOGCC Prudhoe Bay Subject: RE: PBU GNI-01 Change of Service ~ ~~~~~ Page 1 of 2 Mike, per our discussion this morning, the Commission still considers GNI-01 to be a slurry injector and must continue to be tested an a 2 year MIT cycle. We understand the well is disconnected fram the GNI facility, however, BP expects to periodically use the well to inject discrete volumes of Class II wastes at low rates, including used muds. Because of the unscheduled nature of future injection into GNI-01, it is acceptable to have the Commission witness these biennial MITs prior to injecting into the wail and forgo the typical witnessed MIT once injection has commenced and well conditions have stabilized. Jim Regg AoGCC ~„~~~~~~ MAY ~ ~~ 200E From: Bill, Michael L (Natchiq) [mailto:Michael.Bill@bp.com] Sent: Monday, April 21, 2008 9:19 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Engel, Harry R; NSU, ADW Well Integrity Engineer Subject: RE: PBU GNI-01 Change of Service Jim, In your note bekaw you indicated you had some concerns about our plans to begin MIT-IA testing in well GNI- 01 on a 4 year cycle. We no longer consider the well a slurry injection well for the Prudhoe Bay G&I project and it is nat permitted for Class I injection under the EPA permit. While we have no immediate plans to use the well, we need to confirm it's status in regard to MiT's so we can be sure it is fully available when it is needed. Please confirm the MIT frequency required for this well. Update on GNI-04 (replacement for GNI-01): -MIT-IA passed an 3/22f08, EPA witnessed - Step rate test and waterflow log now tentatively scheduled for Wednesday this week. -after EPA approval to inject is received, we wilt add the well to the normal GNI well station. Please call if you have questions, Mike Bill ADW Wells Group 907-564-4692 office 907-564-5510 fax From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, March 11, 2008 4:27 PM To: Bill, Michael L (Natchiq) Cc: Maunder, Thomas E (DOA) Subject: RE: PBU GNI-01 Change of Service • 5/8/2008 PBU GNI-O1 Change of Service • Page 2 of 2 Not sure I agree with the change of MIT cycle for GNI-01. This will require some addition review from us. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Bill, Michael L (Natchiq) [mailto:Michael.Bill@bp.com] Sent: Tuesday, March 11, 2008 3:50 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSU, ADW Well Integrity Engineer; Cooke, Alison D; GPB, Environ Advisor (Services); Engel, Harry R Subject: PBU GNI-01 Change of Service Jim, Prudhoe Bay well GNI-01 was drilled and completed as a Class II slurry disposal well in 1998 as part of the Grind & Inject project (G&I). The well was used for slurry disposal from 1998 until May 2007 when it was shut in due to tubing erosion concerns. There is no indication of any pressure communication. GNI-01 is currently shut in and it's flowline from the G&I plant has been removed. Well GNI-01 will now be replaced as a slurry disposal well by new well GNI-04. In the future, GNI-01 will be used as a Class II disposal well for periodic "direct inject" of waste fluids and also for G&I monitoring purposes. "Direct Inject" refers to the use of pumping equipment and tanks staged at the well to batch inject Class II waste material. The wastes are manifested and the injection rate, volume and well pressures are recorded during the pumping operation. The last GNI-01 MIT-IA took place on 04/22/06. AIO-4E, Rule 6 requires an MIT-IA every 2 years for slurry injection wells and every 4 years for other injection wells. As this well will no longer be a slurry disposal well, we intend to perform the next MIT-IA in 2010, 4 years after the 2006 MIT. Slurry disposal wells GNI-02A and GNI-03 have been approved for Class I disposal injection by the EPA. Disposal has not yet begun in new slurry injection well GNI-04, but EPA witnessed testing is planned for the week of March 17. Please contact me if you have any questions, Mike Bill ADW Wells Group 907-564-4692 office 907-564-5510 fax 5/8/2008 bp . . / (7:~ 7 I ' ,.., {. '} /)' \/ /1 ~O (:; >), Â ì UìíJ7 u 3/fPU !- I, & BP Exploration (Alaskallnc. Box 196612 East Benson Boulevard Anchorage, AK 99519-6612 By Certified Mail to EPA only #700707100001 86209275 August 22, 2007 Mr. Michael Bussell Director, Office of Compliance and Enforcement U.S. Environmental Protection Agency 1200 Sixth Avenue -------Seatt~1-0t-~~~-~~~~----_~_____~ -~~---- Mr. Trevor Fairbanks Department of Environmental Conservation 555 Cordova St. Anchorage, Alaska 99501 SCANNED SEP 1 1 Z007 Mechanicallntegritv Test Notification and Log Transmittal Prudhoe Bay, Pad 3 and Grind and Iniect UIC Permit Number AK-11004-A UIC Permit Number AK-11008-A Wastewater Disposal Permit No. 2004-DB0084 Dear Sirs: BP Exploration (Alaska) Inc. (BPXA) respectfully submits the following notification to meet the requirements in Part II, C, 3, c, (3) for conducting Mechanical Integrity Tests (MITs) at the Prudhoe Bay Pad 3 and Grind and Inject Class I Injection Well Facilities (Permits AK-11004-A and AK-11008-A). In addition to the MIT at Pad 3, the annual fluid movement logging will also be conducted. The annual surveillance procedure will be sent electronically to Mr. Thor Cutler for his approval. . . MIT Notification August22,2007 Page 2 The MITs and fluid movement logs are currently sct1eduled for the first week of October. BPXA will notify your staff when a better estimate of the timing is known. Also included as attachments are copies of the shut-in temperature logs run on the Grind and Inject wells and copies of a descriptive report as required by Part II. C, 3, b, (2) and Part II, C, 3, c, (1) of Permit AK-11008-A. The second copy of the logs and descriptive report is being sent to Mr. Talib Syed. If you have any questions, please contact Ms. Alison Cooke at (907) 564-4838 or Mr, Mike Bill at (907)-564-4692, ----_..._-~- .-~~-_._--_. ~-'-~-'-'--'---------- Sincerely, í' ~, /'\;)''7&, f /"'/' ¡ "./ - \ ./ Þ /1' '" \</-v':~ Neil Dunn NSU Infrastructure Manager Attachments cc: Thor Cutler, EPA Region 10 (descriptive report only) Talîb Syed, EPA Consultant (logs and descriptive report) Jim Regg, AOGCC (descriptive report only) Pro!. Bay Unit, EPA mc Permit: AK'OOS-A Grind & Inject Well Surveillance: Shut-In Temperature Logs Background EPA permit AK-1I008-A effective 09/01/07 requires a fluid movement test in Class I Grind & Inject wells each calendar year, Part II C 3 b (2). Approved fluid movement tests include tracer surveys, temperature logs, noise logs, oxygen activation/water flow logs, borax pulse neutron logs, or other logs. Tests (and fill depth tags) performed within one year prior to the effective date of the permit may be accepted as meeting the permit requirements. Shut-in temperature logs were run in the three Grind & Inject (GNI) wells in May, June and July 2007. The GNI wells normally inject cold slurry or cold water at 50-70 degrees F. The original formation temperature of the target disposal formation was about 115 deg F. The wells were shut-in for 12 to 23 days prior to running the logs. This technique is commonly used for cement channel detection in injection wells on the North Slope of Alaska. -_...._--~_.~- Wellbore temperatures are affected by the temperature of the injected fluids by either by conduction or by convection. When the well is injecting fluids, the wellbore and the formation adjacent to it reaches a temperature near the injection fluid temperature due to conductive heat transfer. When injection ceases, the wellbore temperature will begin to return toward its original temperature. The rate of temperature change of the shut-in well will depend on the original formation temperatures, the injection fluid temperature and the volume of injection. In the G&I wells, the injected fluids are colder than the formation temperatures below about 4000 to 4500 ft TVD. In areas where the injected fluids enter the formation, both conduction and convective heat transfer are involved. The amount of rock cooling is much larger and the rate of temperature change after shut-in will be much slower. Channeling adjacent to the well bore is evident because cooler injected fluids leak off into formations throughout the length of the channel. Several types of logging tools are available to be used to record the temperatures of the well bore fluids: surface reading tools run on electric line and memory tools run on slick line. The results from both instruments are presented in the enclosed log of borehole temperature and pressure versus measured depth. Shut-In Temperature Survev Procedure EPA permit AK-1I008-A requires tracer surveys to ",.. be conducted at injection pressure at least equal to the average continuous injection pressure observed in the previous 6 months." [njection is cycled into the GN[ wells on a rotating basis, with one well injecting at a time. Prior to the Class [ permit effective date, the average and maximum injection pressures were been reported to the AOGCC on form 10-406. A verage daily injection pressures in the three wells over the 6 months prior to the surveys were: GN[-Ol 1137 psi, GN[-02A 1406 psi, and GNI-03 1105 psi. Average wellhead pressures were equal to or in excess of these pressures for the injection cycle completed prior to the surveys. [n each well, the survey procedure involved the following steps: [nject a significant volume of water at the required pressure. Shut-in and freeze protect the well after an injection cycle. After at least 5 days, rig up logging tools, pressure test lubricator. Confirm depth control by comparing to the tie-in log on record. Run the shut-in temperature/pressure survey. Rig down and move off. Page I of 5 Pru!e Bay Unit, EPA VIC Permit: AK-Ios-A Grind & Inject Well Surveillance: Shut-In Temperature Logs GNI-Ol Shut-In Temperature Survey Results - reference GNI-Ol PDS Temp/Pressure Survey, 28-May-2007. Note: the depths referenced below refer to the printed log. The enclosed log trace was run from the fill level in the well to the surface. The log contains the following traces: gamma ray (API units), casing collar locator, Temperature and Pressure. The last injection cycle before logging took place between 04/29 and 05/05/07. The shut-in temperature trace indicates uniformly increasing temperatures with depth to at least 7350 feet measured depth (MD) or 6054 feet true vertical depth (TVD). Temperatures continue to increase with depth to about 7700' MD, 6296' TVD. Below that point, the temperature declined until the fill level is reached, near the top of the active perforations. Based on this data, there is no evidence of injected fluid movement above about 6050' TVD and it is unlikely there is any significant injected fluid movement near the wellbore above 6300' TVD. A plot of the temperature log data from 2005, 2006 and 2007 along with the original baseline temperature survey is included below. GNI-01 Temperature Logs 130¡- I I I 120 ! I ! ! I I 110 I I ~ I ~ 100 I ::J ; ë I 8. ! ~ 90! I- ! I ¡ 80 ! I ! ! ..... 70 I.· . . 1. . . . . ! · Perfs/Jewelry - 2/28/98 BL · 07/12/055 day 51 · 06/23/06 7 day 51 --.- OS/28/07 23day 51 60~-- 4000 4500 5000 5500 True Vertical Depth feet 6000 . . 6500 7000 Page 2 of 5 pro!e Bay Unit, EPA mc Permit: AK-tOS-A Grind & Inject Well Surveillance: Shut-In Temperature Logs GNI-02A Shut-In Temperature Survey Results - reference GNI-02 Schlumberger Static Bottom Hole Pressure survey, Press / Temp / GR / CCL, 14-Jul-2007. Note: the depths referenced below refer to the printed log. The enclosed log trace was run from the fill level in the well to the surface. The log contains the following traces: gamma ray (API units), casing collar locator, Temperature and Pressure. The last injection cycle before logging took place between 06/26 and 07/03/07. The shut-in temperature trace indicates uniformly increasing temperatures with depth to at least 7550 feet measured depth (MD) or 6143 feet true vertical depth (TVD). Temperatures continue to increase with depth to about 7875' MD, 6354' TVD. Below that point, the temperature declined until the fill level is reached, near the top of the active perforations. Based on this data, there is no evidence of injected fluid movement above about 6140' TVD and it is unlikely there is any significant injected fluid movement near the wellbore above 6350' TVD. A plot of the temperature log data from 2007 along with both the GNI-02A baseline~ and the original GNI-02 the baseline temperature survey is included below. GNI-02A Temperature Logs ." 1--- 120 I i 70 o°-o-q¡ ! 110 i I ! u. j ~ 100 i ::I I 16 i Q; i a. ì ~ 90 I ~ I I ! 80 I I i I . JewehyfPerts a 2 02-2B-9B BL -2A12-24-06 BL ~2A07-14-07 i 60 i 4000 --- 4500 5000 5500 True Vertical Depth It 6000 . 6500 7000 Page 3 of 5 Pru!e Bay Unit, EP A mc Permit: AK'OOS-A Grind & Inject Well Surveillance: Shut-In Temperature Logs GNI-03 Shut-In Temperature Survey Results - reference GNI-03 Schlumberger Pressure / Temperature Survey, 06-Jun-2007. Note: the depths referenced below refer to the printed log. The enclosed log trace was run from the fill level in the well to the surface. The log contains the following traces: gamma ray (API units), casing collar locator, Temperature and Pressure. The last injection cycle before logging took place between 05/16 and OS/25/07. The shut-in temperature trace indicates uniformly increasing temperatures with depth to at least 6750 feet measured depth (MD) or 6124 feet true vertical depth (TVD). Temperatures continue to increase with depth to about 7000' MD, 6332' TVD. Below that point, the temperature declined until the fill level is reached, near the top of the active perforations. Based on this data, there is no evidence of injected fluid movement above about 6125' TVD and it is unlikely there is any significant injected fluid movement near the wellbore above 6330' TVD. A plot of the temperature log data from 2005, 2006 and 2007 along with the original baseline temperature survey is included below =--________ ----.-"-.- GNI-03 Temperature Logs 130 80 -6/6/98 Baseline 120 · Perfs/Jewelry 110 · 06/22/05 5 day SI · 06/29/06 5 day SI ~ 100 :s 1¡j G¡ c. E ~ 90 ___ 06/06/07 12day SI 70 60 . 4000 . . 4500 5000 5500 True Vertical Depth feet 6000 6500 7000 Page 4 of 5 pru!oe Bay Unit, EPA VIC Permit: AK!008-A Grind & Inject Well Surveillance: Shut-In Temperature Logs Overall Conclusions 1. There is no indication of channeling up hole in any of the GNI wells above about 6050' TVD. This is significantly below the top of the injection zone at about 4500' TVD. 2. Most of the injected fluid was confined below about 6300' TVD. Michael L. Bill August 21, 2007 -_.~.~- .---..-----,..--- ---_._-_..._.~---._..._- Page 5 of 5 . . WELL LOG TRANSMITTAL " --- .... .---- -~~ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AI< 99518 Fax: (907) 245-8952 1 BL / EDE Disk GNI- 01 Temp / Press Survey 28-May-07 1) 2) 3) 4) 5) 6) 7) SCANNED JUN 2 0 2007 UI c:. ~Cìq -93~ -it /5"/93 Signed: (1. ¿t---- Date : ')'1 1\:\ '1 '1 1. 2. ;o·nn7 [Uu. ,-~: ',,) ~ Print Name: QiA (\~tÅ'¡:;> 0J\().(A'A (LpM ~¡ PROACTIVEDIAGNOS11CSERVICES, INc., 130W.INTERNATlONALAIRPORTRD SUITEC, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: l~DS.¿\~\j(~HOR...~.G::{G23REßr¡C!~..~..~...CG.:.;;jr:l WEBSITE: 'i'PPl'N.:W:wiOR'fLCG.COt!l D:lMaster _Copy _00 ]DSANC·2OxxIZ_ Word\DistributionlTransmiUaC SheetslTransmiUJriginal·doc -------------- BP Exploration (Alaska) Inc. GNI- 01 Prudhoe Bay North Slope Surface - Before RIH Static Temperature/Pressure Survey Elapsed Time Temperature Pressure (Minutes) (Deg. F) (psia) 0.0 50.24 61.58 0.5 50.75 226.61 1.0 50.76 262.63 1.5 50.57 278.57 2.0 50.31 288.38 2.5 49.98 295.02 3.0 49.63 299.65 3.5 49.27 302.99 4.0 48.91 305.47 4.5 48.56 307.38 5.0 48.22 308.87 5.5 47.87 310.05 6.0 47.54 311.02 6.5 47.22 311.81 7.0 46.91 312.48 7.5 46.61 313.04 8.0 46.33 313.53 8.5 46.05 313.95 9.0 45.77 314.31 9.5 45.51 314.63 10.0 45.26 314.91 AVERAGE 48.20 288.90 Date: May 28, 2007 Temperature Data 60 55 50 u. 45 ~ 40 Q 35 30 25 20 o 4 5 2 3 Minutes Pressure Data 350 300 250 <I: ëñ 200 0.. 150 100 50 o 2 3 456 Minutes Page 1 ~ - - -- Start time: 18:23:00 6 8 10 7 9 7 8 10 9 ------------------- BP Exploretion (Alaska) Inc. GNI- 01 Prudhoe Bay North Slope 5,948' TVDss MD =: Elapsed Time (Minutes) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 6.5 7.0 7.5 8.0 8.5 9.0 9.5 10.0 Static Temperature/Pressure Survey Date: May Start time: 23:13:00 Temperature (Deg. F) 93.71 93.16 93.02 93.02 93.04 93.03 93.00 93.00 92.99 92.99 93.00 92.99 93.00 93.00 93.00 93.00 93.00 92.99 93.00 93.00 93.00 93.04 Pressure (psia) 2883.93 Temperature Data 2864.04 2864.17 2864.25 2864.30 2864.35 2864.38 2864.41 2864.42 2864.44 2864.45 2864.47 2864.47 2864.49 2864.49 2864.50 2864.51 94 92 u. 90 d> Q) c 88 86 84 o 8 9 10 2 3 4 5 Minutes 6 7 Pressure Data 3150 2864.52 2864.53 2865.40 3100 3050 « ëñ 3000 0.. 2950 2900 2850 o 456 Minutes 8 9 10 2 3 7 Page 2 ------------------- BP Exploration (Alaska) Inc. GNI- 01 Prudhoe Bay North Slope TVDss MD =: 7,878' Static Temperature/Pressure Survey Elapsed Time Temperature Pressure (Minutes) (Deg. F) (psia) 0.0 86.02 3053.18 0.5 86.09 3053.13 1.0 86.09 3053.14 1.5 86.10 3053.18 2.0 86.10 3053.21 2.5 86.11 3053.24 3.0 86.11 3053.26 3.5 86.10 3053.29 4.0 86.10 3053.31 4.5 86.10 3053.33 5.0 86.11 3053.34 5.5 86.10 3053.36 6.0 86.10 3053.37 6.5 86.10 3053.38 7.0 86.10 3053.39 7.5 86.11 3053.39 8.0 86.10 3053.40 8.5 86.10 3053.40 9.0 86.10 3053.40 9.5 86.09 3053.40 10.0 86.09 3053.40 AVERAGE 86.10 3053.31 Date: May 28, 2007 Start time: 22:59:00 Temperature Data 94 92 u. 90 ~ Q 88 86 84 o 2 3 4 5 6 7 8 9 10 Minutes Pressure Data 3150 3100 3050 « ëñ 3000 0.. 2950 2900 2850 o 2 3 456 Minutes 7 8 9 10 Page 3 - -- --------------- BP Exploration (Aleskaj Inc. GNI- 01 Prudhoe Bay North Slape Surface· After POOH Elapsed Time (Minutes) 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 5.5 6.0 6.5 7.0 7.5 8.0 8.5 9.0 9.5 10.0 AVERAGE Temperature (Deg. F) 28.82 29.42 29.57 29.57 29.37 29.24 29.41 29.32 29.21 29.27 29.19 29.12 29.11 29.11 29.01 29.21 28.96 28.95 28.94 28.93 28.98 29.18 Inner Annulus Outer Annulus Pressure Static Temperature/Pressure Survey Date: May 2007 Start time: 0:30:00 Pressure (psia) 331.28 321.30 318.75 318.87 318.95 318.99 319.02 319.04 319.05 319.05 319.05 319.05 319.04 319.03 319.03 319.02 319.01 319.01 319.00 319.00 318.99 319.69 Temperature Data 50 55 50 u. 45 ~ 40 Q 35 30 25 20 o 2 3 4 5 6 7 8 9 10 Minutes Pressure Data 350 300 250 « ëñ 200 0.. 150 100 50 o 2 3 4 5 6 Minutes 7 8 9 10 Page 4 ------------------- BP Exploration (Alaska) Inc. GNI- 01 North Star North Slope Downhole Temp/Press Static Temperature/Pressure Survey Date: May 28, 2007 Start time: 18:23:00 End time: 0:13:00 Temperature Data 100 90 80 u. 70 d> 50 ! c 50 40 30 20 -50 0 50 100 150 200 250 300 350 Minutes Pressure Data 3500 3000 2500 <I: 2000 ëñ 0.. 1500 1000 500 0 -50 0 50 100 150 200 250 300 350 Minutes Page 5 Re: Correctiion: GNI-OI (pTD #1972380) Internal Waíver Cancellation... . . Subject: Re: Correctiion: GNI~Ol (PTD #1972380) Internal Waiver Cancellation - Nonnal Well From: James Regg <jimJegg@admin.state.ak:.us> Date: Thu, 10 May 200710:04:06 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak:.us> ~ . ".,'... _ . .<'M.... -__... .' ,. _'.. guess we'll see when we get the TIO plot. Mike Bill has not mentloned any in past discussions and there is none evident from annual GNI performance rpts. This might be a derating effort on BP's part. Jim Thomas Maunder wrote: 5Q,~NED JUN 2 5 Z007 Does it have communication? James Regg wrote, On 5/10/2007 9:36 AM: eroded tubing¡ significant wall loss from caliper surveys according to Mike Bill¡ they are planning to work over the well later this' S1t'mftlep,·,·,- _.' . Jim Thomas Maunder wrote: Jack, What is the issue with GNI-01? Could you provide a TIO plot for the 1 ays? Tlì ks Tom AOGCC Thank you - ntegrity Engineer wrote, On 5/9/2007 5:35 P . NSU, ADW All, This waiver limits. The was sent out with the in rrect operating pressure and 1000 psi on the OA. */Jack L. Winslow (for Andrea Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 *From: * NSU, *Sent: May 08, 2007 7:19 PM *To: * 'tom maunde admin.state.ak.us'¡ 'jim regg@admin.s te.ak.us'¡ 'bob fleckenstein@a in.state.ak.us'¡ NSU, ADW Well Operations pervisor; Rossberg, R Steve GPB, Wells Opt Eng¡ GPB, EOC Specialists¡ NSU, Management Coor . ator¡ NSU, Field Svcs Mgr (AES) *Cc: * NS , ADW WI Tech; Bill, Michael L (Natchiq)¡ (AES)¡ NSU ADW Well Integrity Engineer *Subject * GNI-01 (PTD #1972380) Internal Waiver Cancellation - Normal Well internal waiver was issued for lowered MAASP on well GNI-01 (PTD #1972380) on 08/25/05. The well passed an MITIA on 04/22/06 proving two comepentent barriers. Under the new WI System Policy set to take effect on June 1, 2007, well GNI-01 will be Operable, with pressure limits of 2000 psi on the IA and~ ~ o (',......\-t- ~ " ~ <:"0 rJ 6/25/2007 11 :24 AM lof2 Re: Correctiion: GNI-OI (PTD #1972380) Internal Waiver Cancellation... . . Subject: Re: Correctiion: GNI-01 (pTD #1972380) Internal Waiver Cancellation - Nonnal Well From: James Regg <jim _regg@admin.state.ak:.us> Date: Thu, 10 May 2007 09:40:46 -0800 To: Thomas Maunder <tom _ maunder@admin.state.ak:.us> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> AOGCC does not recognize annulus pressure limits for injectors unless we impose them through an admin approval. Any indication of communication (annulus pressures) must be reported to the Commission and permission sought to continue operating the well. Jim Regg AOGCC Thomas Maunder wrote: Jack, What is the issue with GNI-01? Could you provide a TIO plot for the last 90 days? Thanks in advance, Tom Maunder, PE AOGCC NSU, ADW Well Integrity Engineer wrote, On 5/9/2007 5:35 PM: All, This waiver cancellation was sent out with the incorrect operating pressure limits. The correct limits are 500 psi on the IA and 1000 psi on the OA. Thank you - */Jack L. Winslow (for Andrea Hughes)/* Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 SCANNED JUN 2 6 2007 *From: * NSU, ADW Well Integrity Engineer *Sent: * Tuesdpy, .May 08, 2007 7:19 PM *To: * 'tom maunder@admin.state.ak.us'¡ 'jim regg@admin.state.ak.us'¡ 'bob fleckenstein@admin.state.ak.us'¡ NSU, ADW Well Operations Supervisor¡ Rossberg, R Steven¡ GPB, Wells Opt Eng; GPB, EOC Specialists¡ NSU, Waste Management Coordinator¡ NSU, Field Svcs Mgr (AES) *Cc: * NSU, ADW WI Tech¡ Bill, Michael L (Natchiq)¡ GPB, Waste G&I Plant (AES)¡ NSU, ADW Well Integrity Engineer *Subject: * GNI-01 (PTD #1972380) Internal Waiver Cancellation - Normal Well All, An internal waiver was issued for lowered MAASP on well GNI-01 (PTD #1972380) on 08/25/05. The well passed an MITIA on 04/22/06 proving two comepentent barriers. Under the new WI System Policy set to take effect on June 1, 2007, well GNI-01 will be Operable, with pressure limits of 2000 psi on the IA and 1000 psi on the OA. The well is reclassified as a Normal well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you - */Jack L. Winslow (for Andrea Hughes)/* Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 , \:J~, ~r\"'~ ~ (tc t..a' 6/25/2007 11 :24 AM lof2 e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor -;--) I C:;ê1Cl DATE: Wednesday, April 26, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC G&I-01 PRUDHOE BA Y UNIT G&I-01 Src: Inspector 1)~ (\ l?r \0\\ Reviewed By: P.I. Suprv)'f?£. 5/3{OG Comm FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT G&I-01 API Well Number 50-029-22845-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060423083717 Permit Number: 197-238-0 Inspection Date: 4/22/2006 ReI Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I G&I-01 ¡Type Inj. ! D ! TVD ! 4201 I IA i 10 1510 ! 1450 I 1440 I ! P.T. 1972380 ITypeTest! SPT ! Test psi ! 1050.25 lOA r 300 520 ! 500 I 490 ! I i I Interval OTHER P/F P Tubing! 1090 ! 1090 i 1090 i 1090 ¡ I Notes Pretest pressures were observed and found stable. Test perfomed on 2 year cycle. Test pressure limited due to wall loss in tubing indicated by logs. '. ,(/, 1l1.N"'il:.:~) ;),,<:'n. ..''''3¡¡;';, n ~ .' OJ Wednesday, April 26, 2006 Page 1 of I ) ) '~J~VŒ (ill~ A.I,A.SHA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK/, GOVERNOR 333 W. JTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~.q1" dL?/IJ Mike Bill Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay G&I-Ol Sundry Number: 304-469 Dear Mr. Bill: 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~ Daniel T. Seamount, Jr. Commissioner DATED this~ day of December, 2004 Enc!. CCA' NkIEr" DE('\ (';. ~" 200.f ~" ß\L,,,j .' v u Z ,4 ~Â- ¡ 2./11 2.004 ) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION J~""::ìJ APPLICATION FOR SUNDRY APPROVAl) 20 AAC 25.280 NOV 20ü4 1. Type of Req uest: Abandon 0 Alter Casing D Change Approved Program 0 2. Operator Name: Suspend 0 RepairWell D Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate X] / rWaivéi~ StimulateD Time Extensi6H[]'; ,(': Re-enter Suspended Well 0 5. Permit to Drill Number: 197-2380 ./ ""'~t~ë~g BP Exploration (Alaska), Inc. Development D Exploratory D Length Stratigraphic D Service ŒJ // 9. Well Name and Number: , .QNI 01 - (1 f r - c.? ( 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe ()B,r'ool ' L{ I'lk£<:/I.£. J PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 8466 6812.3 MD TVD 6. API Number / 50-029-22845-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 49.20 KB 8. Property Designation: ADL-0028328 WGA- IdGI\- 11. Total Depth MD (ft): 8572 Casing Size Plugs (md): Junk (md): None None Burst Collapse Total Depth TVD (ft): 6944.4 Conductor 82 Production 8525 Surlace 4140 Perforation Depth MD (ft): 7870 - 7880 7995 - 8025 Packers and SSSV Type: 7" Baker SABL-3 Packer 20" 94# H-40 9-5/8" 47# L-80 13-3/8" 72# N-80 Perforation Depth TVD (ft): 6415.21 6422.3 6505.39 6527.4 top bottom top bottom 30 112 30.0 112.0 1530 28 8553 28.0 6929.5 6870 29 4169 29.0 3957.9 4930 Tubing Size: Tubing Grade: Tubing MD (ft): 7" 29 # L-80 25 520 4760 2670 4296 Packers and SSSV MD (ft): 4201 12. Attachments: Description Summary of Proposal ŒI Detailed Operations Program 0 BOP Sketch 0 13. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒI Date: 15. Well Status after proposed work: Oil D GasO WAG D GINJD PIU99~d .- Abandoned 0 WI ,ì j WDSPL ¡,J4A- , r. pared by Garry ~on 564-4657. Mike Bill 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. December 4, 2004 Contact Printed Name Signature Mike Bill ~ . ~../;;;Z- ~ Title Phone Petroleum Engineer 564-4692 11/30/04 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3ot(-f.{fø r Plug Integrity 0 BOP TestO Mechanciallntegrity Test D Location Clearance 0 Other: Approved by: BY ORDER OF THE COMMISSION Date: /21! ( f- RBDMs BFL DEC 0 I 2004 RBDMS BFL OFt ~ 7nn4 ORIGINAL Form 1 0-403 Revised 11/2004 SUBMIT IN DUPLICATE bp ".,. 0 .\1'.\11. ~ --,~ ~....- ~..- -:...-- #...~ .¡r." .i'.~'\- "~ ') ) Memorandum To: D. Cismosi/J. Smart G PB Well Ops Team Leaders Date: November 23, 2004 From: Mike Bill Disposal & Regulatory Compliance Engineer PBGNIWELL Tag TD, Re-Perf Est. Cost: $40,000 PECT: Subject: GNI-01 SL Drift & TaQ; Reperf 1. 2. S E Slickline drift/tag of well GNI-01. Re-perforate 20' of lower interval (7995-8015 ft MD). Request 4-1/2" gun, PowerJet 4505,5 SPF. Flush 1 well bore volume (435 bbl) with water. 3. P Capacity Sustainment: Disposal well GNI-1 was found to be plugged on 10/30/04 after a pump /" problem caused an injection interruption while injecting slurry. Fill was tagged at 7428' SLM on 11/07, 567' MD above the top of the lower, main injection perfs. Coil tubing fill cleanout operations (11/19-21) removed fill to below the perforations but failed to restore injectivity, although the well did have had brief periods of injection during the job. The perforations appear plugged with solids. The lower set of perfs (7995-8025' MD) takes all of the injection while the upper set of perforation~/ (7870-7880' MD) has never had any significant injection. The purpose of this work is to restore injection into the lower perforations at this time. Recent well work: CT FCO to 8040' CTM 11/19-21/04 J ustification/P riority /Ti m i ng: G&I cycles disposal injection between the three GNI wells - GNI-2 began injecting on 11/17. We request this work be done before December 10 to allow the well to resume its normal rotation. See attached procedure. For questions or comments please call Mike Bill at 564-4692(w) or 333-5395(h). cc: Well File Mike Bill Harry Engel Steve Rossberg ) GNI-01 Coiled Tubing Fill Clean Out November 23, 2004 Cost Code: PBGNIWELL ') Purpose: Restore Injectivity. Perforations: Tubing: Packer: Min 10: PBTD: Last Tag: Max. Deviation: Fluid in well: Fluid in IA: Tie in Log: Latest H2S value: Current status: Timing: 7870-7880', 7995-8025' MD (ref: Schlumberger Array Induction Imager 1/10/98) 7" Tail @ 4296' MD, 7" X 9 5/8" Baker SABL-3 @ 4201' MD (Drlg) (lD = 6.00") "R" Nipple @ 4271' MD (Drlg), ID=5.963" 8467' MD (Drlg 01/14/98) 8040' MD CTM 11/21/04, below bottom perforation 52Q @ 5581' MD; 44Q at perfs Water, freeze protected with 60/40 methanol water Nitrogen blanket, Diesel to 2000 ft, Seawater to packer Static Temperature/Jewelry Tie-in Log 2/28/98 None taken. Expected level = 0 ppm based on seawater slurry injection Active slurry injector. Target to complete by 12/10/04 to allow resumption of its normal rotation Grind & Inject Plant: Mark Pliska/Jim Luhrs, 659-8419 G&I Engineer: Mike Bill, 564-4692 (w), 333-5395 (w), billml@bp.com 1, Drift & Tag to fill level. (Note there still may be fill on the bottom of the pipe.) , 2. Establish 1000 psi overbalance. Reperforate interval 7995-8015' MD (20' MD) with PowerJet / 4505, 4-1/2" gun, 5 SPF. (Note: may require large lubricator) 3. Immediately flush well and verify injectivity by pumping one wellbore volume water at 5 bpm /" (435 bbl). Coordinate with G&I plant which may be able to switch water injection into the well. 4. Freeze protect well. ,", ('-}. ) CIW HAC TREE = WELLHEAD =. ...........~..................................,....................................... A CfUA.:rOR = ui<ä'"'1l.Biu;,"....,-",,,- 5£i:"a;' BF. 8..EV = 'm.m"omumm...mmn..... KOP = 2509' Max Angle;;-S2n@nss8ii Datum MD =-^- 7342' Datum ND = -S()ÕÔ'SS 113-318" CSG, 72#, N-80, D = 12.347" H 4169' r----JC Minimum ID = 5.963" @ 4271' HES R NIPPLE T'TBG, 29#, L-80, 0.0371 bpf,ID= 6.184" H 4296' PERF ORA TION SUMMA RY RB= LOG: SWS A IT ON 01/11/98 ANGLEA TTOP ÆRF: 49 @ 7870' t-bte: Refer to A'oduction DB for historical perf data SIZE SPF INTERV AL OpnlSqz DA TE 4-1/2" 5 7870 - 7880 0 03112/98 4-1/2" 5 7995 - 8025 0 03112/98 1 A3TD H 8467' I 9-518" CSG, 47#, L-80, ID = 8.681" H 8553' GNI-01/' ~ :J 8: :& I I ~ REV BY DATE REV BY COMIVENTS 08/31/02 DTMP REMOY E IBP 08l22KJ2 DA.TE 03112/98 01/10KJ1 02/23KJ1 08l14KJ1 09/21KJ1 08l10KJ2 COtvfv1ENlS ORlGINA.L COMPLEfON S 6-CS CONY ERTED TO CA NV AS S6-LG FINA.L RN'KAK CORRECllONS MBlKAK CORRECllONS PI-VKAK IBPWIFISHNG NECK ) SAFETY NOTES: IA Ct£M.INJ-LlNE. 1/4" 55 OPEN EtÐED CONTROL LINE STRAPPED OUTSIDE OF 7" TBG DOWN TO JT #56. ALSO KNOWN AS 04-61 IN PBAS. 4180' HES CEIVENTER I 4201' H9-5I8" X 7" BKR SA BL-3 PKR 1 4271' H7"HESRNIP,ID=5.96" I I 4296' H7" lUBING TAIL WLEG I 4304' HELM) IT LOGGED 02/28/98 I PRLDI-OE BAY LNIT WELL: GNI-O 1 PERMT f\b: 1972380 AR No: 500292284500 SEC26, T11N, R15E, 371624 FEL3467.84 FNL BP Exploration (Alas ka) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg. \<€.Ia 4(Z-3\OA-' P.I. Supervisor II FROM: Chuck Scheve DATE: Wednesday, April 21, 2004 SUBJECT: Mechanical IntegritY Tests BP EXPLORATION (ALASKA) INC G&I-OI PRUDHOE BAY UNIT G&I-OI Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I.Suprv~ 4/Z3/Dt Comm API Well Number: 50-029-22845-00-00 Insp No: mitCS040417135927 Inspection Date: 4/17/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: G&I-Ol Type Inj. N TVD 4201 IA 0 1590 1530 1520 P.T. 1972380 TypeTest SPT Test psi 1050.25 OA 60 470 470 470 Interval Other (describe in notes) PIF p Tubing 680 680 680 680 Notes: Pretest pressures found stable. Well on 2 year test cycle. Wednesday, Apri] 2], 2004 Page I of! Scblum~epgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# Log Description Date SBH TEMP & PRESSURE SURVEY TEMP & PRESS SURVEY LDL LDL LDL MEM PPROF & IPROF LOG MEM PPROF & IPROF LOG MEM PPROF & IPROF LOG INJECTION PROFILE 10559234 CH EDIT SCMT PDC) 10559234 SCMT 10/03/07 10/04/03 10/01/07 10/01/03 10/03/03 09/01/03 09/08/03 09/09/03 10/04/03 03/03/03 03/03/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~~\{'(\~ =", :!:=",...., -~" --= '"""",, H "1 l' "''' '!,.!!~ !! \!; r\c"'Vt:~ V C:U Ot"'" Q n '1,'!!\~ v I U &_'-'v" Alaska OH & Ga5 Gons~ C=ommissfort f~nchorage ;;;-'1' t '~\(¡¡¡:;~~ nep ß n 20f!~ '.lì~6'--ìNf; ~ik>c,,:' Id b ~ 'IJ Oc UJ Blueline NO. 2984 Company: 10/07/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints 1 1 1 1 1 1 1 1 1 CD 2 ~I~ ~- Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received ~~i )~O~~A(\ ( (' Memory Multi-Finger Caliper r; I, r¡!J-?:> ~ Log Results Summar~ uRIG!NAL GNI-01 Prudhoe Bay Alaska 50-029-22845-00 Surface 4,304 Ft. (MD) Well: Field: State: API No.: Top Log Intvl: Bot. Log I ntvl: Company: Log Date: Log No. : Run No.: Pipe Desc.: Pipe Use: BP Exploration (Alaska), Inc. July 18, 2000 4136 2 7" 26 lb. Buttress Prod. Tubing Inspection Type: Tree Erosion & Tubing Damage Inspection COMMENTS: This is the second log of this well to be made with the PDS Caliper. This log was run to monitor potential erosive damage in the well tree due to long term injection of fluids with high-solids content. The entire tubing string was also inspected for damages. No increase in the minor erosive damage recorded in the Flow Cross, Surface Safety Valve and Master Valve portions of the tree in the last log is indicated in this log. A slight increase in corrosive damage is indicated in the tubing, with maximum recorded wall penetrations increasing from 2% to 13% during the time between logs. The damage recorded in this log appears mostly in the form of shallow lines of corrosion. A detailed Tree Inspection Summary, with 3-D and Image Mapping is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (>13%) recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No areas of significant cross-sectional wall-loss (in excess of 10%) were recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: Minimum 10 of 6.07" recorded in R-Nipple @ 4280 Ft. No deposits or abnormal tubing restrictions recorded throughout the interval logged. MICROFll ED Date l/Y61 -/ RECEIVED .JUL2 62000 Alaska Oil & Gas Cons. Commission Anchorage I Field Engineer: R. Liddelow Analyst: R. Richey Witness: L. Wade ProActive Diagnostic Services, Inc. / P.O. Box 1369/ Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659.-2307 Fax: (907) 659-2314 Comments: Tree Cap Swab Valve Cross Flow Surface Safety Valve Master Valve Hanger Assy. p 5 EE SP 5 BP Inc. Well Number: Tree Size & GNI-01 7" Camron 18,2000 Minor erosion recorded from the lower of the Flow Cross to the bottom of the Master Valve. 0 2 3 4 5 6 1 8 9 10 11 12 1 OS aliper Overvi Body Regio Analysis Well: Field: Company: Country: GNI-01 Prudhoe Bay BP Exploration (Alaska), Inc. USA Survey Date: Tool Type: Tool Size: No. of Fingers: Anal sed: July 18, 2000 MFC40 No.00432 23/4" 40 R.A. Riche Penetration and Meta! loss (% wal!) Damage Profile (% wall) penetration body metal loss body penetration body 0 1 metal loss body 50 100 120 100 80 60 40 20 0 0 to 1% 20 to 40% 40 to 85% above 85% 51 0 0 Damage Configuration ( body) 50 0 40 30 20 10 100 isolated pitting gen era! corrosion line corrosion ring corrosion hole / pass ible hole total = 44) 0 0 Bottom of Survey = 101.5 Analysis Overview page 2 JOINT TABULATION S Pipe: 7 ins 26 ppf L-80 BTRS Wall thickness. Body: 0.362ins Upset = 0.362ins NominallD: 6.276 ins Well: Field: Company: Country: Date: GNI-Ol Prudhoe Bay BP Exploration (Alaska), Inc. USA July 18, 2000 penetration body metal loss bodv Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (%wall) inches inches I % % inches inches inches 50 10 1 0 .03 8 4 0 0 6.28 Line shallow corrosion. 2 0 .04 10 4 0 .03 6.30 Line shallow corrosion. 3 0 .05 13 5 0 0 6.26 Shallow corrosion. 4 0 .03 9 3 0 0 6.28 Line shallow corrosion. 5 0 .05 12 4 0 0 6.29 Line corrosion. 6 0 .02 6 3 0 0 6.25 Shallow corrosion. 7 0 .04 12 5 0 0 6.28 Shallow corrosion. 8 0 .04 10 5 0 0 6.22 Line shallow corrosion. 9 0 .03 7 5 0 0 6.29 Line shallow corrosion. 10 0 .02 6 5 0 0 6.30 11 0 .01 I 4 4 0 0 6.29 I 12 0 .04 10 3 0 0 6.29 Line shallow corrosion. 13 0 .03 8 5 0 0 6.25 Line shallow corrosion. p 14 0 .04 10 5 0 0 6.26 Line shallow corrosion. 111 15 0 .03 9 3 0 0 6.29 Line shallow corrosion. 111 16 0 .04 12 3 0 0 6.31 Line shallow corrosion. Jill 17 0 .04 10 3 0 0 6.28 Line shallow corrosion. 18 0 .04 12 5 0 0 6.27 Line shallow corrosion. 19 0 .04 12 5 0 0 6.28 Line shallow corrosion. 20 0 .03 9 4 0 .03 6.28 Line shallow corrosion. 21 0 .04 10 5 0 0 6.30 Line shallow corrosion. 22 0 .04 12 4 0 0 6.24 Line shallow corrosion. 23 0 .03 9 3 0 0 6.21 Line shallow corrosion. 24 0 .04 12 6 0 0 6.28 Line shallow corrosion. 25 0 .03 8 4 0 0 6.24 Line shallow corrosion. 26 0 .02 7 4 0 0 6.28 27 0 .04 12 5 0 0 6.29 Line shallow corrosion. 28 0 .04 10 4 0 0 6.28 Line shallow corrosion. 29 0 .04 12 3 0 0 6.26 Line shallow corrosion. 30 0 .01 4 4 0 0 6.27 31 0 .04 12 4 0 0 6.28 Line shallow corrosion. 32 0 .04 10 4 0 0 6.26 Line shallow corrosion. 33 0 .02 7 6 0 0 6.29 34 0 .01 3 3 0 0 6.23 ')~ 0 .01 3 3 0 0 6.26 JJ 36 0 .04 10 6 0 0 6.26 Line shallow corrosion. 37 0 .02 5 5 0 0 6.29 38 0 .04 12 4 0 0 6.28 Line shallow corrosion. 39 0 .01 4 3 0 0 6.29 40 0 .01 3 2 0 0 6.27 41 0 .01 4 4 0 0 6.27 42 0 .03 9 3 0 0 6.28 Line shallow corrosion. 43 0 .02 7 2 0 0 6.26 44 0 .02 6 4 0 0 6.?7 45 0 .02 4 3 0 0 6.24 46 0 .05 13 3 0 0 6.22 Line shallow corrosion. 47 0 .01 3 3 0 0 6.26 48 0 .01 3 1 0 0 6.23 49 0 .01 3 5 0 0 6.27 Ii! 50 0 .01 4 3 0 0 6.28 0 Pipe Tabulations page 1 PDS CA ER JOINT TABULATION SH r Pipe: 7 ins 26 ppf L-80 BTRS Wall thickness. Body: 0.362ins Upset = 0.362ins NominallD: 6.276 ins Well: Field: Company: Country: Date: GNI-OI Prudhoe Bay BP Exploration (Alaska), Inc. USA July 18, 2000 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset Body ID Comments (%wall) , inches inches I % % inches inches inches ) 50 10 51 0 .01 3 2 0 0 6.28 52 0 .01 3 2 0 0 6.23 53 0 .03 9 2 0 0 6.22 Line shallow corrosion. 54 0 .03 9 2 0 0 6.26 Line shallow corrosion. 55 0 .01 3 4 0 0 6.28 :J6 0 .01 3 2 0 0 6.26 57 0 .01 3 2 0 0 6.26 58 0 .02 6 4 0 0 6.26 59 0 .01 3 2 0 0 6.26 60 0 .04 12 2 0 0 6.28 Line shallow corrosion. 61 0 .02 6 3 0 0 6.27 6) 0 .01 3 2 0 0 6.)5 63 0 .04 11 3 0 0 6.26 Line shallow corrosion. 64 0 .01 3 2 0 0 6.25 65 0 .01 4 2 0 0 6.23 66 0 .01 3 ) 0 0 6.25 67 0 .01 3 2 0 0 6.2&= 68 0 .02 5 3 0 0 6.2 69 0 .0) 5 1 0 0 6.22 70 0 .01 3 2 0 0 6.27 71 0 .01 3 2 0 0 6.24 72 0 .01 4 1 0 0 6.26 73 0 .02 6 4 0 0 6.27 74 0 .02 6 2 0 0 6.26 II 75 0 .02 6 1 I 0 0 6.25 !I 76 0 .02 5 2 0 0 6.26 77 0 .02 6 2 0 0 6.25 78 0 .02 6 2 0 0 6.21 79 0 .02 6 2 0 0 6.26 80 0 .02 5 2 0 0 6.27 81 0 .02 5 2 0 0 6.25 82 0 .02 6 2 0 0 6.22 83 0 .01 4 2 0 0 6.25 84 0 .01 3 3 0 0 6.27 Line shallow corrosion. 85 0 .01 4 2 0 0 6.20 86 I 0 .0) 5 2 0 0 6.24 87 0 .02 51 2 0 0 6.24 88 0 .02 6 2 0 0 6.23 89 0 .02 5 3 0 0 6.25 90 0 .02 6 3 0 0 6.26 Line shallow corrosion. 91 0 .04 11 3 0 0 6.25 Line shallow corrosion. 92 0 .02 6 3 0 0 6.26 0 .04 10 2 0 0 6.21 Line shallow corrosion. 0 .021 6 2 0 0 6.25 0 .ü31 8 2 0 0 6.26 Line shallow corrosion. 96 0 .02 6 2 0 0 6.26 97 0 .02 6 2 0 0 6.25 98 0 .02 5 2 0 0 6.21 99 0 .02 6 ) 0 0 6.21 100 0 .05 13 2 0 0 6.25 Line shallow corrosion. 0 Pipe Tabulations page 2 PDS CA ER JOINT TABULATION S Pipe: 7 ins 26 ppf L-80 BTRS Wall thickness. Body: 0.362ins Upset = 0.362ins NominallD: 6.276 ins Well: Field: Company: Country: Date: GNI-Ol Prudhoe Bay BP Exploration (Alaska), Inc. USA July 18, 2000 penetration body metal loss bodv Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset BOdy ID Comments (%wall) inches inches % % inches inches inches p 50 10 100.1 0 .03 9 2 .03 0 6.26 PUP Line shallow corrosion. P 100.2 0 0 0 0 0 0 6.24 PACKER 100.3 0 .03 7 3 0 0 6.24 PUP Line shallow corrosion. P 101 0 .02 6 2 0 0 6.25 Î 101.1 0 .02 6 1 0 0 6.25 PUP ~ 10 1.2 0 0 0 0 0 0 6.27 R-NIPPLE 101.3 0 .02 6 1 0 0 6.27 PUP 111 101.4 0 .04 11 2 0 .10 6.24 PUP pr I 101.5 0 0 0 0 0 0 6.22 WLEG 0 Damage Classifications Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 75% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 5 * pipe ID, but extends less than 20% of circumference General - damage depth range exceeds 1 * pipe ID and/or extends more than 20% of circumference Isolated - damage depth range does not exceed 5 * pipe ID or extend more than 20% of circumference Damage reporting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length = 0.500 feet. Pipe Tabulations page 3 PDS(~ALIPER JOINT TALLY SHEET (" Pipe: 7 ins 26 ppf L-80 BTRS Wall thickness. Body: 0.362ins Upset = 0.362ins NominallD: 6.276 ins Joint Depth Length Measured Type No. ID feet feet inches 1 28.53 42.98 6.293 2 71.51 41.73 6.299 3 113.24 42.02 6.305 4 155.26 42.04 6.302 5 197.30 41.88 6.309 6 239.18 41.80 6.298 7 280.98 42.19 6.295 8 323.17 42.07 6.301 9 365.24 40.85 6.306 10 406.09 42.14 6.306 11 448.23 41.43 6.309 12 489.66 41.93 6.31 5 13 531.59 42.20 6.303 14 573.79 41.08 6.31 5 15 614.87 40.61 6.314 16 655.48 41.90 6.303 17 697.38 41.56 6.304 18 738.94 40.89 6.31 7 19 779.83 42.11 6.31 3 20 821. 94 42.05 6.305 21 863.99 42.11 6.309 22 906.1 0 41.62 6.305 23 947.72 40.93 6.303 24 988.65 42.03 6.311 25 1030.68 41.95 6.309 26 1072.63 41.78 6.318 27 111 4.41 42.07 6.31 5 28 11 56.48 42.42 6.31 5 29 1198.90 40.73 6.31 7 30 1239.63 41.98 6.311 31 1281.61 42.02 6.319 32 1323.63 40.13 6.31 3 33 1363.76 41.97 6.309 34 1405.73 41.99 6.31 3 35 1447.72 40.10 6.313 36 1487.82 42.22 6.305 37 1530.04 40.07 6.31 5 38 1 570.11 41.30 6.31 7 39 1611.41 42.08 6.323 40 1653.49 41.87 6.31 5 41 1695.36 40.58 6.314 42 1735.94 39.28 6.312 43 1775.22 39.89 6.31 7 44 1815.11 42.08 6.321 45 1857.19 41.29 6.31 5 46 1898.48 42.02 6.307 47 1940.50 42.31 6.314 48 1982.81 41.50 6.320 49 2024.31 41.71 6.302 50 2066.02 41.88 6.310 Well: Field: Company: Country: Date: GNI-Ol Prudhoe Bay BP Exploration (Alaska), Inc. USA July 18, 2000 Joint Depth Length Measured Type No. ID feet feet inches 51 2107.90 41.96 6.31 5 52 2149.86 42.13 6.307 53 2191.99 41.59 6.307 54 2233.58 42.21 6.320 55 2275.79 41.93 6.310 56 2317.72 42.21 6.31 2 57 2359.93 42.01 6.314 58 2401.94 40.33 6.304 59 2442.27 42.11 6.31 7 60 2484.38 42.02 6.322 61 2526.40 40.03 6.308 62 2566.43 42.18 6.307 63 2608.61 41.94 6.304 64 2650.55 42.12 6.307 65 2692.67 42.07 6.301 66 2734.74 40.66 6.307 67 2775.40 42.08 6.31 7 68 2817.48 42.38 6.322 69 2859.86 41.12 6.309 70 2900.98 42.13 6.31 2 71 2943.11 41.06 6.307 72 2984.1 7 42.29 6.31 3 73 3026.46 42.13 6.305 74 3068.59 42.06 6.308 75 3110.65 42.27 6.310 76 3152.92 42.08 6.310 77 3195.00 42.05 6.299 78 3237.05 42.07 6.301 79 3279.12 41.85 6.298 80 3320.97 40.43 6.31 3 81 3361.40 42.08 6.311 82 3403.48 42.26 6.304 83 3445.74 41.94 6.300 84 3487.68 42.01 6.306 85 3529.69 41.72 6.300 86 3571.41 41.62 6.308 87 3613.03 41.99 6.304 88 3655.02 41.60 6.307 89 3696.62 42.12 6.299 90 3738.74 42.08 6.310 91 3780.82 39.68 6.301 92 3820.50 42.00 6.298 93 3862.50 42.07 6.299 94 3904.57 41.94 6.297 95 3946.51 41.94 6.310 96 3988.45 42.06 6.307 97 4030.51 40.90 6.303 98 4071.41 41.81 6.305 99 4113.22 41.50 6.300 100 4154.72 41.93 6.298 loint Tallv page 1 RECEIVED JUL 26 2000 Alaska Oil & Gas Cons. Commission Anchorage PDS (~ALIPER JOINT TALLY SHEET (' Pipe: 7 ins 26 ppf L-80 BTRS Wall thickness. Body: 0.362ins Upset = 0.362ins NominallD: 6.276 ins Well: Field: Company: Country: Date: GNI-Ol Prudhoe Bay BP Exploration (Alaska), Inc. USA July 18, 2000 Joint Depth Len gth Measured Type No. ID feet feet inches 100.1 4196.65 10.44 6.3 04 PuP 100.2 4207.09 9.07 nominal Pkr 100.3 4216.16 9.66 6.292 PuP 101 4225.82 42.08 6.298 101.1 4267.90 9.56 6.299 PuP 101.2 4277.46 5.92 nominal R-nio 101.3 4283.38 10.26 6.31 7 PuP 101.4 4293.64 10.36 6.293 Puo 101.5 4304.00 unknown 6.293 WLeg Joint Depth Length Measured Type No. ID feet feet inches Joint Tally page 2 RECE\V£D JUL Z 6 2000 Alaska on & Gas Cons. Gomm\ss\QO Anchorage PROAClr.E DI~ S£Al/leu, INC. S''l' ~~~ PDS Memory Multifinger Caliper Log Results Summary ( ~ .. Q. Company: Log Date: Log No. : Run No.: Pipe Oesc.: Pipe Use: ARca Alaska, Inc. July 24, 1999 1005 1 7" 26# Buttress Tubing Well: GNI-01 Field: Prudhoe Bay State: Alaska Top Log Intvl: Surface Bot. Log Intvl: 4303 Ft. (ELMO) Inspection Type: Tree Erosion & Tubing Damage Inspection COMMENTS: This log was run to locate and identify potential erosive damage in the well tree due to long term injection of fluids with high-solids content. The entire tubing string was also inspected for damages. Minor erosive damage is recorded in the Flow Cross, Surface Safety Valve and Master Valve portions of the tree, with the worst damage indicated in the lower body of the Flow Cross. At this location, the average diameter shows to increase 0.11 n, with a maximum wall penetration at any one point equal to 0.10". A cross-sectional drawing of this area is included in the report. The Safety Valve and Master Valve show wall loss ranging from 0.03" to 0.05" throughout the body areas, with no damage to the gates. A detailed Tree Inspection Summary, with 3-D and Image Mapping is included in this report. No significant damage of any type was recorded throughout the tubing string. RECEIVED t II ç, 0 4 1999 Maximum Recorded Wall Penetrations: Alaska Oil & Gas Cons. Commission . ... . Anchorage No slgmflcant wall penetrations (>2%) recorded throughout the Interval surveyed. Maximum Cross-Sectional Wall Reductions: No significant cross-sectional wall loss (>2%) recorded throughout the interval surveyed. Maximum Recorded ID Restrictions: Minimum 10 of 5.88" recorded in R - Nipple @ 4280 Ft. No deposits or abnormal tubing restrictions recorded throughout the interval surveyed. I PDS Engineer: Joey Burton Witness.: Cory Morgan ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Ty¡ Inspection Sum Date: Comments: ARCO Alaska, Inc. July 24,1999 Well Number: Tree Size & GNI-01 T' Camron Minor erosion recorded from the lower body of the Flow Cross (4.2') to the bottom of the Master Valve (9.55'). . 0 2.0 ------------------~-,-- 3.0 ------_._..__.._-_.__.~~-- 4. (\ '" u 5.0 6.0 7.0 8.0 9.0 PRUDHOE BAY ARCO ALASKA, INC. USA 7 ins 31 f N-80 Buttress Tubin : Erosion in Tool ::: 32 Mean 6.493 Reference ID ::: 6.375 Reference OD ::: 7 Wall area ::: N/A % JULY 24, 1999 PDS 23/4 In. 40 J. Burton Body of Tree Flow Cross @ 4.54 Ft. Below Tree Cap. Joint 0 at 4.535 ft Finger 11 Radius::: 3.289 ins Erosion in Lower Cross-Sections page 4 of Flow Cross @ 4.54 Ft. below Tree Ii r Damage body body metal body 100 I I I I I I I I ì I I I I I I I I I I I I I I I I I I i I I I I I I I I I i I I I i I I I I I I I I I I I I I I I V, I I I I I I I I I i I I I I I I I I I I I I I I I I I I ! I I I I I I i I I I I I ! 1 I I I I I I I I i I I I I I I I I I I ì I i I I I I I I 'illlii I IIII l I LLLLJ Survey = 4 Analysis Overview 2 Memory 50 i -T--: I Tl above 85% I I II I I I Ii I I I I I III II i I II I I I I II I¡III III ! I I I I I I ¡III I II I I I ¡ I I I I I 1IIIIIII ¡ II III¡IIII I I 1I1I II I I I I I I I I I II I 10011 I I I I I I I I WlllJlUJ Analysis Overview 3 Well GNI-01 body USA body 24, Joint II I Metal v profile No. Makeup '~'f~"h wall) - inches inc~~~l % % 50 10C 0.11 0000 0.011 I 3 61 PuP Jt. II n-T n 1.01 0000 0.018 ¡ 4 4 list Full Length Jt. 2.0, 0.000 ' 0.012 1 3 2 I III I I 3C 0.000 0.018' 4 1 1 1 I I I 1 I 4.0 0012 3 2 0000 J II 5.0 0012 3 2 0000 J 1 I 6.C ,0016 4 1 0000 I JO I ¡ I I ¡ , 70 0.010 2 0000 0 6.134 I -- I . II , 8.0 0.014 1 0.000 JO 1 9.0 0.000 0019 0000 I 0 !II! I I I 10.0 10.012 0000 No Damane i [I II II 4 2 O.OU) 1 I I '.0 0.018 4, 2 0.000 .C] I I '.0 0018 4 1 'i-~I (] ¡ I. 0.000 0.018 4 31 6.1 I 0 0.016 4 ~ 1 0000 0.000 6.1 n"mam> 1 .0 0.018 4 6.1 0 0.010 2 2 0.000 0.000 1 I . 1 I I ,( \ 0.012 I 3 'Bt~ JOI \ I 24.0 O. ) I C 4 31 2 ¡ 0.. 2 -------- ¡ I 25.0 O. J .C 10 21 1 0000 ' I II I 260 0 J .C 15 4 2 0.000 I I I I 27.0 O. J .C iO 21 3 0000 0000 I I I I 28.0 0000 017 4 1 (J 000 0.000 i I 1 29.0 0.000 018 4 2 0.000 0.000 6. 6 I ' I 300 0000 0019 5 'I 0000 0000 11 No e (I II I 310 0.000 0.011 I 3 3 i 0.000 0000 14 1 ! I 1 320 (J 000 0012 3 1 001 1 orm :095 33.0 0.000 0.010 2, 2 OC] J 0.000 .108 340 0000 0016 4 1 001 1 0000 :090 35.0 0.000 0.017 4 2, 0.01 J 0.000 6.119 360 0000 0018 4 2 0000 0000 6118 I 37.0 0.000 0.013 3 3 O. XJ 0.000 6.108 380 0000 0018 4 2 0 XJ 0000 6120 I 39.0 0.000 0014 3 1 0 10 0000 R 120 i i LIDO OOCO 0010 1 0 10 0000 6088 No I ! 41.0 0.000 0.012 3 1 0000 0000 Rml I I 1 42 0 0000 0014 '4 1 0000 I I ¡ i 43.0 0.000 0.018 4 1 0000 0.000 6086 I I 44.0 0000 0.016 4 2 0 000 (J noo 6126 45.0 0000 0.018 4 2, 0.000 . æ _..6084 I I 46 0 0000 0010 ") 2 0000 61rD 47.0' 0.000 0.010 ") 1 0000 6.107 I 450 0 no] 0.018 4 1 0000 nooo 6114 ¡ I 49.0 0.000 0.014 :'I 1 0000 0000 6.088 I 500 0000 0018, 4 2 0000 0000 6112 No n;:;m;:;tiP I I! I I ¡=;10 0.000 0.018 4 1 nm1e R 1?2 I I 520 0000 . 0.014 3 1 0000 R 118 II "'30 0000 0.012 :'I 2 0000 R 114 I I 540 0.000 0.014 3 1 0000 0000 6120 I ¡ . ¡:;:;r,0 onrn I n01F< 4 1 ~R114 I I I I 580 0000 10018' 4 2 0 8119 ~ JJ ")70. nom I on1¡=; I 4 2 0000 I 0.000 R 1?,,) ~ Pipe Joint ,- 1 ,e" OUVII I Metal ''''''''' AM No 'i~ches in;~~\ % % 58.( -Cf5ijJ 0.01 3 1 59.0 0.000 0.01 3 2 60.0 0.000 i 0.011 I 4 2 61.0 0.000 0016 1 4 4 6'2.0 J 0.013 I 3 630 J 0.018 1 ? 1 640 I 0.012 ! 3 0.014 1 4 ! 41 2 I 4 4 J 1 4 1 0.000 I I 3 1 I 0.013 3 2 0012 3 2 J i 0.018 4, 2 J ! 0.017 4 4 i 0 0000 1 0.012 :: 2 1 0.000 o~ms (JeO 0.013" )[J 0 0CiII (JeO 0.016 4 )() ODOO (JeO ('014 00Cill (JeO Ci.012 ODOO 0.000 0019 ' 0 0CiII 0.000 0.018 0:000 0000 0018 41 C)[J 00Cill 0.000 0.014 3 ()() 0.000 53. .000 0018 4 2 r m 0.000 34 .000 0.010 2 3 ( 00 ODOO 350()[J 0018 4 2.lJ000 36. .000 0.018 4 2 0 0000 870 00Cill 0011 3 4 0 00Cill 88.0 0.000 0.016 4 2 0000 I n 0CiII 890 0.000 0010 2 ? 0 0CiII 0.000 _SJCLQ OQ;XL. 0.018 4 ? 0000 0000 91 .0 ocm 0011 3 ? 0 0CiII 0.000 92.0 orm 0018 4 3 0000 onon ì~ 0000 n01? 2 Of1fJO OOCill ~,Olm 0.018 3 0000 0000 95 0 0000 0.019 ' ? 0 0CiII 0 ffi'J 96.0 0.000 0.018 2 nOCill nnon 97.0 0000 0018 4 ? 0 0CiII 0 0CiII 98.0 0000 n 01 S 4 ? n 0CiII n 0CiII 990 0000 0016 4 :'I 100Cill 00Cill i 100.0 0.000 '~o%t 3 3 nîm nnnn !1OO1 0000 :'I 1 OOCill == i 100.2 onnn nnlO ? ? anon 11003 OŒX) 0014 1 3~ i101.o~ nnnn i 101 1 0000 41 -? 0000 0 0CiII 1101.2 0.000 0.014 31 3 1 nnnn nnnn 11013 0000 0018 I 41 1 0 0CiII . 0 0CiII ! 101.4 0 0CiII nOD I :<.1 :<. 0 nnn I n nnn I inches O.orJO QoOö 0.000 I 0.000 0.000 f- Well: Date: - inches 6094 I 6.138 [ I No Siqnificant Damaqe I 1 1 6.140 6086 . ~¡~ 6.134 R 1:'3fi R1:::\4 fi 1:'36 ( ( f ( R14 R14 -6150 fi m? R 118 R 1?1 R 11? fi 140 R 14R "-In fi 11 fi R 1?8 R 1:::\? 6~~_- 6.141 I R 14" R D8 RrnR fi11? R 111 Ri4B Pun .11 S CO? . P",..i<",r -R1?O Pun .11 R (JQ(1 -R11:~ SM4 ~. R 144 Nn Damaae ! Damaae Pun .J! R-"-llnnle Pun.11 Plln .It ~ WLEG Pipe page 2 GNI-01 I Dar~~~~g 1( ._- -- -- ¡~ Nominal I D: 6.184 ins Joint ,,~,,~""" I Metal .~a~eup BO~ì % % '.C 1 0 1 2 0 2 i 0 0 2 C 1 1 1 0 2 1 1 0 0 2 1 0 2 i.C 0, ,{ 0 '.C 1 0000 0 2 0 1 0 2 0 2 X 2 C I 1.( X 0 r If )( 2 ( J i.( X :/ 10000 0000 1 0.000 0.000 2 0000 0000 2 0.000 0000 2 0000 0000 2 0.000 0.000 1 0.000 0000 2 0000 0000 1 D 000 D 000 0 0000 D D DDD 0 000 6. 1 4.1 2 0000 0.000 6.128 0 lorm 0.000 6œñ 1 0000 0.000 6.112 1 0 0(10 0 000 R 111 NI1 1 0.000 0000 6.146 Pun JI. 0 D 000 0 000 Pi q?? P"cker 0 0000 0.000 6.120 Pun JI. 1 DOOO 0000 Rrm 2 0.000 0000 6.115 Pun ,II. 0 0000 0.000 1 Pi RR4 n ",. 1 0.000 I 0000 1 6.14.'5 Pun JI. 0 om'!! 00001 R144 PuoJtRWIFG For! 01 0.006 I I 0.000 0.000 I .DC 0.000 0.003. 0 0000 0.002 0 0 73.0 J 74.0 J 75.0' 70 -, 0, 0 C 1 1 1 0.002 I 0, IC 0 0.000 \ iC C 0000 0 820 0000 1 83.0 0000 01 84.0 0000 0000 0 850 0000 0000 0 86.0 0.000' 0000 0 i 81.0 0000; 0.001 0' 88.0 0000 0.006 1 89.0 0000 oa::ri 0 900 0000 i 0000, 0 _~~Io ~.~~- 0 I 93.0 0.000 0.002 0 940 0000 0000 0 950 0.000 0.009 ") I 96D D 000 0000 D 970 0000 i 0000 0 98 0 0.000 I OOOS 1 99.0 0.000 1 0.006 1 '100.0 om"] om::J 1 100.1 0.000 0.002 I 01 1m2 0000 0 roo 0 100.3 0.000 0.004 1 i 101 0 orJOO 0001 0 i 1011 0.000 0000 0 ! 101 2 0000 0004 1 101.3 0.000 0.000 0 ¡ 1014 0000 0002 0 inches ii 0.000 10.000 I 0' J( 0.000 I 0. 0.000 I I IC iC 0.000 '.C 6.1 6.1: 6.140 6.1 Damaqe 6.086 ! Damaqe 6 14 6 IR 6 6 6.134 6.138 6. 6. 6 6.Œ 6118 . 6.121 R 112 6.140 ñ 1 46 No 6.116 6128 6.132 6140 n"m"l'Ip GNI-01 body loss body Damage 0 w~~ IC ------- 12 JELL LOG TRANSMITTAL ( ProActive Diagnostic Services, Inc. To: ARCO Alaska, Inc. AOGCC Lori Taylor RE: Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Carl Jablonski/Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 I LOG DIGITAL MYLAR / BLUE LINE --1 IT. .L WELL DATE TYPE DATA SEPIA PRINT(S) REPORT I FILM ! Open Hole I i Res. Eva I. CH I I Mech. CH ! C\1- d::ß I I GNI-O 1 July 24, Caliper Survey I '1~~ r- /~ &"'""'~, I I / ~--. ~~~\ 1999 ~""'-~ '--1 .'- ~ "'~~ ':' ~ :. -. ,1 ',\...'~ ~" ,C}J , ",," '..... I r ," 1"1 - 99Q \.) - 1 I ~"¡ ¡j ,+!' " ~ L '\A~L& Signed. Print Name: Date. !\!aSKa Qi! &. Gas Cons. Commission Anchora,ge ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-mail: pdsprudhoe@NA800.net Website: www.memorylog.com C: \My Documents\Excel- Word - Documents\Distribution - Fonns\Arco -pb - fonn.doc ~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Well Job # Log Description -- q,P ;X?>8 GNI #1 -G t"J . ?S"S- GNI #2 - '1 '1. , ð', GNI #3 g:¡. oCt (p D.S. 2-25 g ~. \ ~3 D.S. 3-22 - ~ ~ . oG (p D.S. 3-24A 84 . cOs 2. D.S. 3-31 <10. )~~ D.S. 9-44 g . (:).8 D.S. 11-2 - c¡ CD ' 151 D.S. 11-05A ðl'/lsÞ/ D.S.11-6 c.¡ 3 . ;).0 cj D.S. 11-24A -i~ . °'° D.S. 12-33 ~ ~ . I ~ '3 D.S. 14-36 Of'1. 0 .S. 17-19A --.. ~ D.S. 17-19A ~ urG TEMPERATURE LOG WIPRESSURE TEMPERATUR8PRESSURELOG PRESSURE TEMPERATURE LOG PRODUCTION PROFILE LOG PRODUCTION LOG GRlCCL LOG STATIC PRESSURE SURVEY PRODUCTION PROFILE LOG INJECTION PROFILE LOG PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION LOG & GAS LIFT SURVEY INJECTION PROFILE INJECTION PROFILE LOG STATIC PRESSURE SURVEY PRESSURE & TEMPERATURE SURVEY SIGNED&¥____------------- Date 980606 980512 980606 980511 980531 980529 980514 980511 980513 980527 980522 980531 980528 980604 980514 980601 7/1/98 NO. 11312 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay BL RF Sepia . Floppy Disk LIS Tape 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Rfi+t Jut! ' DATE: l,h~LhL~ (;'~~ L Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. ~;:J ~;:.~. Cr t-¡~ ? ~ '8 ~ ~ ~ J.ç š- 0/ 6/29/98 -- NO. 11302 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A TIN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) ~~- Well Job # Log Description Date BL RF Sepia LIS Tape GNI #1 98285 PEX-AIT/BCS/CNT/SDN 980128 1 GNI #2 98285 PEX-AIT 980128 1 1 GNI #2 98285 PEX-MCFL 980128 1 1 GNI #2 98285 PEX-CNL 980128 1 1 GNI #2 98285 PEX-3 DET.DENSITY CNL 980128 1 1 GNI #2 98285 BHC SONIC 980128 1 1 GNI #2 98285 BOREHOLE PROALE 980128 1 1 GNI #2 98285 SSTVD 980128 1 1 GNI #2 98285 RFT !J80128 1 1 ~- SIGNED, ~~{t~----------_u_- DATE: : I. Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ~~. o~l - t;'1. ~~~ -- q t'J. ~5S- -'1'1' Ig~ ß~ . 1:;2.0 80' o3~ 'ß~'04ß ~<.Þ . Oï ~ C\3' '3<S <2ì . D~t"J ~ NO. 11255 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL RF Sepia Floppy Disk LIS Tape D.S. 15-4~~qw4 98206 '1'Dl'P 971226 1 1 1 Gn: #1 STEP RATE TEST 980423 1 1 Gn: #2 STEP RATE TEST 980417 1 1 Gn: #3 em, 980510 1 1 D.S. 2-23 PROID:TJ:Cfi PROFILE 980506 1 1 D.S. 6-16 PROID:TJ:Cfi PROfiLE W/PSP 980501 1 1 D.S. 7-33 PROID:TJ:Cfi PROnLE 980418 1 1 D.S. 11-16 ST1 PR.CDX::TJ:Cfi PROFILE 980426 1 1 D.S. 15-09A PR.CDX::TJ:Cfi PROFILE 980509 1 1 D.S. 18-11 PROID:TJ:Cfi PROnLE 980501 1 1 SIGNED: ~¥----------------- DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. 6/15/98 -- FROM: R Reo f\'iH 5 FRX NO.: ARCO Alaska. Inc. ~( Pos.' Office S,);, \ ,..103'50 Anchorage Alas~a ~951 U-O~)6O Telephone 907 2ï1) ~:<i ;: 9137 265 6216 85-131-98 82:3BP P.132 ~~ ~~ David W. Hanson Staff Permit Coordinator Prudhoe Bay/GPMA (ATO-1968) 907-263-4745 907-264-4334 (fax) May 1,1998 Ms. Wendy Mahan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 RE: Grind & Inject Facility Status Eastern Operating Area, Prudhoe Bay Unit Dear Ms. Mahan: <11- z38"' The following information is an update on the completion status of the three Grind & Inject (G&I) injection wells and the slurry operations at the plant: Well GNI-1 Well GNI.2 Required by AIO 48? Date Date Surtace Casing Cement Y 1/5/98 1/22/98 Quality Log Injection Casing Cement Y 1/14/98 2/1/98 Quality Log 1 nitial Perforation N 1/12/98 1/13/98 Perf Breakdown/Step Rate N 1/13/98 1/14/98 Test Begin Seawater Injection 4/6/98 4/6/98 Baseline Temperature Survey Y 2/28/98 2/28/98 Baseline Pressure Falloff Test Y 4/17/98 4/20/98 Baseline Step Rate Test Y 4/23/98 4/17/98 81 Temperature Log N 4/23/98 4/17/98 MIT Witnessed Y 4/23/98 4/23/98 Begin Slurry Injection 4/25/98 5/1198 Well GNI-3 is currently drilling; surface casing was run on April 29. When this well has been completed, a similar status update win be sent to you. Þ.H(:() .c.:.:~I<:! ~'1' :~ . ~..~'. :~. c ~.; ::';"'. ¡{¡(on::¡,;,' "" ,;,,', FROM: "RRCO E~~S I' FRX NO.: '?07 265 6216 05-01-'?8 02:39P P.03 Wendy Mahan May', 1998 \l I~, Page 2 Slurry injection in well GNI-1 began on April 25. As of today (May 1), 129.979 bbls of slurry (6,204 cubic yards of solids) has been injected. Slurry injection is planned to begin in well GNI-2 this evening. 80th the seawater and the slurry injection have proceeded as planned. Please note, beginning on May 1O, Flow Station 2 (FS-2) will shutdown for three days. Because the seawater for G&I comes from FS-2, the G&I plant wiU also be shutdown during this time period. If you have any questions, please call Mike Bill (263-4354) or me. AnCere,y, \J~\0 .c\h'À~ David W. Hanson AACO Alagks. Inc. is a Subsidiary of AtlanticRichtieldCompany ï 7. 0 S-9 'H, \.,~ 4~,,'2.0 qt¡...{3~ q', 2SS- (,<1 . tiC¡ ~O'O~3 1<P . ~~ QS. D~Cø ~ NO. 111019 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm AUn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL RF Sepia Floppy Disk LIS Tape D.S. 1-13~g"4c.ß 98192 CNTG 971224 1 1 1 D.S. 4-41-tt "ß4t/Lf 98190 TDTP 971220 1 1 1 D.S. 5-1 B -tr6SJ'1 98180 TDTP 971225 1 1 1 GNI #1 PRESSlTEMPLOG 980313 1 1 GNI #2 PRESS/TEMP LOG 980314 1 1 D.S. 1-02 PRODUCTION PROFILE 980328 1 1 D.S. 6-16 PRODUCTION PROFILE 980328 1 1 D.S. 9-06 PRODUCTION PROFILE WIDEFT 980329 1 1 D.S. 16-14A CEMENT BOND LOG 980409 1 1 --- ~~P-_' SIGNED: u~~------------ DATE: ~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907)' 562-6521. Thank you. 4/23/98 ~ (, STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well DOil DGas 0 Suspended 0 Abandoned r:g] Service Class II Cretaceous Disposal Well 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97 -238 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22845 4. Location of well at surface .'0 9. Unit or Lease Name 4206' NSL, 964' WEL, SEC. 26, T11 N, R15E, UM i --~~-~. £I] Prudhoe Bay Unit At top of productive interval 10. Well Number 1086' NSL, 4059' WEL, SEC. 23, T11 N, R15E, UM if{' GNI-01 At total depth ,; - I I , ç:':..... 11. Field and Pool 1810' NSL, 3720' WEL, SEC. 23, T11 N, R15E, UM - - '.........--- .,j,. Prudhoe Bay Field I Prudhoe Bay 5. Elevation in feet (indicate KB, OF, etc.) 16. Lease Designation and Serial No. Pool KBE = 49.2' ADL 028323 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband.15. Water depth, if offshore .116. No. of Completions 12/28/97 1/10/98 3/12198 NI A MSL One 17. Total Depth (MD+ TVD) r 8. Plug Back Depth (MD+ TVD)rI19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 8572 6945 FT 8466 6862 FT r:g] Yes 0 No None MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, DIR, SP, CAL, RES, DEN, NEU, Sonic, US IT, CBT 23. CASING. LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 80' 30" 260 sx Arctic Set (Approx,) 13-3/8" 72# L-80 31' 4169' 16" 2030 sx CS III, 610 sx Class 'G' ¡r\.fb",\ .r:, ,¡.t:Lf 9-5/8" 47# L-80 28' 8553' 12-1/4" 2300 sx Class 'G' . d"\ 1 I 1t\nO IJ.r- 1\ I' l~tJ'" . 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RE~a Uti Ii {:iSS \;0115. t.y..,,,....~, ' Bottom and interval, size and number) . SIZE DEPTH SET (MD) PÂCKER t)ET'~(MD) 4-1/2" Gun Diameter, 5 spf 7",29#, L-80 4296' 4201' MD TVD MD TVD 7870' - 7880' 6415' - 6422' 7995' - 8025' 6505' - 6527' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 140 Bbls of Diesel 27. PRODUCTION TEST nDI~ f\1^1 Date First Production I Method of Operation (Flowing, gas lift, etc.) tj ~ \lCll I '\I T "\ L- April 6, 1998 Class II Cretaceous Disposal Well Date of Test Hours Tested PRODUCTION FOR OIL -BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL -BBL GAs-McF WATER-BBL OIL GRAVITy-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. * This well is taking about 9-112 Bbls/Min at 1300 psi on Form 10-407 Rev. 07-01-80 Submit In Duplicate It' , f 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SV3 4102' SV2 4354' SV1 5030' Ugnu 4 5998' Ugnu 1 7270' West Sak 2 8030' West Sak 1 8324' K12 / CM3 8560' 3908' 4092' 4538' 5143' 6000' 6531' 6752' 6935' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed fI Dan Stone c:::::::::::::: - -f"'('").' ~- ........ ~ GNI #1 97-238 Well Number Permit No. / Approval No. Title Senior Drillinq Enqineer Date '1./ \ "I ., ~ Prepared By Name/Number: Terrie Hubble, 564-4628 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 1 0-407 Rev. 07-01 -80 Performance Enquiry Report Operator ARca Page Date 21:07, 11 Feb 98 Formation Integrity Test Report The analysis is from - 01:45, 06 Jan 98 - to - 03:15, 06 Jan 98 Programs in Result Table: GNI #1 Drill & Complete \'ìell Type Time From Time To GNI-01 Event 01:45, 06 Jan 98 01:45, 06 Jan 98 GNI-01 Event 02:45. 06 Jan 98 02:45. 06 Jan 98 GNI-01 Event 03:15, 06 Jan 98 03: 15, 06 Jan 98 Duration Description E.M.W. (equivalent mud weight) Depth MDR 4330.0 4330.0 4330.0 Hole Size MDR 12-1/4 12-1/4 12-114 .J--. ~o.; 0 hr 0 min Obtained required level of integrity 12.3 0 hr 0 min Obtained required level of integrity 12.3 0 hr 0 min Obtained required level of integrity 12.1 '@ ( ( Progress Report Facility PB Surfcote Well GNI-Ol Rig Nabors 18E Page 1 Date 11 February 98 Dateffime 26 Dec 97 12:00-12:30 12:30-00:00 27 Dec 97 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-19:30 19:30-20:30 20:30-21:00 21 :00- 22:00 22:00-00:00 28 Dec 97 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-20:30 20:30-21:00 21:00-21:30 21 :30-22:30 22:30-00:00 29 Dec 97 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-00:00 30 Dec 97 00:00-00:30 00:30-01:30 01 :30-02:00 02:00-04:00 04:00-06:00 06:00-08:00 08:00-12:00 12:00-12:30 12:30-00:00 31 Dec 97 00:00-00:30 00:30-01 :30 01 :30-02: 15 02: 15-02:30 02:30-03:30 03:30-06:00 06:00-12:00 12:00-12:30 12:30-16:30 16:30-18:00 18:00-20:30 20:30-21 :30 21:30-22:00 22:00-00:00 01 Ian 98 00:00-00:30 00:30-02:30 Duration 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 6 hr 1/2 hr 7 hr 1 hr 1/2 hr 1 hr 2 hr 1/2 hr 5-1/2 hr 6 hr 1/2 hr 8 hr 1/2 hr 1/2 hr 1 hr 1-1/2 hr 1/2 hr 5-1/2 hr 6 hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 1 hr 1/2 hr 2 hr 2hr 2 hr 4 hr 1/2 hr 11-1/2 hr 1/2 hr 1 hr 3/4 hr 1/4 hr 1 hr 2-1/2 hr 6 hr 1/2 hr 4hr 1-1/2 hr 2-1/2 hr 1 hr 1/2 hr 2 hr 1/2 hr 2 hr Activity Held safety meeting Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Held safety meeting Rigged up Fluid system Made up BHA no. 1 Held safety meeting Held drill (Accumulator) Made up BHA no. 1 Held safety meeting Drilled to 260.0 ft Drilled to 567.0 ft Held safety meeting Drilled to 1073.0 ft Circulated at 1073.0 ft Pulled out of hole to 211.0 ft R.I.H. to 1073.0 ft Drilled to 1107.0 ft Held safety meeting , Drilled to 1450.0 ft Drilled to 1792.0 ft Held safety meeting Drilled to 2105.0 ft Circulated at 2105.0 ft Pulled out of hole to 1000.0 ft R.I.H. to 2105.0 ft Drilled to 2449.0 ft Held safety meeting Drilled to 2510.0 ft Circulated at 2510.0 ft Pulled out of hole to 180.0 ft Pulled BHA R.I.H. to 2509.0 ft Drilled to 2726.0 ft Held safety meeting Drilled to 3533.0 ft Held safety meeting Drilled to 3597.0 ft Pulled out of hole to 2529.0 ft R.I.H. to 3597.0 ft Circulated at 3597.0 ft Drilled to 3660.0 ft Drilled to 3997.0 ft Held safety meeting Drilled to 4157.0 ft Circulated at 4157.0 ft Pulled out of hole to 667.0 ft R.I.H. to 4157.0 ft Drilled to 4175.0 ft Circulated at 4175.0 ft Held safety meeting Pulled out of hole to 180.0 ft P@ f t Progress Report Facility PB Surfcote Well GNI-Ol Rig Nabors 18E Page 2 Date 11 February 98 Dateffime 02:30-05:00 05:00-06:00 06:00-08:00 08 :00-12:00 12:00-12:30 12:30-20:30 20:30-22:30 22:30-23:00 23:00-23: 15 23: 15-23:45 23:45-00:30 02 Jan 98 00:30-01:30 01:30-02:00 02:00-03:00 03:00-06:00 06:00-07:30 07:30-09:30 09:30-12:00 12:00-12:30 12:30-00:00 03 Jan 98 00:00-00:30 00:30-01 :30 01:30-02:00 02:00-02:15 02: 15-06:00 06:00-11 :00 11 :00-12:30 12:30-13:00 13:00-13:30 13:30-14:56 14:56-16:09 16:09-16:24 16:24-20:00 20:00-21:30 21:30-00:00 04 Jan 98 00:00-06:00 06:00-12:00 12:00-12:30 12:30-17:00 17:00-19:30 19:30-21:30 21 :30-23:00 23:00-00:30 05 Jan 98 00:30-01:00 01:00-04:00 04:00-05:30 05:30-06:00 06:00-12:00 12:00-12:30 12:30-14:30 14:30-15:45 15:45-16:30 16:30-20:30 20:30-22:30 Duration 2-1/2 hr 1 hr 2 hr 4 hr 1/2 hr 8 hr 2 hr 1/2 hr 1/4 hr 1/2 hr 3/4 hr 1 hr 1/2 hr 1 hr 3 hr 1-1/2 hr 2 hr 2-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1 hr 1/2 hr 1/4 hr 3-3/4 hr 5 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/4 hr 1 hr 1/4 hr 3-1/2 hr 1-1/2 hr 2-1/2 hr 6 hr 6 hr 1/2 hr 4-1/2 hr 2-1/2 hr 2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 3 hr 1-1/2 hr 1/2 hr 6 hr 1/2 hr 2 hr 1-1/4 hr 3/4 hr 4 hr 2 hr Activity Pulled BHA Rigged up Casing handling equipment Rigged up Casing handling equipment Ran Casing to 600.0 ft (13-3/8in OD) Held safety meeting Ran Casing to 4169.0 ft (13-3/8in OD) Circulated at 4169.0 ft Held safety meeting Tested High pressure lines Pumped Lo/Hi vis combination spacers - volume 95.000 bbl Mixed and pumped sluay - 313.000 bbl Displaced slurry - 632.000 bbl Functioned DV collar Circulated at 2148.0 ft Cleared Mud pumps Cleared Sand traps Circulated at 2148.0 ft Cleared Mud pumps Held safety meeting Rigged up Flowline Held safety meeting Rigged up Bell nipple Serviced Mud pumps Circulated at 2148.0 ft Circulated at 2148.0 ft Circulated at 2148.0 ft Circulated at 2148.0 ft Held safety meeting Tested High pressure lines Mixed and pumped slurry - 506.000 bbl Displaced slurry - 320.000 bbl Tested Casing Rigged down Divertor Installed Casing head Installed BOP stack Installed Bell nipple Rigged up BOP stack Held safety meeting Rigged up Bell nipple Tested BOP stack Made up BHA no. 3 RI.H. to 2148.0 ft Drilled installed equipment - DV collar RI.H. to 4080.0 ft Circulated at 4080.0 ft Pulled BHA Conducted electric cable operations Conducted electric cable operations Held safety meeting Made up BHA no. 4 RI.H. to 4080.0 ft Circulated at 4080.0 ft Tested Casing - Via string Drilled installed equipment - Float shoe ~@ ( ( Progress Report Facility PB Surfcote Well GNI-Ol Rig Nabors 18E Page 3 Date 11 February 98 DatelTime 22:30-23:30 23:30-00:45 06 Jan 98 00:45-01:45 01:45-02:45 02:45-03: 15 03:15-04:00 04:00-06:00 06:00-12:00 12:00-12:30 12:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-00:00 07 Jan 98 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-14:30 14:30-15:15 15:15-16:00 16:00-00:00 08 Jan 98 00:00-00:30 00:30-04:00 04:00-05:30 05:30-06:00 06:00-07:30 07:30-08:30 08:30-10:00 10:00-12:00 12:00-12:30 12:30-14:00 14:00-14:30 14:30-00:00 09 Jan 98 00:00-00:30 00:30-03:00 03:00-05:00 05:00-05:30 05:30-06:00 06:00-07:00 07:00-08:00 08:00-12:00 12:00-12:30 12:30-00:00 10 Jan 98 00:00-00:30 00:30-06:00 06:00-09:30 09:30-11:30 11:30-13:00 13:00-14:30 14:30-18:00 18:00-21:30 21 :30-23:00 23 :00-00:00 Duration 1 hr 1-1/4 hr 1 hr 1 hr 1/2 hr 3/4 hr 2 hr 6 hr 1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 5-1/2 hr 6 hr 1/2 hr 2 hr 3/4 hr 3/4 hr 8 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1 hr 1-1/2 hr 2 hr 1/2 hr 1-1/2 hr 1/2 hr 9-1/2 hr 1/2 hr 2-1/2 hr 2 hr 1/2 hr 1/2 hr 1 hr 1 hr 4 hr 1/2 hr 11-1/2 hr 1/2 hr 5-1/2 hr 3-1/2 hr 2 hr 1-1/2 hr 1-1/2 hr 3-1/2 hr 3-1/2 hr 1-1/2 hr 1 hr Activity Circulated at 4195.0 ft Tested Other sub-surface equipment - Via string Perfonned fonnation integrity test Perfonned fonnation integrity test Perfonned fonnation integrity test Rigged down High pressure lines Drilled to 4330.0 ft Drilled to 4765.0 ft Held safety meeting Drilled to 5200.0 ft Circulated at 5200.0 ft Pulled out of hole to 4100.0 ft RI.H. to 5200.0 ft Drilled to 5451.0 ft Held safety meeting Drilled to 5451.0 ft Drilled to 6016.0 ft Held safety meeting Drilled to 6200.0 ft Pulled out of hole to 5200.0 ft R.I.H. to 6200.0 ft Drilled to 6570.0 ft Held safety meeting Drilled to 6801.0 ft Circulated at 6801.0 ft Pulled out of hole to 5800.0 ft Pulled out of hole to 650.0 ft (cont...) Pulled BHA Tested Top ram Made up BHA no. 5 Held safety meeting R.I.H. to 6750.0 ft Reamed to 6801.0 ft Drilled to 7352.0 ft Held safety meeting Drilled to 7509.0 ft Circulated at 7450.0 ft Circulated at 7450.0 ft Pulled out of hole to 7000.0 ft Circulated at 7030.0 ft RI.H. to 7509.0 ft Drilled to 7698.0 ft Held safety meeting Drilled to 8220.0 ft Held safety meeting Drilled to 8480.0 ft Drilled to 8480.0 ft (conL.) Circulated at 8572.0 ft Pulled out of hole to 4150.0 ft RI.H. to 8572.0 ft Circulated at 8572.0 ft Pulled out of hole to 1000.0 ft Pulled BHA Rigged up Logginglbraided cable equipment '@ ( { Progress Report Facility PB Surfcote Well GNI-Ol Rig Nabors 18E Page 4 Date 11 February 98 Dateffime 11 Ian 98 00:00-00:30 00:30-04:00 04:00-06:00 06:00-11 :00 11 :00-12:00 12:00-12:30 12:30-13:30 13:30-14:30 14:30-23:30 23:30-00:00 12 Ian 98 00:00-00:30 00:30-01:00 01 :00-06:00 06:00-08:00 08:00-11:00 11 :00-11: 15 11:15-11:30 11:30-12:30 12:30-14:30 14:30-16:00 16:00-17:00 17:00-17:30 17:30-00:00 13 Ian 98 00:00-00:30 00:30-05:00 09:00-12:00 12:00-12:30 12:30-14:00 14:00-18:00 18:00-20:00 20:00-20:30 20:30-21:30 21 :30-22:00 22:00-00:00 14 Ian 98 00:00-00:30 00:30-01:30 01 :30-02:00 02:00-02:30 02:30-04:30 04:30-05:30 05:30-06:00 06:00-08:30 08:30-09:30 09:30-12:00 12:00-12:30 12:30-15:00 15:00-16:30 16:30-19:30 19:30-20:30 20:30-00:00 15 Ian 98 00:00-00:30 00:30-05:30 05:30-06:00 06:00-06:30 Duration 1/2 hr 3-1/2 hr 2 hr 5 hr 1 hr 1/2 hr 1 hr 1 hr 9 hr 1/2 hr 1/2 hr 1/2 hr 5 hr 2 hr 3 hr 1/4 hr 1/4 hr 1 hr 2 hr 1-1/2 hr 1 hr 1/2 hr 6-1/2 hr 1/2 hr 4-1/2 hr 3 hr 1/2 hr 1-1/2 hr 4 hr 2 hr 1/2 hr 1 hr 1/2 hr 2 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 2 hr 1 hr 1/2 hr 2-1/2 hr 1 hr 2-1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 3 hr 1 hr 3-1/2 hr 1/2 hr 5 hr 1/2 hr 1/2 hr Activity Held safety meeting Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations (cont...) Installed Internal BOPs Held safety meeting Installed Internal BOPs Rigged up Casing handling equipment Ran Casing to 4170.0 ft (9-5/8in OD) Circulated at 4170.0 ft Held safety meeting Circulated at 4170.0 ft Ran Casing to 9-5/8in (8000.0 ft OD) Ran Casing to 8552.0 ft (9-5/8in OD) (conL.) Circulated at 8552.0 ft Held safety meeting Pumped Water spacers - volume 70.000 bbl Mixed and pumped slurry - 370.000 bbl Displaced slurry - 630.000 bbl Circulated at 4180.0 ft Pumped Diesel spacers - volume 120.000 bbl Pumped Water based mud spacers - volume 50.000 bbl Circulated at 4180.0 ft Held safety meeting Circulated at 4180.0 ft Removed Casing hanger running tool Held safety meeting Installed Seal assembly Tested BOP stack Made up BHA no. 6 R.I.H. to 1815.0 ft Circulated at 1815.0 ft R.I.H. to 4146.0 ft Circulated at 4146.0 ft Held safety meeting Freeze protect well - 120.000 bbl of Diesel Drilled installed equipment - DV collar Drilled installed equipment - DV collar R.I.H. to 8418.0 ft Drilled cement to 8462.0 ft Circulated at 8466.0 ft Circulated at 8466.0 ft (cont...) Tested Casing - Via annulus and string Laid down 6000.0 ft of 5in OD drill pipe Held safety meeting Laid down 7000.0 ft of 5in OD drill pipe Pulled BHA Conducted electric cable operations Rigged up Tubing handling equipment Ran Tubing to 2300.0 ft (7in OD) Held safety meeting Ran Tubing to 1900.0 ft (7in OD) Installed Control lines Installed Control lines (cont...) '@ ~ ( Progress Report Facility PB Surfcote Well GNI-Ol Rig Nabors 18E Page 5 Date 11 February 98 Dateffime 06:30-09:00 09:00-12:00 12:00-12:30 12:30-15:00 15:00-18:00 18:00-19:30 19:30-21 :00 21 :00-21: 15 21:15-22:15 22: 15-23: 15 23: 15-00:00 16 Jan 98 00:00-00:30 00:30-01 :00 01:00-06:00 Duration 2-1/2 hr 3 hr 1/2 hr 2-1/2 hr 3 hr 1- 1 /2 hr 1-1/2 hr 1/4 hr 1 hr 1 hr 3/4 hr 1/2 hr 1/2 hr 5 hr Activity Rigged down BOP stack Rigged up Surface tree Held safety meeting Installed Surface tree Freeze protect well - 0.000 bbl of Diesel Reverse circulated at 4200.0 ft Freeze protect well - 140.000 bbl of Diesel Installed Pennanent packer Tested Tubing - Via string Tested Casing - Via annulus Rigged down Fluid system Held safety meeting Installed Surface tree Rig moved 20.00 % l \ GNI-01 INITIAL PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 3/1/98: RIH w/bailer & tagged TO at 8426' MD. 3/12/98: MIRU & set BOPS & lubricator on well. PT equipment, then RIH w/perlorating guns & shot initial perforation intervals as follows: Perlorated: 7870 - 7880' MD (Cret) 7995 - 8025' MD (Cret) Used 4-1/2" hollow carriers & shot the perf intervals at 5 spf at 60 degree phasing. Shot upper interval at balanced pressure, and the lower interval at underbalanced pressure. POOH w/guns. ASF. RD. 3/13/98: Pumped 360 bbls Seawater @ 1 - 5 bpm to perform an Injectivity Test. Had a final injectivity of 800 psi at 5 bpm w/360 bbls Seawater away. Followed Injectivity Test wfTemperature Log, which indicated channel down from lowest perfs. Upper set of perfs did not appear to take much injection. RD. Placed the well on initial injection & obtained a valid injection rate. { -- Anadrlll SURVEY REPORT Client: Field: ARCO/SSD Prudhoe Bay/Surfcote Well Name: API number: Job umber: Rig: County: State: GNI#1 50-029-22845 40001915 Nabors18-E NSB AK Spud Date: Last survey date: Total accepted surveys: MD of first survey: MD of last survey: Survey Calculations Calc method for positi, Minimum Curvature Calc method for DLS: Mason & Taylor Geomagnetic data Magnetic Model: Magnetic Date: Magnetic field strength: Magnetic dec (+EIW-): Magnetic Dip: Depth references Permanent datum Depth reference GL above Permanent KB above Permanent DF above Permanent MSL Drill Floor, 47.71 18.7 49.2 47.71 FT FT FT FT ( qJ--¡~d-3'? ######## ~e&- ::ze '\ ¡. 1O-Jan-98 94 110 8573 FT FT BGGM 1996 Version 3-Nov-97 1147.02 HCNT 28.22 degrees 80.73 degrees MWD Survey Reference Criteria Reference G: 1002.68 Reference H: 1147.02 Reference Dip: 80.78 Tolerance G: 4 Tolerance H: 6 Toll"rance Dip: 0.3 Vertical section origin Latidude (+N/S-): 0 Departure (+EIW-): 0 Azim from rotary table to target: 315 degrees Correction Magnetic dec (+EIW-): Grid convergence (+EIW-): Total az carr (+EIW-): mGal HCNT degrees mGal HCNT degrees 28.22 degrees 0 degrees 28.22 degrees 1 110.00 0.00 0.00 0.00 110.00 60.80 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 195.37 0.14 178.50 85.40 195.40 146.20 -0.08 -0.10 0.00 0.10 178.50 0.16 MWD 6-axis 3 286.07 0.17 182.90 90.70 286.10 236.90 -0.25 -0.35 0.00 0.35 180.19 0.04 MWD 6-axis 4 372.04 0.41 151.50 85.90 372.00 322.80 -0.63 -0.75 0.14 0.76 169.45 0.33 MWD 6-axis 5 465.16 0.57 159.90 93.20 465.19 415.99 -1.37 -1.48 0.46 1.54 162.77 0.19 MWD 6-axis 6 556.64 0.84 156.50 91.40 556.5~ 507.39 -2.40 -2.52 0.88 2.67 160.71 0.30 MWD 6-axis 7 647.35 0.91 153.20 90.70 647.28 598.08 -3.71 -3.77 1.47 4.05 158.68 0.10 MWD 6-axis 8 737.87 1.14 142.70 90.60 737.86 688.66 -5.28 -5.13 2.34 5.64 155.46 0.33 MWD 6-axis 9 831.83 1.30 138.00 93.90 8~1.74 782.54 -7.27 -6.66 3.62 7.58 151.48 0.20 MWD 6-axis 10 922.83 1.35 142.40 91.0Q 922.72 873.52 -9.37 -8.28 4.96 9.65 149.05 0.12 MWD 6-axis 11 1013.07 1.20 140.20 90.30 1012.99 963.79 -11.36 .9.85 6.22 11.65 147.73 0.17 MWD 6-axis 12 1107.60 1.15 120.10 94.50 1107.48 1058.28 -13.26 -11.08 7.67 13.48 145.31 0.44 MWD 6-axis 13 1200.04 1.24 122.20 92.40 1199.85 1150.65 -15.13 -12.08 9.32 15.26 142.35 0.11 MWD 6-axis 14 1294.78 1.13 131.80 94.80 1294.63 1245.43 -17.07 -13.25 10.89 17.15 140.60 0.24 MWD 6-axis 15 1387.29 1.08 126.50 92.50 1387.12 1337.92 -18.84 -14.38 12.27 18.90 139.53 0.12 MWD 6-axis 16 1479.63 1.17 127.60 92.30 1479.40 1430.20 -20.64 -15.47 13.71 20.67 138.45 0.10 MWD 6-axis 17 1571.26 1.12 137.60 91.70 1571.08 1521.88 -22.46 -16.70 15.06 22.49 137.96 0.22 MWD 6.axis 18 1667.17 1.16 134.90 95.90 1666.96 1617.76 -24.37 -18.08 16.38 24.40 137.83 0.07 MWD 6-axis 19 1760.05 0.86 126.50 92.80 1759.75 1710.55 -25.99 -19.16 17.60 26.02 137.42 0.36 MWD 6.axis 20 1852.79 1.00 118.90 92.80 1852.54 1803.34 -27.46 -19.96 18.87 27.47 136.61 0.20 MWD 6-axis 21 1947.93 0.81 17.20 95.10 1947.63 1898.43 -27.95 -19.72 19.80 27.95 134.89 1.4S MWD 6-axis 22 2042.01 2.62 351.00 94.10 2041.68 1992.48 -25.89 -16.96 19.66 25.96 130.79 2.05 MWD 6-axis 23 2136.51 4.81 345.40 94.50 2135.98 2086.78 -20.73 -10.99 18.32 21.37 1~0.97 2.35 MWD 6.axis 24 2229.86 6.20 346.40 93.40 2228.95 2179.75 -13.05 -2.30 16.15 16.31 98.12 1.49 MWD 6-axis 25 2325.57 6.46 346.10 95.70 2324.06 2274.86 -4.03 7.95 13.64 15.79 59.78 0.27 MWD 6-axis 26 2418.11 7.10 342.80 92.50 2415.92 2366.72 5.49 18.46 10.70 21.33 30.10 0.81 MWD 6.axis 27 2508.64 9.16 343.60 90.50 2505.50 2456.30 16.76 30.71 7.01 31.50 12.86 2.28 MWD 6-axis 28 2604.73 11.20 348.20 96.10 2600.08 2550.88 31.29 47.19 2.94 47.28 3.57 2.28 MWD 6-axis 29 2694.00 13.15 329.70 89.30 2687.41 2638.21 48.38 64.46 -3.96 64.58 356.48 4.86 MWD 6.axis 30 2785.93 16.08 321.00 91.90 2776.33 2727.13 71.15 83.38 -17.25 85.14 348.31 3.98 MWD 6-axis Page 1 ORIGiNAL (, )( ( Schlumberger ANADRILL Survey Report Seq Measured Incl Azimuth # Depth angle angle ft d d deg 31 2878.97 17.88 317.50 93.10 2865.37 2816.17 98.26 103.94 ~35.02 109.68 341.38 2.22 MWD 6-axis 32 2973.99 19.84 313.10 95.00 295527 2906.07 128.94 125.71 -56.65 137.88 335.74 2.55 MWD 6-axis 33 3067.53 23.24 309.70 93.50 3042.23 2993.03 163.18 148.34 -82.43 169.71 330.94 3.87 MWD 6-axis 34 3159.16 24.67 309.70 91.70 3126.03 3076.83 200.25 172.12 -111.08 204.85 327.16 1.56 MWD 6-axis 35 3251.29 27.20 310.50 92.10 3208.85 3159.65 240.38 198.08 -141.88 243.65 324.39 2.77 MWD 6-axis 36 3347.16 29.24 313.10 95.90 3293.35 3244.15 285.65 228.32 -175.65 288.07 322.43 2.48 MWD 6-axis 37 3441.82 30.88 313.80 94.60 3375.23 3326.03 333.02 260.91 -210.05 334.95 321.16 1.77 MWD 6-axis 38 3534.77 31.75 312.70 93.00 3454.68 3405.48 381.33 294.02 -245.25 382.88 320.17 1.12 MWD 6-axis 39 3627.84 32.79 313.30 93.00 3533.31 3484.11 430.95 327.89 -281.57 432.19 319.35 1.17 MWD 6-axis 40 3721.71 34.70 314.10 93.90 3611.39 3562.19 483.09 363.93 -319.27 484.13 318.74 2.09 MWD 6-axis 41 3812.06 36.41 313.00 90.40 3684.93 3635.73 535.64 400.14 -357.37 536.49 318.23 2.02 MWD 6-axis 42 3904.27 38.38 313.50 92.20 3758.18 3708.98 591.60 438.51 -398.15 592.29 317.76 2.16 MWD 6-axis 43 3998.40 40.28 313.00 94.10 3830.96 3781.76 651.21 479.36 -441.59 651.76 317.35 2.05 MWD 6-axis 44 4074.45 42.31 312.30 76.10 3888.13 3838.93 701.39 513.38 -478.53 701.82 317.01 2.74 MWD 6-axis 45 4113.03 42.46 312.50 38.50 3916.57 3867.37 727.31 530.88 -497.69 727.69 316.85 0.52 MWD 6-axis 46 4197.60 42.41 315.80 84.60 3979.02 3929.82 784.38 570.63 -538.64 784.70 316.65 2.63 MWD 6-axis 47 4271.88 43.41 312.60 74.30 4033.44 3984.24 834.94 605.88 -574.91 835.23 316.50 3.23 MWD 6-axis 48 4363.31 45.19 312.20 91.40 4098.85 4049.65 898.71 648.92 -622.05 898.91 316.21 1.97 MWD 6-axis 49 4455.96 46.76 314.30 92.70 4163.28 4114.08 965.32 694.60 -670.58 965.47 316.01 2.35 MWD 6-axis 50 4548.01 48.26 316.70 92.00 4225.43 4176.23 1033.15 742.99 -718.11 1033.30 315.98 2.52 MWD 6-axis 51 4641.71 49.28 316.90 93.70 4287.18 4237.98 1103.58 794.36 -766.35 1103.76 316.03 1.10 MWD 6-axis 52 4733.36 49.42 318.00 91.70 4346.92 4297.72 1173.09 845.61 -813.39 1173.31 316.11 0.92 MWD 6-axis 53 4825.98 49.50 318.30 92.60 4407.11 4357.91 1243.36 898.03 -860.34 1243.64 316.23 0.26 MWD 6-axis 54 4916.28 49.83 317.30 90.30 4465.56 4416.36 1312.10 949.02 -906.58 1312.45 316.31 0.92 MWD_M 55 5015,62 50.75 315.70 99.30 4529.00 4479.80 1388.46 1004.42 -959.16 1388.83 316.32 1.55 MWD 6-axis 56 5110.65 50.68 316.10 95.00 4589.15 4539.95 1461.99 1057.22 -1010.34 1462.36 316.30 0.33 MWD 6-axis 57 5204.26 50.78 316.90 93.70 4648.46 4599.26 1534.50 1109.84 -1060.27 1534.90 316.31 0.67 MWD 6-axis 58 5299.81 51.23 317.00 95.50 4708.56 4659.36 1608.68 1164.08 -1110.93 1609.12 316.34 0.48 MWD 6-axis 59 5393.38 51.84 315.30 93.60 4766.78 4717.58 1681.95 1216.93 -1161.71 1682.40 316.33 1.56 MWD 6-axis 60 5487.58 52.12 316.00 94.20 4824.80 4775.60 1756.15 1269.99 -1213.58 1756.60 316.30 0.66 MWD 6-axis 61 5581.05 52.23 314.80 93.50 4882.14 4832.94 1830.00 1322.!;i8 -1265.44 1830.45 316.26 1.02 MWD 6-axis 62 5675.45 51.59 313.10 94.30 4940.32 4891.12 1904.20 1374.09 -1318.86 1904.60 316.17 1.57 MWD 6-axis 63 5768.44 51.69 313.40 93.00 4998.03 4948.83 1977.09 1424.05 -1371.98 1977.44 316.07 0.27 MWD 6-axis 64 5862.15 51.20 314.jO 93.80 5056.50 5007.30 2050.43 1474.87 -1424.88 2050.73 315.99 0.91 MWD 6-axis 65 5955.95 50.38 314.40 93.70 5115.73 5066.53 2123.02 1525.62 -1476.79 2123.31 315.93 0.88 MWD 6-axis 66 6049.51 49.26 314.10 93.60 5176.12 5126.92 2194.53 1575.52 -1528.02 2194.79 315.88 1.22 MWD 6-axis 67 6141.77 48.96 314.40 92.30 5236.54 5187.34 2264.30 1624.21 -1578.00 2264.54 315.83 0.41 MWD 6-axis 68 6235.52 47.81 314.60 93.70 5298.77 5249.57 2334.35 1673.31 -1627.96 2334.57 315.79 1.24 MWD 6-axis 69 6326.84 47.82 314.20 91.30 5360.08 5310.88 2402.00 1720.64 -1676.30 24Q2.20 315.75 0.32 MWD 6-axis 70 6417 .90 48.10 314.90 91.10 5421.08 5371.88 2469.65 1768.10 -1724.51 2469.84 315.72 0.65 MWD 6-axis 71 6512.92 47.91 315.70 96.00 5484.65 5435.45 2540.25 1818.29 -1774.17 2540.44 315.70 0.66 MWD 6-axis 72 6607.01 46.89 315.20 94.10 5548.34 5499.14 2609.52 1867.65 -1822.76 2609.71 315.70 1.15 MWD 6-axis 73 669~.39 47.37 315.40 92.40 5611.20 5562.00 2677 .23 1915.79 -1870.40 2677.43 315.69 0.54 MWD 6-axis 74 6793.90 47.20 315.10 94.50 5675.31 5626.11 2746.67 1965.10 -1919.28 2746.86 315.68 0.29 MWD 6-axis 75 6887.27 47.08 315.50 93.40 5738.84 5689.64 2815.13 2013.76 -1967.43 2815.32 315.67 0.34 MWD 6-axis 76 6982.23 46.3& 315.70 94.90 5803.89 5754.69 2884.23 2063.13 -2015.78 2884.42 315.67 0.75 MWD 6-axis 77 7074.95 46.70 316.00 92.80 5867.72 5818.52 2951.58 2111.46 -2062.70 2951.78 315.67 0.42 MWD 6-axis 78 7169.14 47.32 317.50 94.10 5931.88 5882.68 3020.37 2161.60 -2109.86 3020.59 315.69 1.34 MWD 6-axis 79 7263.89 47.67 317.30 94.80 5995.93 5946.73 3090.20 2213.04 -2157.16 3090.45 315.73 0.40 MWD 6-axls 80 7359.98 46.84 318.00 96.10 6061.16 6011.96 3160.70 2265.19 -2204.71 3160.99 315.78 1.02 MWD 6-axis 81 7450.74 46.33 317.60 90.70 6123.50 6074.30 3226.50 2314.00 -2248.96 3226.83 315.82 0.65 MWD 6-axis 82 7544.65 46.52 318.40 93.90 6188.22 6139.02 3294.43 2364.56 -2294.48 3294.81 315.86 0.65 MWD 6-axis 83 7639.03 45.87 319.20 94.40 6253.57 6204.37 3362.41 2415.81 -2339.35 3362.85 315.92 0.92 MWD 6-axis 84 7735.69 46.11 318.30 96.70 6320.75 6271.55 3431.81 2468.10 -2385.21 3432.31 315.98 0.71 MWD 6-axis 85 7830.22 45.00 318.70 94.50 6386.92 6337.72 3499.15 2518.63 -2429.92 3499.71 316.03 1.21 MWD 6-axis 86 7923.56 43.93 317.90 93.40 6453.58 6404.38 3564.46 2567.48 -2473.43 3565.08 316.07 1.29 MWD 6-axis 87 8Ö18.39 42.83 318.00 94.80 6522.48 6473.28 3629.49 2615.83 -2517.04 3630.16 316.10 1.16 MWD 6-axis 88 8114.09 41.88 318.40 95.70 6593.20 6544.00 3693.86 2663.89 -2560.02 3694.59 316.14 1.03 MWD 6-axis 89 8206.75 40.80 318.50 92.60 6662.73 6613.53 3754.91 2709.66 -2600.59 3755.71 316.18 1.17 MWD 6-axis Page 2 ( ( 90 8298.58 40.36 318.40 91.90 6732.52 6683.32 3814.59 2754.40 - 2640.24 3815.44 316.21 0.48 MWD 6-axis 91 8390.63 39.51 318.20 92.00 6803.07 6753.87 3873.54 2798.49 - 2679.52 3874.46 316.24 0.93 MWD 6-axis 92 8483.17 38.74 318.30 92.60 6874.90 6825.70 3931.88 2842.09 - 2718.43 3932.85 316.27 0.83 MWD 6-axis 93 8513.53 38.52 318.30 30.30 6898.57 6849.37 3950.77 2856.21 - 2731.02 3951.76 316.28 0.73 MWD 6-axis 94 8573.00 38.52 318.30 59.50 6945.12 6895.92 3987.76 2883.88 - 2755.67 3988.79 316.30 0.00 MWD_M Page 3 -~~ qr,.~~~ ~ z?-q~ .- 4/15/98 ~ NO. 111005 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm AUn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) Well Log Description Floppy Disk Job # Date BL RF Sepia GNI#1 98184 MWD GR-REAL TIME 980110 1 1 1 SIGNED: ~~---------------------------- DATE: ~t~t5 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. qt-z.;)..~~ 91'~5S- '1 t-r - ,.., <.0 'ì ~ . O( U> 'it; . of.Þlp ~{g.13'8 3/4/98 ~ NO. 11884 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL RF Sepia Floppy Disk LIS Tape GNI #1 PRESSURE 'l'D2PERATURE GR/CCL .:JEWELRY UX; 980228 1 1 GNl #2 PRESSURE 'l'D2PERATURE GR/CCL .:JEWELRY UX; 980228 1 1 D.S. 07-37 PRESS/TEMP UX; 980219 1 1 D.S. 9-2 PROWCTION UX; FBS Icml PRESS/TEMP I GRAD 980227 1 1 D.S. 11-36 PROIX1CTION LOG FBS/cnI/PRESS/TDlP/GRAD 980226 1 1 D.S. 02-06A .....~-;~C 97568 RST-BORAX UX; REPROCESSED 971112 1 1 '* t ~~- SIGNED: c=fÇ>~~ (7~ -------------- ------!-~l------ DATE: 0>/0:::Á1: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. t ( Well Compliance Report File on Left side of folder 197-238-0 PRUDH~ BAY UNIT MD 08572.~ TVD 06945.. ~Ietion Date: .- T Name Interval G&I-01 50- 029-22845-00 ARCO 3/~/~~ ""Completed Status: WDSPL Current: Sent Received OH 4/1 5/98 4/15/98 CH 5 2/4/98 2/4/98 OH 2/16/98 2/19/98 OH 4/15/98 4/15/98 OH 2/16/98 2/19/98 OH 2 2/16/98 2/ 19/98 OH 2/16/98 2/] 9/98 OH 2/16/98 2/19/98 CH 3/4/98 3/5/98 CH 5 4/23/98 4/30/98 CH 5 6/1 5/98 6/24/98 CH 5 3/15/99 3/1 8/99 CH 5 7/1/98 7/2/98 CH 8/4/99 8/4/99 01-1 4/16/98 4/17/98 OH 2/16/98 2/19/98 D 8296 '\ .7"" SCHLUM GR V/ BL(C) 50-4000 ~ÁL 3610-8570 ~~ 4175-8572 L CMT ADV]SOR L DSI L M WD OR L PEX-A]T ~L 36]0-8570 ~;~ 3610-8570 6oP1'N~L 36]0-8570 ~AL 3610-8570 ~L 150-8419 L PEX-BHP L PEX-CN L PEX-NDT L PRES/TEM L PRES/TEM FINAL 7700-8428 L STEP RATE TEST FINAL 4000-8400 lA~.~;00-8004 L TEM/PRES L TEMP-PRES FINAL 100-7995 R CALIPER """"'--1 PDS 0-4303 7/24/99 R SRVY RPT ~-- SCHLUM 110.-8573. T 8331 .~.. SCHLUM AIT/DAS/CN/SDN Daily Well Opsl ;1/i(~j, {?-."J~) ¿ rd m<ì V-- ¡- Are Dry Ditch Samples Required? yes 2.':-.,~j\.nd ReceivegJ_,,y..es-flo'''' Was the well cored? yes ¡¡;:;r,,.. Analysis Description Received?-yes~-oo- Sample'Sënr::'~" Comments: -- ""._".-...._~..-"--'._'''-''-- -. -- ''"'--''-'"--'~''''~''' ,.,-.--.-.-.-.-- ..---.--..-...".-....---.--- - --- - ~~--_.._---_.u_---,u..__.-._,_._,,--,----.--.._.-~-._,"-'..,- .!JJ ---------------._-,---~---------_..__._._-------_._---._--~---.,-,-~--~-,,------_.._--'-'-""---'-'-'-_.._'-.,-----'- _..._----_.__._--~---_._'''-----_._----'''''--''._.'---_.n.-...._~-.'-_'__._-'. .-..---...--..-.-..------" ,".-,-...------,---."..-...--..-.-....- -, --- --.-.- .. -_.-- --.- ---_.~,,-----_._.,---".'._-'------"'''--'._---_._-_._''-'''.--- _.~----. -- .-- - -..-....,.--,.... .-. '...-'.u.-..--".-- . ... --- .--.- .---_'0.....-.- ,,-_. . ..- ..-. . Tuesday, April 04, 2000 - --------..-.-.. T/C/D 0 - -------- -. -~ -- ._-.. ..-.-'.-"--- _._d- - - --, - __n - ---.. .-.. Page I of I CP1- ~~6 l 2/16/98 ~ NO. 11820 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape ~ GNI #1 #=.- 2-=)'~ I 98031 PEX-AIT/DAS/CNT/SDN 980111 1 GNI #1 --.;;;;7 98031 PEX-AIT 980111 1 1 GNI #1 98031 PEX-CNL 980111 1 1 GNI #1 98031 PEX-NEUTRON DENSITY 980111 1 1 GNI #1 98031 PEX~OREHOLEPRORLE 980111 1 1 GNI #1 98031 DSI 980111 1 1 ~,. ------- - --., '- " SIGNED: \..~- Mq:L - Please sign and return one copt of this transnÍïltal to Sherrie at the above address. DATE: Thank you. TO: David Johns / Chairman~ State of Alaska Alaska Oil and Gas Conservation Commission MEMORANDUM DATE: January 5, 1998 . THRU: Blair Wondzell, ~ P. I. Supervisor t /,-2.(.,« FILE NO: 4fnkaefe.doc FROM: Chuck Scheve, ¿,5 Petroleum Inspector SUBJECT: Leak Off test PBU GNI-1 PTD 97-238 Mondav. Januarv 5.1998: I traveled to the Surfcot Pad and witnessed the leak off test of the surface casing shoe on ARCOs GNI-1 disposal well. There were three lealt-off tests done on this well and all tests showed a formation leak off at approximately 600 psi with a 9.4 mud in the hole. This equates to a 12.3 ppg EMW. The initial test showed a pressure anomaly between .5 and .75 bbls pumped, this was attributed to the mud motor in the hole and the location of the pressure gauge on the drill pipe. On the subsequent two tests a second pressure gauge was added to the casing. These two tests repeated well with the first test when plotting off the drill pipe gauge but did not show the above mentioned pressure anomaly when plotting off the casing gauge. The BJ cement unit was utilized for the casing pressure test and all three leak off tests. This unit provided a very stable slow (.33 bbl per minute) pump rate. Digital electric gauges and flow totalizer made for accurate plotting of pressure verses volume. Using the cement unit's displacement tanks provided accurate volume measurements both while pumping and bleeding off pressure. The procedure used for these tests was good and drilling foreman Wayné , Stafford was a pleasure to work with. The use of the Cement pump shdutd be encouraged for future leak off tests. Summary: I witnessed the casing pressure test and the Leak Off test of the surface casing shoe on Area's GNI-1 Well. Attachments: ~ A B C D '4- '4- C a 600 5 i n g 500 p r e400 s s u r 300 e A - Leak Off Point B - Stop Pwnp & Close Valve C - 10 Second Shut-in Pressure D - End Of Test 900 800 700 I I I I I I I 0123456789 . SHUT -IN TIME IN MINUTES (for -x-) I I I I I I I r-X 10 200 100 I 0 I' 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 BARREL'S or STROKES LEAKOFF'3- Maximum Volume Line For L.O.T. ~-~ -0- Casing test -ð- Leak Off test -x- Shut-in -0- Max L.O.P. 1/6/98 A 9001 I I I I I I I I I I I I I I I I I I \ I I I C~ing' I II Maximum Volume I B I '1'-- Line For L.O. T. C 800 D ~ ~ A - Leak Off Point 700 B - Stop Pwnp & Close Valve C - 10 Second Shut-in Pressure C I I 1 I I I I I I' I I I 1 J ! I I~ I I I I ID - End Of Test 8600 I s i I n I g500 I ! 10 11 I I I I I I I I I I ". I -0- Casing test p I I 234 5 6 7 8 9 r SHUT -IN TIME IN MINUTES (for -x-) e 400 s I I I I I I ¡ FFFf I I -tr- Leak Off test s u r 300 e I I I \ II I 1 I I I I I I j I ¡ I I I I I I I I -)(- Shut-in 200 , - , -o-MaxL.O.P. II -~;--.::..- 1 I II ! I ¡ ¡ ¡ I I I I I ! I I I I I I I I I I I I l 100 0 0.00 0.25 0.50 0.15 1.00 1.25 1.50 1.15 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 BARREL'S or STROKES LEAKOFF'~ 1/6/98 A B C D ~ ~ C a 600 s i n gSOO p r e 400 s s u r 300 e 900 800 700 200 100 0123456789 SHUT-IN TIME IN MINUTES (for -x-) Maximum Volume Line For L.O.T. A - Leak Off Point B - Stop Pwnp & Close Valve C - 10 Second Shut-in Pressure D - End Of Test ./~~ -<>- Casing test -6- Leak Off test -x- Shut-in -0- Max L.O.P. 0 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25- 5.50 5.75 6.00 6.25 BARREL'S or STROKES LEAKOFF1 1/6/98 TO: State of Alaska Alaska Oil and Gas Conservation Commission David JOL_~ DATE: January 4, 1998 Chairm~' MEMORANDUM THRU: Blair Wondzell, ~ P. I. Supervisor' ((~19fJ Chuck Scheve, e",..$. Petroleum Inspector FILE NO: afnkadfe. doc FROM: SUBJECT: BOPE Test Nabors 18E PBU GNI-1 PTD # 97-238 Sunday. Januarv 4. 1997: I traveled to Arcos GNI-1 Well being drilled by Nabors Rig 18E and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows the test lasted 2.5 hours with no failures. The test went well with good test procedures being employed by the Nabors crews. The rig was clean and all related equipment appeared to be in good working order. The location was spacious and well organized. Summary: I witnessed the initial BOPE test on Well GNI-1 being drilled by Nabors Rig 18E. Nabors 18E, 10/31/97, Test Time 2.5 hours, no failures Attachment: afnkadfe.xls Confidential (Unclassified if doc. removed) X Unclassified - Confidential jl I~ ,1 STATE OF ALASKA ( OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Workover: Nabors - Rig No. SSD GNI-1 Set@ Weekly - Other MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Post~ BOP STACK: Annular Preventer Pipe Rams I..ower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Well Sign OK Drl. Rig OK Hazard Sec. OK ' Yes... Quan. Test Press. P/F 1 25013000 P 1 250/5,000 P 1 250/5,000 P 1 250/5,000 P 1 250/5,000 P 2 250/5,000 P 1 250/5,000 P N/A N/A N/A Visual OK OK OK OK OK Alarm OK OK OK OK . OK ~ 1/4/97 659/4608 Wayne Stafford Allen Madson T. 11N R. 15E Meridian ~ DATE: 18E PTD # 97-238 Rig Ph.# Rep.: Rig Rep.: Location: Sec. 26 TEST DATA FLOOR SAFETY VALVES: Upper Kelly IIBOP Lower Kelly IIBOP Ball Type Inside BOP CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes UM Test Quan. Pressure PIF 1 250/5,000 P 1 250/5,000 P 1 250/5,000 P 1 250/5,000 P 16 32 1 1 Test Pressure 25015 000 250/5 000 Functioned Functioned P/F P p p p OPERATION: Drlg: x Drlg Contractor: Operator: Well Name: Casing Size: 133/B Test: Initial X ACCUMULATOR SYSTEM: System Pressure 3000 '= Pressure After Closure 1600 " 200 psi Attained After Closure minutes 30 sec. System Pressure Attained ---:¡- minutes 50 sec. Blind Switch Covers: Mast~ OK Remote: OK Nitgn. Btl's: 8 @ 2000- Psig. .. . .. .. TEST RESU~TS. . ... . . ...' Number of Failures: 0 ,Test Time: 2.5 tfours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good Test Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021 L (Rev.12194) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Chuck Scheve Witnessed By: afnkadfe TONY KNOWLES, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 16, 1997 James Smith Senior Drilling Engineer, Acting ARCO Alaska, Inc. POBox 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit GNI # I ARCO Alaska, Inc. Permit No. 97-238 Sur. Lac. 4206'NSL, 964'WEL, Sec. 26, TllN, RI5E, UM Btmhole Loc. 1883'NSL, 39I9'WEL, Sec. 23, TIIN, RI5E, UM Dear Mr. Smith: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmcntal agencies, and does not authorize conducting drilling operations until all other required permitting determinations arc madc. Please rcfer to the attached letter addressed to Tom Wellman for the requirements for all ncw grind and inject wells. The blowout prevention equipment (BOPE) must be tcstcd in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission pctroleum field inspector on thc North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosure cc: Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation \v/o cncl. / STATE OF ALASKA:, ALASK~ \ .JIL AND GAS CONSERVATION C¿..¡MISSION PERMIT TO DRILL 20 AAC 25.005 !,~~ ~ìí'i ',,~~ ~, '¡¡¡¡ ~fl~1" ~~ 1:11 ~~ÌIÞ !j1~~1 ,Ü ~\ ~:I::;I ~tI? ~î~ ~¡i 1 a. Type of work ~ Drill D Redrill 111 b. Type of well D Exploratory D Stratigraphic Test D Development Oil D Re-Entry D Deepen ~ Service D Development Gas D Sinqle Zone D Multiple Zone 2. N¡:¡.Z2?Jator f ~J1, 11-1 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 50.70' Prudhoe Bay Field / Prudhoe 3. Address I 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028323 4. Location of well at surface 7. Unit or Property Name 11 . Type Bond (See 20 MC 25.025) 4206' NSL, 964' WEL, SEC. 26, T11 N, R15E, UM Prudhoe Bav Unit At top of productive interval 8. Well Number Number U-630610 1521' NSL, 3558' WEL, SEC. 23, T11 N, R15E, UM GNI #1 At total depth 9. Approximate spud date Amount $200,000.00 1883' NSL, 3919' WEL, SEC. 23, T11N, R15E, UM 12/17/97 12. Distance to nearest property line13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028322, 1361' No Close Approach 2560 8760' MD / 7051' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 MC 25.035 (e)(2)} .,,,oÞ./33SO p" D" Kick Off Depth 2000' Maximum Hole Anqle 48° Maximum surface -aaee. psig, At total depth (TVD) ---8808' " 4398 psig 18. Casing Program Specifications Setti ng Depth a .-;.!.,. e:r.. ~"'7 Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H-40 Weld 80' Surface Surface 110' 110' 260 sx Arctic Set (Approx.) 16" 13-3/8" 72# L-80 BTC 4132' Surface Surface 4132' 3941' 2550 sx CS, 470 sx Class 'G' 12-1/4" 9-5/8" 47# L-80 BTC-Mod 8760' Surface Surface 8760' 7051' 1920 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner RECEIVE' Perforation depth: measured DEC 1 1 1994. ORIGINAL true vertical Älaska Oil & Gas Cons. Con m 20. Attachments 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program .. 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 MC 25.050 Requirements Contact Engineer Name/Number: David Nakamura, 564-5480 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify th,M' he foregoing is trvnd co~rect to the best of my knowledge Date / rJ¡;/1 9') Signed ~JJU L ~ Title Senior Drilling Engineer, Actinq James Smitlì ì1 ,// V Commission Use Only Permit Number V I API Number Approval D~ I See cover letter ?7-23~ 50- ð2..9 -- 2. Z <? 7" S /~ -/ b - 1 for other requirements Conditions of Approval: Samples Required DVes ~No Mud Log Required DVes ,RINo Hydrogen Sulfide Measures DVes ~No Directional Survey Required '"2!1 Ves DNo Required Working Pressure for BOPE D2M; ~3M; D5M; D10M; D15M Other: Onginal Signed By by order of Date I ~ .-J (, -9 1 Approved By O;:)virl W ,Jnhn~tnn Commissioner the commission D IS! Form 10-401 Rev. 12-01-85 Submit In Triplicate I Type of Well: ( ( I Well Name: I GNI #1 (Surfcote Pad West) Injection Well Summary I lJ!]ector Surface Location: 4206'F8L 9641 FEL, 826 T11 N R15E UM Target Location: 1521' F8L 3558' FEL, 823 T11 N R15E UM BHL: 1883' F8L 3919' FEL 823 T11N R15E UM I AFE Number: 14J0364 1 Estimated Start Date: 112/17/97 I Rig: I Nabors 18E 1 Operating days to complete: 118 I MD: 18760' I Well Design: ~VD: 17051' I KB Elev. 150.70' I Big Bore Injector Objective:: Three new Class II Cretaceous disposal wells are planned in support of EOA Reserve Pit Close Out Grind and Inject operations. These wells will be located at the east end of the Surfcote Pad, between DS-4 and L-4. These disposal wells will be in highly erosive service, accepting mud and cuttings slurries. No chrome alloys are required and H2S fluids in'ection is unlikel . Bond 10 s are re uired in each well. Formation Markers Formation Tops MD TVD SV5 3294' 3251' SV3 4119' 3931' UG1 7292' 6051' CM3 8760' 7051' TO 8760' 7051' Casin Hole Size Tubular WtlFt Grade Conn 8tm O.D. MDITVD 30" 20" 94# H-40 Weld 80' 11 0'/11 0' 16" 13-3/8" L-80 BTC 4132' Su rface 4132'/3941' 12-1/4" 9-5/8" L-80 BTC-MOD 8760' Surface 8760'/7051' L-80 BTC-MOD Surface 4433'/4151' RECEIVED DEC 11 1991 Page 1 Aluka au &. aø CønJ. commission A"~hø'agø ( ,'- \ Lo 0 en Hole Lo s: 1611 Hole: MWD Dir/GR 12-1/411 Hole: MWD Dir/GR; GR/SP/Cal/Sonic/Resist/Densit /Neutron Cased Hole Lo s: 16" Hole: GR/USIT/CBT 12-1/4" Hole: GR/USIT/CBT Directional 48° None None Cement Calculations Lead Cement Tail Cement Casina/Liner Sk / Wt / Yield Sk / Wt / Yield Comments Cold Set Lead to surface (400% excess through 13-3/8" 2550/12.2/1.92 470/ 15.8/1.15 permafrost, 50% excess to top tail); Class G Tail (750' MD with 50% excess; Pump time=4+ hr.; TOC = Surface Class G Tail (50% excess to surface casing shoe); Pump 9-5/8" N/A 1920 / 15.8 / 1.15 time=4+ hr.; TOC = :1:41321 MD (surface casino shoe) Volume assumptions: Gauge hole + designated excess; 801 shoe joints; TOC as designated. M dP u rogram Surface Section: Spud Mud I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Initial 9.6 :I: 300 35-50 25-45 50-80 9-10 15-20 Final 9.8 300 20-40 15-30 30-50 9-10 15-20 Hazards/Concerns Gravel beds, bridging, lost circulation. Frequent sweeps to aid hole cleaning. Intermediate Section: LSND Densit , Funnel Vis, sec LSR YP Gels H 10.0 - 10.2 40 - 60 8 - 13 15-25/20-35 9 - 10 Hazards/Concerns Potential high torque could require lubricant use. Be alert for lost circulation, differential stickin due to hi her MW. HPHT FL, cc <10 Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. . Maximum anticipated BHP: 3350 psi @ 7000' TVDss (9.2 ppg EMW) . Maximum surface pressure: 2650 psi @ 7000' TVDss (based on BHP and a full column of gas from TO @ 0.10 psi/ft) REtE1VED DEC 11 1991 Page 2 IU0.8\<Ø on I!t G~§ Gnns (iommission Anuhor~nG ( ( Operations Summary Drillina Ria Procedure 1. Pre-rig: Set and cement 80' of 2011 conductor. Install cellar ring. 2. MIRU Nabors 18E. NU and function test diverter. 3. Drill 1611 hole to :t41321 MD (:1:3941" TVD) per directional plan. Hold diverter drill while drilling surface hole. 6. 7. Run and cement 13-3/811, 72 lift, L-80 casing to TD. Ensure that cement reaches ./ surface. S~.f- C7v CoÐII- <It 2./3.5": /(~-i; Test 13-3/811 casing to 3,000 psi for 30 minutes. Drill shoe joint and 20' of new formati9r('(..~~ ~ci., Perform and record LOT. Repeat LOT two additional times (three LOTs total). ) ,// ('. ~~.. '\ ;t ~.i( clo ~ L~. pal" ~ ~4..... t. Ð,:r~' 'Jò / Drill 12-1/4" hole directionally to :1:8760' MD (7051' TVD). rz (QI.'i w~ ¡}~...!\I. ~' ...// L . h G /SP/C I. IS . /R . t/D . IN 1'2i3'(~ T ~~~Jf\ / og well Wit R a Iper OnlC eSls enslty eutron. (7 ./ Run GR/USIT/CBT (cement evaluation log) in 13-3/8" casing. 4. 5. 8. 9. Run and cement 9-5/8" casing to TD. TOC to 13-3/8" casing shoe. RU and establish injection down 9-5/8" x 13-3/8" annulus. 10. Test 9-5/8" casing to 4000 psi for 30 minutes. 11. Log 9-5/8" with GR/USIT/CBT (cement evaluation log). 12. Run 7" L-80 completion with packer at :1:4433' MD. Have AOGCC representative witness annulus test. 13. Freeze protect well, set packer. 14. Set BPV, ND BOPE. 15. NU and test tree. 16. RDMO. 17. Post rig: Perforate 9-5/8" casing. Page 3 1~/~8/1~97 22:08 I <KB> 0 400 BOO 1200 1600 2000 T V 2400 0 2800 3200 3600 '4000 4~OO 4800 5,00 '5600 6000 6400 6800 907-344-"'~60 ( SHARED SERVICES ANADRILL DPC ') ( ¡ DRILLING ¡] I I G&I #1 (P6) Surfcote West! VERTICAL SECTION VIEW ~ PAGE 04 Section at: 315.00 TVD Scale.: 1 inch ~ 800 feet Oep Scale.: 1 inch = 800 feet Drawn... ..: 08 Dee 1997 ...~-....._-..--- I I AnadrilJ Schlumberger' I, i INCLN I 0.00 ¡ 0.00 ! 42.64-! 46.35 ¡ 48.36 ¡ 48.36 : 45.32 ! 45.321 ! 1 Marker Identification A) KB BI KOP BUILD 2/100 C} 13-3/8~ CSG PT <1\> D) END 2/100 BUILD E) .CURVE 2/100 F) TARGET ***...*****~* G) END 2/100 CURVE HI TD 9-5/8. CSG PT<I\> MD BKB SECTN 000 2000 2000 0 ~132 3941 757 4417 4141 961 8045 6551 3672 8045 6551 3672 8197 6655 3782 8760 7051 4183 r- ----- ---------- -~~r ---- ----- ---...- i I ! ¡,-.J ! . ¡ I ¡ I' I i I ¡ ----- ---------- ---- ~-~ ----- ----- --------~- ----- ---~- ---~------ ----- ------ 7200 0 400 800 1200 1600 2000 2~OO Section Departure 2800 4000 4400 4800 ¡ 5200 . 3200 3600 (Anildri 11 (e) 97 GI1PI;i 3.2b.5 6: en ~ P) l¿/~~/l~~1 LL:~e 907-344. ---')60 ANADRILL DPC \ , .,. (' SHARED SERVICES DRILLING \ ~r~aU5 200 feet) ('J) ~~ I '" Ì'( ~ ~ ~ "" ~ ~ ~ Marker Iöentification MO A) KB 0 at KOP SUlLO 2/100 2000 C) 13~3/88 cSG PT <II> 4132 0) END 2/100 BUILD 4417 E) CURVE 2/100 8045 F) TARGET ~.**~*~~.**** BO~5 G) END 2/100 CURVE 8197 H) TD 9-5/e8 CSG PT<I\> 8760 ~. .. 3250 3000 2500 2750 LAnal1rHl (C)97 GI1P6 3.i!b.5 6:28 PM PI N/S 0 N 0 N 536N 679 N 2596 N 2596 N 2675 N 2958 N 2250 E/H 0 E 0 E 536 W 619W 2596 W 2596 \II 2675 W 2958 ... . 2000 1750 1500 I Gf;! #1 (P6) Surfcote West I PLAN VIEW !. . i at AZImuth 315.0q i I I ! I I I ¡ I i ., I : i '. II i :c I l- I :::;) ; 0 ¡ en 1:50 ~ 250 0 2~ : I <- WEST: EAST -> ¡ ¡.--- ! ,I' \ CLOSURE. ....: 4163 feet DECLINATION.: +28.534 (E) SCALE.,.,.,.: 1 inch = 500 feet DRAWN...,.,.: 08 Dee 1997 Anadril1 Schlumberger .-- --- I ," . A .....nl I ~ .\ 'Or ~... ! \ 1 \ r. , C; A "A-DP 1 \ \ ! APPRO\J ED ~tRPI RMrr111\'G ,.- ~)'" L " i> AN :If (~ C!(~ \ ,. .-----...-. . -,......... --.---.- --.. .-------.,....-..-. 1250 1000 750 500 PAGE 0:5 ¡ ! IJ , 32J ) ~ i ! -j 30\1) ¡ 27!:0 i ! 210 I I 2~:¡0 ¡ !.. i 2~!)O i I ¡ 1pO i I I i 11iJO I ! i 11:50 I ¡ ~ i i 1- I i i ! 1 i ~ i I i ~oo ;;0 1)0 ^ jO I :x:: l- ce 0 :z: D Anadrill schJumhergrr t Ala~ka District; ¡ 111L East 80t.h Avenue Ancnorage I AK 99518 (901) J.9-4511 Pax 344-2160 -~~;. . DIRECTIONAl. WBlL PLAN for SHARED SBRVICBS DRILLING ~ell.........: GkI '1 (P6) Surfcote west Field........: prudboe Bay. Surfcote Pad oomputatioD..: MiniMum curvature Uait8........~ PlBT surface Lat..: ?0.~aJ00800 N surface Long.: 148.24362703 W . y-coord 5956199.8'7 5958720.00 S959070.S8 LOCATIONS ~ ALAS KA Zone; x-coord 717019.97 714350.00 713978. U surface......: 'rarge t . . . . . . . : BHI. . . . . . . . . . . : Legal Description 4206 PSI. 964 PS~ g26 TllN R15E UK 1521 FBI. 3558 FBI. 623 'l'11N R158 OM 1883 ~SI. 3~19 PEL S23 T11N R15B UN PROPOSBD We:LL PROFILE ..-=s...~s...=--_G=- c.:-s__c:=-- 2__a:;:l3111 ::I-.-¡:;;:~-_. ----_._"=---~---- ---=---.. STATION MBASURED INCLN DIRBCTION VERTI~-DEnHS SBC1'ION IDSNTIFICA'lIOll DBP'I'H 1<NGLB AZlMU'lB TVD SUB-SBA DEPART _.-----=...-~...g=-- -::..g==--" ---=_.- --a;-<:8---_. -=---_.. -~=_._G= 8S---.." tœ 0.00 0.00 0.00 0.00 -50.70 0.00 BAS! pE:RMAP'ROST 1935.70 0.00 0.00 1935.70 18S5.00 0.00 XDP BUILD 1/100 2000.00 0.00 a.oo 2000.00 1949.30 0.00 2100.00 2.00 315.00 2099.98 2049.28 1.15 2200.00 4.00 315.00 2199.S. 2149.14 6.98 lIrepared. . . . . I Vert sect az.: XB elevatiOD.: KagJlet:ic Dcln: scale pactor.: 08 Dee 1.997 31.5.00 50.70 ft +28.534 (I) 0.99995350 +1.65345683 I --/ f ( ( ~.1.. Con vergence. . : ANADRlll AKA-DPC APPROVED FOR PERMITTING ONLY PLAN #~ -_S..._~__5--.g8-.~- .....----....-..---- --_as Co-.- COORDINA'l'ES - PROM ALASKA Zone 4 'rOOt. DLI J 1 WBI.t.HEAD X Y FACS 100 t ;;¡ _C...K---- -_g___QD-- _.s..__._~----._-- ---- .-.- I- r 0.00 N 0.00 1 117019.87 5956199.8""-- HS 0.00 r 0.00 1J 0.00 B 71.7019.81 5956199.97 HS 0.00 t , 0.00 N 0.00 B 7L70]9.87 S956199.87 45L. 0.00 ~ ( 1.23 N 1.23 W 711018.60 Si56201.01 45t.. 2.00 4 . 93 1l 4.93)( '71.7014.80 5956204.66 45L 2.00 --_J 315.00 2299.45 2248.'75 15.69 11.10 N 11.10 W 717008.46 5956210.64 HS 2.00 31.5.00 2396.70 2348.00 27.88 19.'71 N 19.'71 W 11.6999.60 5956219.01 HS 2.00 315.00 2497.4'7 2446.77 13.52 30.78 Ii 30.77 'If 716988.22 5956229.'74 HS 2.00 J L5. 00 2595.62 2544.92 62..60 44.27 N U .27 W 716974.35 S956242.84 HS 2.00 315.00 2693.06 2642.36 85.10 60.17 N 60.17 W 7]6957.99 5956258.28 HS 2.00 L D G') fTi ---.---------------.-.------.-------...----.--.---.--------.--.--------...-.---.--..--.....-...--------...---.----..---.--.---------.--.u -.....---.- ...-........ -"'-' .--.-.,.---...-....-- ..-.---'-" .-..... ..- ...-- .-- CSì (Ju\adriLL (c)91 GI1P6 J .2b.5 6:24 PM P) I\,) '2300.00 6.00 24GO.OO 8.00 2500.00 LO.OO 2600.00 12.00 '2700.00 14 .00 ::2800.00 16.00 315.00 2789.64 2738.94 315.00 2885.27 2834.57 110.9& 1.40.'21 2900.GO 18.00 78.47 N 99.15 N 78.47 W 716939.1.7 5956276.04 as 99.1~ W 716917.91 5956296.11 HS 2.00 2.00 G&:I #1 (P6) Surfcote WeBt Oð Dee 1991 ~age 2 ~ROP09ED HB~~ PROFILB !i ~=~._==~.c;=._-==._~ 8a:::ZZ:--== -=:::;;::;;--- .---;;;=s_- ._c=_w-==.~~ø-=== =---=_.. __~=..D=...==~.D~=~-. ---~s..=-_G-..P---=. STA'l'ION Me:1\SURBD INCLN DIRECTION VSR'r[CAL-DBPTHS SHerrON OOORDIHATSS-PROM AlAS KA Zone .( TOOL DLI IDENTIFICATION DEPTH ANGLE AZ IMUTH TVD SUB-SEA DEPART WSLLHBAD X Y I?ACB LOO =..~==.8==..-==s.c=- ==.._s::::z:s :;;:::121._== ..===_81== -=_.==S8 =~.8I~=_C .-==--;::=r _=__K=~..; ---;=,.-~. -=s_c~=.- --_.._~..~ _c:=-- ... 300-0.00 20.00 315.00 2979.82 2929.12 112.11 122.17 N l22.16 19 7L6894.245956318.(6 KS 2.00- 31{)0.00 2'2.00 3J.S.OO 3073.11 3022.41 208.60 141.51 N 147.50 H 716868.18 59563(3.05 US 2.00 3200.00 24.0-0 315.00 3165.21 3114.51 2.47.67 175.13 N 175.13 W 116839.11 5956369.81 HS 2.00 SV5 3:2 H .2.8 25.89 315.00 3250.70 3200.00 '287..3 203.25 N 203.24 W 7L6810.ð6 5956397.16 HS 2.00 3300.00 26.00 315.00 3255.8( 3205.14 289.93 2G5.02 N 205.01 91 116809.04 5956398.88 HS 2.00 3400.00 28.00 315.00 3344.94 3294.24 335.33 237.12 N 231.11 If 716176.03 5956430.04 US 2.00 3500.00 30.00 315.00 3432.39 3381.69 383.81 271.'° N 271. 39 H 716740.78 5956463.31 HS 2.00 3600.00 32.00 315.00 3518.11 3467. U 435.31 307.82 N 307.8L W 116703.33 5956~98.66 H9 2.00 3700.00- 3(.00 3L5.00 3601.97 3551.27 489.77 346.33 N 3'6.32 W 716663.72 5956536.04 US 2.00 3800.00 36..00 315.00 3683.88 3633.18 5(1.13 386.88 N 386.81 H 716622.02 5956575.41 as 2.00 3900.00 38.00 315.00 3763.74 3713.04 607.30 429.44 N 429.4'2 W 716578.26 595661G.72 US '2.00 4DOO.00 '0.00 315.00 3841.45 3790.75 670.23 473.93 N (73.92 W 716532.50 5956659.91 HS 2.00 4100.00 u.OO 315.00 391.6... 92 386~.22 735 . $14 520.32 N 520.31 W 116484.79 5956104.9f HS 2.00 SV3 4118.60 4:2.37 315.00 3930 .10 3880.00 7~8.33 529.15 il 529.14)f 716475.71 5956713.5L HS 2.00 - 13-3/BT CSG liT < 11> 4132.17 4'2.640 315.00 39fO.70 389G.OO 757.49 535 . 64 N 535.62 ~ 716469.04 5956719.80 HS 2.00 "'r=-:- - 4200.00 44. DO ns. 00 3990.05 3939.35 804.03 568.55 N 56B.53 W 716435.20 595675].75 HS 2.00 oao .00 46.00 315.00 4060.16 4010.06 874.74 6 L8 . 54 H 618.52 59 716383.7B 5956800.28 as 2.00 4400.00 48.00 315.00 4128-.95 4078.25 947.87 670.26 N 670.24 N 716330.61 5956850.,a HS 2..00 E:ND '2/100 BUILD 4417.40 48.35 315.00 41.40.56 40ð9.86 960.84 619.U N 679.~0 W 716321.18 5956859.38 US 2.00 4U 1.97 4S.36 315.00 4140.94 4090.24 961.27 679.73 N' 679.71 W 716320.86 5956859.67 as 2.00 OOl 1292.15 48.36 315.00 6050.70 GOOO.OO 3109.22 2199 .59 ~ :z198.52 W 114758.93 5958334.00 KS 0.00 CURVE 2/100 8044.6S 48.36 315.00 6550.70 6500.00 36'11. 58 2596.24 N 2596.16 If 714350.00 5958720.ÐO LS 0.00 TARGET ~~~..~~~.***. 8044 . 6S U.36 315.00 6550.10 6500.00 3671.59 2.596.24 N 2596.16 W 71(3S0.0~5'58720.00~ 0.00 8100.00 47.25 315.00 658'7.87 6537.17 371'2.59 26'25.24 N 2625.16 W 11~320.18 5958748.15 ~s 2.00 BND 2/l00 CURVE 8196.55 45.32 n5 .00 6654.59 6603.89 3782.37 2614.58 N 2674.50 1'1' 714'269.44 59S879~.04 HS 2.00 0(3 B759.5J0 45.3'2 :U5.00 7050.70 7000.00 4162.95 2957.82 N 2957.71 W 713978.13 5959070.98 0.00 TD 9-5/8" CSG PT<I~> 8159.90 45.32 315.00 7050.70 7000.00 4182.95 2957.82 N 2957.17 W 713978.13 5959070.98 0.00 - -_.~-- .-_u_.__._-1ànadr.ill..-' cl~1....<U.1~§. ..~- :.~ ~.:.~.._~_:}.~.._~--~ L__--.----.... -.,.--._u_--.. ANADRiLl . AKA..DPC APPROVED ",-,,--"-' ,-,-----_u'-H---..-.---.--_uuo.ED R 1 E R M f TT I N G . .. --- '"'O-t~fLY-----'--''' ..-."U"" .._~_.-_._..- '-" PLAN #~_.~P j . . I- "- . .... C Q .... I- U U ~ "- "- .. C Q U Œ I Lt ~ ~ I " -J I-- a cs þ Z Þ C ^ I- r r ~ l) () ~-~. '...-/' -0 1> G> fTl (S) . ..__n- -. W ¡ ( 'GNI #1 ( Proposed Completion Design K.B. ELEV = 50.7' TREE: FMC WELLHEAD: FMC BiQ Bore 20", 94#, H-40 @ 1101 MD 7" L -80 Tubing 13-3/8",72#, L-80 @ 41321 MD 7" X 9-5/8" Packer 'X' or 'XN' nipple, WLEG Cretaceous GNI Perforations 9-5/8",47 #, L-80 @ 8760' MD '. DATE REVISED BY COMMENTS PRUDHOE BAY UNIT 12/10/97 D. Nakamura Grind and Inject #1 WELL: G&I #1 API NO 50-029-22XXX SEC 26; T11 N; R15E BP Exploration (Alaska) H 127943 DATE INVOICE CREDIT MEMO 092297 CK092297H HANDL NG INST: DESCRIPTION GROSS s/h terri hubble X 4628 100.00 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. .: /'::~' ',' : ,",,' ~r ,:", ,',., "':'~.""""~ I' ",",'" ',' ,', ',',I,'"! '\ilTOTA'~':,,:,,:,,!:, f;/JI ~I :t DATE Û¥i22i97 VENDOR DISCOUNT CHECK NO 00127943 NET 100.00 H TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 .-\ ugust 7. 1997 \1r. Tom Wellman PRB/GPMA HSET \lanager ARCa Alaska. Inc. r a Box 100360 Anchorage. AK 99510-0360 Subject: Review or' the Drill Site 4 ("OS 4") Incident Report Dear rvlr. Wellman: We received your OS incident report on May 23. 1997 and have now completed our review of it. We also have had several constructive meetings with your staff to exchange views on the interpretation of data and findings. While the precise mechanisms remain elusive for determining the cause of the broach. both groups have brought forth several plausible explanations. Although we may never fully understand what happened. we must keep in mind that our ultimate purpose is to learn from this incident so that future disposal projects may be designed and operated more safely. To that end we ha\'e formulated several guidelines that we believe will allow both groups to better evaluate future disposal operations and prevent any broaching to the surface or into an unwanted interval. Vv'e plan to require these guidelines. with specitic details following a case-by-case review. for all new grind and inject wells. REQUIREMENTS FOR ALL NEW GRIND AND INJECT WELLS As conditions warrant. the following may be required: 1. MIT's every t\\"o years. ì CQL's demonstrating that all casing strings are fully cemented. " .J. Pre-injection step-rate test. taken to the higher of injection rate or pressure. with follow up tests either as warranted. or at certain time or volume intervals. 4. Pre-injection ten1perature surveys. especially gradients. with follo\v-up surveys either as warranted. or at certain time or volume intervals. rom Wellman \ RCO Alaska. Inc. "1 August 7.1997 5. Borax-PNL's or equivalent log. as warranted. 6. Frequent tags to locate tOp of till. In addition to the above guidelines. \\"e will require a thorough revie\\" of all wells within 1/4 mile radius of the grind and inject well (from the point it penetrates the contining zone) to ensure that these other wells can not serve as a conduit for t1uid movement to the surface or into other strata. \Ve will also discourage the siting of any new wells within 1/4 miles radius of the grind and inject well. We invite your comments on these guidelines or if you have any ideas that will improve future operations. If you have any questions. please contact tv1r. Blair W ondzell or Mr. Jack Hartz at the Commission. ~ Robert N. Christenson. P.E. Commissioner cc Johnathan Williams. EP A Alison Cooke. BPX . WELL PERMIT CHECKLIST COMPANY 4vt!' ~ FIELD & POOL INIT CLASS ()~~)f1' ADMINISTRATION WELL NAME (till ,¿1.2.. PROGRAM: exp 0 dev 0 redrll 0 serv'Ji! wellbore seg ¡~: ann. disposal para req U GEOL AREA f9 <::> UNIT# //¿; 5 ð ON/OFF SHORE ~~) A PR pA~E) ~77 ENGINEERING 1. Permit fee attached. . . . . . . . . . . 2. Lease number appropriate. . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . 8. If deviated, is wellbore plat included.. . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval. . 13. Can permit be approved before 15-day wait... ....... 14. Conductor string provided. . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . 24. Drilling fluid program schematic & equip list adequate. 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . .-I¡;'~ BOPE press rating appropriate; test to psig. I J 172lf Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . ¿r- -- GEOLOGY REMARKS .<~J 4~/ /<:.Þ// ~ ...:S- /'t::>£/~,(ye¿/ 6>~ X.) J IJ . -,.J ./ r' c::. l" (! ,jtr; <9~ ~ <0 '!? -Ä 7" r-ð~/~./) Å.VD \.-~~ "i"b v-J~ I A.J~ ~; I\JJ---"i"Ot.,,~~ - ') 30. Permit can be issued w/o hydrogen sulfide measures. . . .)f Æ4 31. Data presented on potential overpressure zones. . . . . .. Y 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . N r 33. Seabed condition survey (if off-shore). . . . . . . . . . . .. Y N 34. Contact name/phone for weekly progress reports. . . . . .. Y N [exploratory only] A8 R D~TE/ /?#4&7 GEOLOGY: RP~C:: ENGINEERING: COMMISSION: BE~2/~WJ~ JDH~) RNC CO Cn'>f¡-i" HOW/lit - A \FORMSlcheklist rev 09J9ï Comments/Instructions: \.Jc. ~ 'I~( ~ 0 0 :z .-. -- -3 ~ =:0 - -3 H - :z -3 - ..... - 00 00 ""0 > .-. l . '.l> ( H " Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history. file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ****************************** ALASKA COMPUTING CENTER ****************************** *----------------------------* *------- SCHLUMBERGER -------* *----------------------------* ****************************** COMPANY NlWE WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO MICROfILMED Date-l/3/0 I : ARCO ALASKA, INC. : GNI #1 : PRUDHOE BAY : NORTH SLOPE : ALASKA : 500292284500 : 98184 9')'-).38 11- g:2~Cp ~ I-.{ lis !î¡ LIS Tape Verification Listing Schlumberger Alaska Computing Center REEL HEADER SERVICE NAME: EDIT DATE : 98/04/14 ORIGIN : FLIC REEL NAME : 98184 CONTINUATION # : PREVIOUS REEL COMMENT 14-APR-1998 12:26 : ARCO ALASKA INC., PRUDHOE BAY GNI #1, API #50-029-22845-00 **** TAPE HEADER SERVICE NAME: EDIT DATE : 98/04/14 ORIGIN : FLIC TAPE NAME: 98184 CONTINUATION # : 1 PREVIOUS TAPE COMMENT : ARCO ALASKA INC., PRUDHOE BAY GNI #1, API #50-029-22845-00 TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA BIT RUN 1 --------- JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 98184 FRISNEGGER WHIPP # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD GNI #1 500292284500 ARCO Alaska, Inc. SCHLUMBERGER WELL SERVICES 14-APR-98 BIT RUN 2 BIT RUN 3 --------- --------- 26 llN 15E 4206 964 49.20 47.70 18.70 ------------- OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ---------- 1ST STRING 2ND STRING 12.250 --------- 13.375 4169.0 PAGE: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3RD STRING PRODUCTION STRING # REMARKS: 14-APR-1998 12:26 PAGE: 2 THIS IS THE REAL TIME MWD GR DATA LOGGED 5-JAN TO 10- JAN-98. $ $ FILE HEADER FILE NAME : EDIT. 001 SERVICE : FLIC VERSION : 001C01 DATE : 98/04/14 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE -------------- MWD $ 1 clipped curves; all bit runs merged. 0.5000 START DEPTH STOP DEPTH ----------- -~._------- 4176.0 8523.0 # BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) ----------EQUIVALENT MWD BASELINE DEPTH -------------- 88888.0 8493.5 8482.5 8477.5 8471.5 8462.0 8446.5 8445.5 8442.0 8425.0 8393.0 8382.0 8364.0 8352.0 8343.0 8339.5 8333.5 8323.0 8264.0 UNSHIFTED DEPTH---------- 88892.0 8497.5 8485.5 8481.0 8476.0 8465.0 8450.5 8448.5 8446.0 8428.0 8397.5 8382.5 8368.0 8357.0 8346.5 8343.0 8336.0 8326.5 8267.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8254.5 8249.0 8245.0 8243.5 8236.0 8232.0 8229.0 8224.0 8217.0 8198.5 8194.0 8188.0 8184.5 8181.0 8150.5 8141.5 8115.5 8101. 0 8094.5 8087.0 8082.0 8072.0 8052.0 8043.5 8034.0 7992.0 7977.5 7974.5 7970.0 7957.5 7943.5 7935.5 7923.0 7900.5 7886.0 7873.5 7860.5 7851.5 7841.0 7836.5 7835.0 7821.5 7815.5 7806.0 7790.0 7770.5 7768.0 7763.5 7757.5 7750.0 7739.5 7730.0 7726.5 7722.0 7706.5 8256.5 8251.0 8248.5 8246.5 8238.5 8232.5 8229.5 8224.5 8218 . 5 8202.5 8196.0 8189.0 8187.0 8183.5 8153.0 8146.0 811 7 .5 8103.5 8097.5 8089.5 8084.0 8073.5 8054.5 8046.0 8037.0 7995.0 7979.5 7975.0 7969.5 7958.5 7945.5 7939.5 7927.0 7904.0 7890.0 7877.0 7862.0 7854.0 7844.0 7840.5 7837.0 7823.0 7817.0 7808.0 77 92.0 7775.0 7772.5 7766.5 7761. 5 7753.0 7741.5 77 32.5 7729.0 7725.5 7709.0 14-APR-1998 12:26 PAGE: 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7692.5 7676.5 7670.0 7664.5 7658.0 7645.0 7641.5 7621. 0 7609.0 7601.0 7595.5 7583.0 7569.0 7560.5 7556.0 7535.5 7528.5 7521.0 7505.0 7486.5 7472.0 7447.0 7440.5 7435.0 7429.5 7417.0 7409.0 7390.0 7379.5 7363.0 7348.5 7336.0 7327.0 7316.0 7309.5 7296.5 7287.5 7284.0 7270.5 7231.5 7220.5 7202.5 7193.5 7185.0 7178.0 7169.5 7160.5 7132.5 7121.0 7117.5 71 02.5 7085.0 7068.5 7050.0 7038.0 7695.0 7678.0 7673.5 7668.0 7662.0 7650.0 7645.5 7622.5 7612.0 7604.0 7597.5 7584.0 7571.5 7563.5 7558.0 7536.0 7530.0 7522.5 7506.0 7486.5 7473.0 7447.0 7441.5 7436.0 7430.5 7417.5 7409.0 7390.0 7380.5 7363.5 7346.5 7334.5 7327.5 7318.5 7308.0 7296.0 7286.5 7281.5 7270.5 7230.5 7219.5 7202.5 7193.5 7184.5 7178.0 7169.0 7160.5 7135.0 7123.5 7119.0 7105.0 7086.0 7069.0 7050.0 7038.0 14-APR-1998 12:26 PAGE: 4 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7031. 5 7025.5 7014.5 7007.0 7002.0 6992.0 6990.5 6973.0 6963.0 6951.0 6936.5 6929.0 6923.0 6917.0 6912.5 6903.5 6893.5 6889.5 6881.0 6872.5 6864.5 6854.0 6850.0 6841.5 6825.5 6818.0 6809.0 6801.5 6786.5 6778.5 6762.5 6752.0 6740.5 6731.5 6709.5 6675.5 6658.5 6634.0 6626.0 6608.0 6603.5 6600.5 6590.0 6588.5 6582.0 6579.5 6570.0 6556.0 6550.0 6545.5 6530.0 6511.0 6496.0 6480.5 6472.0 7031. 5 7022.5 7012.0 7007.5 7003.0 6996.0 6994.5 6973.5 6963.0 6950.5 6938.0 6928.5 6923.0 6917.5 6914. 0 6905.5 6894.5 6890.0 6882.0 6873.0 6866.0 6855.5 6851.0 6843.0 6826.5 6819.5 6812.0 6804.0 6789.0 6781.0 6764.5 6753.5 6742.5 6733.5 6711.0 6677.5 6660.5 6636.0 6628.5 6609.0 6604.0 6602.0 6590.5 6587.5 6582.5 6580.5 6569.5 6557.5 6552.5 6546.0 6531. 0 6511. 5 6496.5 6480.0 6471.0 14-APR-1998 12:26 PAGE: 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6466.5 6464.5 6451.5 6439.0 6433.0 6427.0 6420.5 6411.0 6409.0 6380.0 6360.5 6356.5 6333.0 6323.5 6310.0 6295.5 6285.5 6159.0 6147.5 6135.0 6122.5 6117.5 6117.0 6113.0 6093.5 6088.0 6081.5 6076.5 6059.5 6055.0 6053.0 6040.0 6000.5 5980.5 5957.5 5952.0 5945.0 5926.5 5910.5 5901.0 5887.0 5856.5 5850.0 5846.5 5843.5 5825.0 5818.5 5790.0 5784.5 5764.0 5744.0 5733.0 5718.0 5715.0 5702.0 6467.0 6463.0 6451.5 6436.5 6432.0 6425.0 6419.5 6411.5 6409.0 6380.5 6362.0 6358.0 6332.5 6324.5 6309.0 6296.0 6285.0 6161.5 6149.0 6136.5 6124.5 6118.0 6116.0 6112. 0 6093.0 6089.0 6080.5 6077 .5 6060.0 6055.5 6054.5 6040.5 6002.0 5982.5 5958.5 5952.5 5944.5 5927.5 5912.5 5903.0 5889.0 5858.5 5853.5 5850.0 5845.0 5826.0 5818.5 5790.5 5785.5 5764.5 5745.0 5735.0 5720.0 5716.0 5702.5 14-APR-1998 12:26 PAGE: 6 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5686.5 5680.0 5654.0 5632.0 5613.5 5574.5 5567.5 5562.5 5552.0 5546.0 5544.0 5532.5 5521.0 5505.0 5492.5 5479.5 5474.0 5467.0 5447.0 5442.5 5427.5 5416.0 5378.0 5368.5 5364.5 5357.0 5334.5 5325.0 5297.5 5286.5 5251.0 5229.0 5197.5 5172.0 5160.0 5127.5 5125.5 5121.5 5112.5 5099.0 5076.0 5016.0 5003.5 4986.0 4971.5 4941. 5 4927.5 4902.0 4860.5 4844.5 4797.0 4791. 0 4767.0 4752.5 4724.5 5686.5 5681.0 5655.5 5633.5 5615.0 5576.0 5567.0 5562.5 5554.0 5547.0 5545.5 5534.5 5521.5 5506.5 5495.0 5482.0 5475.0 5468.0 5448.5 5444.0 5429.0 5418.0 5381.0 5370.5 5365.0 5357.0 5335.5 5325.0 5299.5 5289.5 5253.5 5230.5 5198.0 5174.5 5163.0 5130.0 5127.5 5122.5 5115.0 5101.0 5078.0 5017.5 5005.0 4987.0 4971 . 5 4942.0 4928.0 4904.0 4858.5 4842.0 4794.5 4789.0 4767.0 4753.5 4724.5 14-APR-1998 12:26 PAGE: 7 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1998 12:26 PAGE: 8 4713.0 4681. 5 4675.5 4659.0 4651.0 4620.5 4605.5 4580.5 4569.5 4561. 0 4547.0 4541. 5 4504.5 4496.0 4473.5 4462.0 4432.5 4419.5 4404.5 4394.5 4385.5 4380.5 4375.0 4370.5 4360.5 4353.5 4335.0 4313.5 4298.5 4278.0 4259.5 4239.5 4213.0 4192.0 100.0 4714.5 4682.5 4676.5 4660.5 4652.5 4622.0 4605.5 4581.5 4569.5 4561.0 4547.0 4540.5 4505.5 4497.0 4474.5 4465.0 4435.0 4421.0 4406.0 4395.5 4386.5 4382.0 4377.0 4373.0 4361.0 4353.0 4336.0 4315.5 4299.5 4278.0 4259.0 4238.5 4211 . 0 4190.0 98.0 $ # MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE -------------- ----------- --------- ---------- $ # REMARKS: THIS IS THE EDITED AND CLIPPED DATA FROM THE REAL TIME MWD GR DATA. THE LOG WAS DEPTH SHIFTED TO THE PEX GR LOGGED 11-JAN-98. $ # LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1998 12:26 PAGE: 9 ** DATA FORMAT SPECIFICATION RECORD ** TYPE ** SET TYPE - 64EB ** REPR CODE ------------------------------ VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 0 0 16 1 0.5 FT 64 0 FT 68 1 0 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- PROCESS (HEX) NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE --------------------------------------------------------------------------------------- DEPT FT 00 000 00 0 1 1 .7. 4 68 0000000000 GRIN MWD AAPI 00 000 00 0 1 1 1 4 68 0000000000 ROP MWD FPHR 00 000 00 0 1 1 1 4 68 0000000000 GR AIT GAPI 00 000 00 0 1 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA DEPT. 8549.000 GRIN.MWD -999.250 ROP.MWD -999.250 GR.AIT 84.801 DEPT. 8000.000 GRIN.MWD 30.037 ROP.MWD 199.580 GR.AIT 29.541 DEPT. 7000.000 GRIN.MWD 76.211 ROP.MWD 339.594 GR.AIT 53.627 DEPT. 6000.000 GRIN.MWD 89.738 ROP.MWD 63.582 GR.AIT 41.278 DEPT. 5000.000 GRIN.MWD 144.316 ROP.MWD 70.147 GR.AIT 93.437 DEPT. 4000.000 GRIN.MWD -999.250 ROP.MWD -999.250 GR. AIT 46.214 ** END OF DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1998 12:26 PAGE: 10 FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER : EDIT .001 : FLIC : 001C01 : 98/04/14 : 1024 : LO **** FILE HEADER **** FILE NAME: EDIT. 002 SERVICE : FLIC VERSION : 001C01 DATE : 98/04/14 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0 . 5000 2 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- MWD $ 4178.0 8521.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 10-JAN-98 IDEAL 4.0C REAL-TIME 8572.0 4175.0 8572.0 80 38.5 47.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- GR $ GAMMA RAY MWD GR # LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1998 12:26 11 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE: MUD FILTRATE AT (MT): MUD CAKE AT (MT): # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: THIS IS THE RAW DATA $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 0 0 24 1 0.5 FT 42 0 FT 68 1 1 PAGE: 12.250 4169.0 WA TER BASED MUD 9.80 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-APR-1998 12:26 PAGE: 12 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 00 000 00 0 2 1 1 4 68 0000000000 GR MWD AAPI 00 000 00 0 2 1 1 4 68 0000000000 GR INT AAPI 00 000 00 0 2 1 1 4 68 0000000000 ROP5 MWD F/HR 00 000 00 0 2 1 1 4 68 0000000000 ROP5 INT F/HR 00 000 00 0 2 1 1 4 68 0000000000 VDEP MWD FT 00 000 00 0 2 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 8523.000 GR.MWD -999.250 GR.INT -999.250 ROP5.MWD -999.250 ROP5.INT 27.690 VDEP. MWD -999.250 DEPT. 8000.000 GR.MWD 50.460 GR. INT 30.037 ROP5.MWD 197.290 ROP5.INT 199.580 VDEP. MWD 6508.601 DEPT. 7000.000 GR.MWD 93.720 GR.INT 76.211 ROP5.MWD 318.940 ROP5.INT 339.594 VDEP. MWD 5815.580 DEPT. 6000.000 GR.MWD -999.250 GR.INT 89.738 ROP5.MWD 78.670 ROP5.INT 63.582 VDEP. MWD 5142.840 DEPT. 5000.000 GR.MWD -999.250 GR.INT 144.316 ROP5.MWD 67.800 ROP5.INT 70.147 VDEP. MWD 4519.540 DEPT. 4173.000 GR.MWD -999.250 GR.INT 75.700 ROP5.MWD -999.250 ROP5.INT -999.250 VDEP. MWD -999.250 END OF DATA **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER **** : EDIT. 002 : FLIC : 001C01 : 98/04/14 : 1024 : LO LIS Tape Verification Listing Schlurnberger Alaska Computing Center TAPE SERVICE NAME DATE ORIGIN TAPE NAME CONTINUATION # PREVIOUS TAPE COMMENT 14-APR-1998 12:26 TRAILER : EDIT : 98/04/14 : PLIC : 98184 : 1 : ARCO ALASKA INC., PRUDHOE BAY GNI #1, API #50-029-22845-00 REEL TRAILER SERVICE NAME: EDIT DATE : 98/04/14 ORIGIN : PLIC REEL NAME : 98184 CONTINUATION # : PREVIOUS REEL COMMENT : ARCO ALASKA INC., PRUDHOE BAY GNI #1, API #50-029-22845-00 PAGE: 13 IvIJ Date ********* *************** * ****** CENTER * COMPUTING * * ALASKA * **************** .........:::::--------------:: '-----::-SCHLUMBERGER ---:::-. :-::::_------------::::::..... - ******** *********** COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO KA INC. : ARCO ALAS I . GNI #1 ~ PRUDHOE BAY ; NORTH SLOPE . ALASKA . 500292284500 : 98031 OFllMED C¡~- ;f~ r: :tt- ~3'? \ ~j"'~ ~;:",.~},~.,~ t::: ~ ';' .' (.: ,,) 1,'PC} ~:;..:Jl .",,, ^è:, '. .\-: , / ~~~.~ '~,:~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 PAGE: 1 REEL HEADER SERVICE NAME: EDIT DATE : 98/02/11 ORIGIN : FLIC REEL NAME : 98031 CONTINUATION # : PREVIOUS REEL COMMENT : ARCO ALASKA INC, GNI #1, PRUDHOE BAY, API #50-029-22845-00 TAPE HEADER **** SERVICE NAME: EDIT DATE : 98/02/11 ORIGIN : FLIC TAPE NAME : 98031 CONTINUATION # : 1 PREVIOUS TAPE COMMENT : ARCO ALASKA INC, GNI #1, PRUDHOE BAY, API #50-029-22845-00 TAPE HEADER Prudhoe Bay OPEN HOLE WIRELINE LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: GNI #1 500292284500 ARCO Alaska, Inc. SCHLUMBERGER WELL 10-FEB-98 SERVICES # JOB DATA RUN 1 RUN 2 RUN 3 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 98031 H.KIRKBY S WHIPP # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 26 UN 15E 4206 964 56.60 55.10 29.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ------------- --------- ---------- 1ST STRING 2ND STRING 12.250 13.375 4169.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 PAGE: 2 3RD STRING PRODUCTION STRING # REMARKS: CONTAINED HEREIN IS THE LDWG AQUIRED ON ARCO ALASKA'S GNI $ $ FORMATTED OPEN HOLE DATA #1 WELL. **** FILE HEADER FILE NAME : EDIT. 001 SERVICE : FLIC VERSION : 001C01 DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; Depth DEPTH INCREMENT: 0.5000 # FILE SUMMARY LDWG TOOL CODE shifted and clipped curves; all runs merged; no cased hole data. START DEPTH STOP DEPTH -------------- ----------- ---------- AIT DAS CNT SDN $ 8558.0 8536.0 8539.0 8552.0 4183.0 4176.0 4176.0 4176.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ----------EQUIVALENT UNSHIFTED DEPTH---------- AIT DAS CNT SDN BASELINE DEPTH -------------- $ # MERGED DATA SOURCE LDWG TOOL CODE RUN NO. PASS NO. MERGE TOP MERGE BASE -------------- -------- --------- ---------- DAS DAS $ 1 2 1 1 8326.0 4176.0 8536.0 8326.0 # REMARKS: THIS FILE CONTAINS THE EDITED OPEN HOLE DATA. THE DATA WAS CLIPPED OF INVALID READINGS AT FIRST READING AND AT CASING POINT. THE DIPOLE SONIC DATA WAS AQUIRED OVER TWO PASSES AND SPLICED AT 8326' MD. THE DAS DTSH & DT CURVES WERE RELABLED AT THE GEOQUEST COMPUTING CENTER. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center # LIS FORMAT DATA 11-FEB-1998 09:19 PAGE: 3 ** DATA FORMAT SPECIFICATION RECORD ** TYPE ** SET TYPE - 64EB ** REPR CODE ------------------------------ VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 0 0 112 1 0.5 FT 9 0 FT 68 1 0 ------------------------------ ** SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1209212 00 000 00 0 1 1 1 4 68 0000000000 SP AIT MV 1209212 00 000 00 0 1 1 1 4 68 0000000000 CNTC CNT CPS 1209212 00 000 00 0 1 1 1 4 68 0000000000 CFTC CNT CPS 1209212 00 000 00 0 1 1 1 4 68 0000000000 CRAT CNT 1209212 00 000 00 0 1 1 1 4 68 0000000000 NRAT CNT 1209212 00 000 00 0 1 1 1 4 68 0000000000 FCNT CNT CPS 1209212 00 000 00 0 1 1 1 4 68 0000000000 NCNT CNT CPS 1209212 00 000 00 0 1 1 1 4 68 0000000000 DEV SDN DEG 1209212 00 000 00 0 1 1 1 4 68 0000000000 NPHI CNT PU-S 1209212 00 000 00 0 1 1 1 4 68 0000000000 CPHI CNT PU-S 1209212 00 000 00 0 1 1 1 4 68 0000000000 CALl SDN IN 1209212 00 000 00 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 1209212 00 000 00 0 1 1 1 4 68 0000000000 PEF SDN BN/E 1209212 00 000 00 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 1209212 00 000 00 0 1 1 1 4 68 0000000000 MINV SDN OHMM 1209212 00 000 00 0 1 1 1 4 68 0000000000 MNOR SDN OHMM 1209212 00 000 00 0 1 1 1 4 68 0000000000 MSFL SDN OHMM 1209212 00 000 00 0 1 1 1 4 68 0000000000 AF10 AIT OHMM 1209212 00 000 00 0 1 1 1 4 68 0000000000 AF20 AIT OHMM 1209212 00 000 00 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlurnberger Alaska Computing Center 11-FEB-1998 09:19 PAGE: 4 --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) --------------------------------------------------------------------------------------- AF30 AIT OHMM 1209212 00 000 00 0 1 1 1 4 68 0000000000 AF60 AIT OHMM 1209212 00 000 00 0 1 1 1 4 68 0000000000 AF90 AIT OHMM 1209212 00 000 00 0 1 1 1 4 68 0000000000 DT DAS US/F 1209212 00 000 00 0 1 1 1 4 68 0000000000 DTSH DAS US/F 1209212 00 000 00 0 1 1 1 4 68 0000000000 TENS DAS LB 1209212 00 000 00 0 1 1 1 4 68 0000000000 GR DAS GAPI 1209212 00 000 00 0 1 1 1 4 68 0000000000 SCRA DAS 1209212 00 000 00 0 1 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- DATA DEPT. 8558.000 SP.AIT -999.250 CNTC. CNT -999.250 CFTC.CNT -999.250 CRAT. CNT -999.250 NRAT. CNT -999.250 FCNT.CNT -999.250 NCNT. CNT -999.250 DEV. SDN -999.250 NPHI.CNT -999.250 CPHI.CNT -999.250 CALI. SDN -999.250 DRHO.SDN -999.250 PEF.SDN -999.250 RHOB.SDN -999.250 MINV. SDN -999.250 MNOR. SDN -999.250 MSFL.SDN -999.250 AF10.AIT 2.500 AF20.AIT 2.797 AF30.AIT 2.885 AF60. AIT 3.020 AF90.AIT 3.138 DT. DAS -999.250 DTSH.DAS -999.250 TENS.DAS -999.250 GR.DAS -999.250 SCRA.DAS -999.250 DEPT. 4176.000 SP.AIT -2.500 CNTC. CNT 1251.897 CFTC.CNT 331.773 CRAT. CNT 4.037 NRAT. CNT 3.870 FCNT. CNT 352.990 NCNT. CNT 1305.364 DEV. SDN 42.096 NPHI.CNT 48.905 CPHI.CNT 44.676 CALI. SDN 12.438 DRHO.SDN 1.324 PEF.SDN 10.000 RHOB.SDN 4.338 MINV. SDN 0.077 MNOR. SDN 0.099 MSFL.SDN 0.105 AF10.AIT -999.250 AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT -999.250 AF90.AIT -999.250 DT. DAS 127.701 DTSH.DAS 300.238 TENS.DAS 2658.000 GR.DAS 39.261 SCRA.DAS 2.351 ** END OF DATA ** **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER **** : EDIT. 001 : FLIC : 001C01 : 98/02/11 : 1024 : LO LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-FEB-1998 09:19 PAGE: 5 FILE HEADER FILE NAME: EDIT. 002 SERVICE : FLIC VERSION : 001COl DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUMMARY LDWG TOOL CODE curves for open hole logs run into casing. START DEPTH STOP DEPTH -------------- ----------- ---------- DAS CNT $ 4176.0 4176.0 3587.0 3634.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ----------EQUIVALENT DAS CNT UNSHIFTED DEPTH---------- BASELINE DEPTH -------------- $ # REMARKS: THIS FILE CONTAINS THE CASED HOLE EDITED DATA. THE DATA WAS CLIPPED AT CASING AND ALSO CLIPPED OF INVALID DATA AFTER LAST READING. THE DIPOLE SONIC DT & DTSH CURVES WERE RELABELED AT THE GEOQUEST COMPUTING CENTER. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 3 4 66 66 73 66 0 0 56 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center II-FEB-1998 09:19 PAGE: 6 ------------------------------ TYPE REPR CODE VALUE ------------------------------ 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) --------------------------------------------------------------------------------------- DEPT FT 1209212 00 000 00 0 2 1 1 4 68 0000000000 CNTC CNT CPS 1209212 00 000 00 0 2 1 1 4 68 0000000000 CFTC CNT CPS 1209212 00 000 00 0 2 1 1 4 68 0000000000 CRAT CNT 1209212 00 000 00 0 2 1 1 4 68 0000000000 NRAT CNT 1209212 00 000 00 0 2 1 1 4 68 0000000000 FCNT CNT CPS 1209212 00 000 00 0 2 1 1 4 68 0000000000 NCNT CNT CPS 1209212 00 000 00 0 2 1 1 4 68 0000000000 NPHI CNT PU-S 1209212 00 000 00 0 2 1 1 4 68 0000000000 CPHI CNT PU-S 1209212 00 000 00 0 2 1 1 4 68 0000000000 DT DAS US/F 1209212 00 000 00 0 2 1 1 4 68 0000000000 DTSH DAS US/F 1209212 00 000 00 0 2 1 1 4 68 0000000000 TENS DAS LB 1209212 00 000 00 0 2 1 1 4 68 0000000000 GRCH DAS GAPI 1209212 00 000 00 0 2 1 1 4 68 0000000000 SCRA DAS 1209212 00 000 00 0 2 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 4176.000 CNTC.CNT 1251.897 CFTC.CNT 331.773 CRAT. CNT 4.037 NRAT. CNT 3.870 FCNT.CNT 352.990 NCNT. CNT 1305.364 NPHI.CNT 48.905 CPHI.CNT 44.676 DT. DAS 127.701 DTSH.DAS 300.238 TENS. DAS 2658.000 GRCH. DAS 39.261 SCRA.DAS 2.351 DEPT. 3587.000 CNTC.CNT -999.250 CFTC.CNT -999.250 CRAT. CNT -999.250 NRAT. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT -999.250 NPHI.CNT -999.250 CPHI.CNT -999.250 DT. DAS 130.384 DTSH.DAS 289.638 TENS. DAS 2504.000 GRCH.DAS 22.403 SCRA.DAS 2.221 END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 PAGE: 7 FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER : EDIT .002 : FLIC : 001C01 : 98/02/11 : 1024 : LO FILE HEADER FILE NAME : EDIT. 003 SERVICE : FLIC VERSION : 001C01 DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fa Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- AIT DSI PEX $ 8582. 0 8582.0 8582.0 4176.0 4176.0 4176.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): ll-JAN-98 8CO-069 1800 10-JAN-98 600 ll-JAN-98 8572.0 8570.0 3587.0 8570.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 8 AIT CNL GR DSI $ ARRAY INDUCTION COMPENSATED NEUTRON GAMMA RAY DIPOLE SONIC # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # PAGE: AITH HRCC-B 847 HRGD 842 DSST-B 12.250 4169.0 4176.0 WATER 9.90 55.0 8.8 5.3 BASED MUD 2.120 67.0 2.000 67.0 2.700 67.0 THERMAL SANDSTONE 2.65 1.5 Two standoffs used on the AITH Bowspring on Neutron for eccentralization This is a primary depth control log Nine standoffs run on DSI REMARKS: THIS FILE CONTAINS THE RAW OH DATA FOR 0.5' SAMPLE RATE TOOLS, CLIPPED AT CASING. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 66 66 0 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 PAGE: 9 TYPE ------------------------------ VALUE REPR CODE ------------------------------ 3 4 5 6 7 8 9 11 12 13 14 15 16 0 73 66 66 73 65 68 65 66 68 66 65 66 66 66 80 1 0.5 FT 12 0 FT 68 1 1 ------------------------------ ** SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1209212 00 000 00 0 3 1 1 4 68 0000000000 TENS AIT LB 1209212 00 000 00 0 3 1 1 4 68 0000000000 SP AIT MV 1209212 00 000 00 0 3 1 1 4 68 0000000000 CNTC PEX CPS 1209212 00 000 00 0 3 1 1 4 68 0000000000 CFTC PEX CPS 1209212 00 000 00 0 3 1 1 4 68 0000000000 TNRA PEX 1209212 00 000 00 0 3 1 1 4 68 0000000000 GR AIT GAPI 1209212 00 000 00 0 3 1 1 4 68 0000000000 RTNR PEX 1209212 00 000 00 0 3 1 1 4 68 0000000000 RCFT PEX CPS 1209212 00 000 00 0 3 1 1 4 68 0000000000 RCNT PEX CPS 1209212 00 000 00 0 3 1 1 4 68 0000000000 DEVI PEX DEG 1209212 00 000 00 0 3 1 1 4 68 0000000000 NPHI PEX PU 1209212 00 000 00 0 3 1 1 4 68 0000000000 TNPH PEX PU 1209212 00 000 00 0 3 1 1 4 68 0000000000 NPOR PEX PU 1209212 00 000 00 0 3 1 1 4 68 0000000000 DTCO DSI US/F 1209212 00 000 00 0 3 1 1 4 68 0000000000 DTSM DSI US/F 1209212 00 000 00 0 3 1 1 4 68 0000000000 TENS DSI LB 1209212 00 000 00 0 3 1 1 4 68 0000000000 GR DSI GAP I 1209212 00 000 00 0 3 1 1 4 68 0000000000 RSHC DSI 1209212 00 000 00 0 3 1 1 4 68 0000000000 PR DSI 1209212 00 000 00 0 3 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 8582.000 TENS.AIT 2723.000 SP.AIT -9.000 CNTC.PEX 1995.529 CFTC.PEX 802.721 TNRA.PEX 2.526 GR.AIT 84.801 RTNR.PEX 2.664 RCFT.PEX 759.186 RCNT.PEX 1985.293 DEVI.PEX -999.250 NPHI.PEX 31.196 TNPH.PEX 24.432 NPOR.PEX 23.994 DTCO.DSI 96.096 DTSM.DSI -999.250 TENS.DSI -999.250 GR.DSI -999.250 RSHC. DSI -999.250 PR.DSI -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 PAGE: 10 DEPT. CFTC.PEX RCFT. PEX TNPH.PEX TENS.DSI 4176.000 331. 773 352.990 44.676 2658.000 TENS. AIT TNRA. PEX RCNT. PEX NPOR.PEX GR.DSI 2488.000 4.037 1305.364 41.749 39.261 SP.AIT GR.AIT DEVI.PEX DTCO.DSI RSHC.DSI -2.500 27.752 42.096 127.701 2.351 CNTC. PEX RTNR.PEX NPHI.PEX DTSM.DSI PR.DSI 1251.897 3.870 48.905 300.238 0.390 END OF DATA **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER **** : EDIT .003 : FLIC : 001C01 : 98/02/11 : 1024 : LO FILE HEADER **** FILE NAME : EDIT. 004 SERVICE : FLIC VERSION : 001C01 DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 4 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- AIT $ 8582.0 4176.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: 11-JAN-98 8CO-069 1800 10-JAN-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center II-FEB-1998 09:19 11 TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ---------------- --------- AIT $ ARRAY INDUCTION # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # PAGE: 600 II-JAN-98 8572.0 8570.0 3587.0 8570.0 TOOL NUMBER ----------- AITH 12.250 4169.0 4176.0 WATER 9.90 55.0 8.8 5.3 BASED MUD 2.120 67.0 2.000 67.0 2.700 67.0 THERMAL SANDSTONE 2.65 1.5 Two standoffs used on the AITH Bowspring on Neutron for eccentralization This is a primary depth control log Nine standoffs run on DSI THIS FILE CONTAINS THE RAW OH DATA FOR 0.25' SAMPLE RATE TOOLS, CLIPPED AT CASING. REMARKS: $ # LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** I1-FEB-1998 09:19 PAGE: 12 TYPE REPR CODE ------------------------------ VALUE ------------------------------ 1 66 2 66 3 73 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 0 0 48 1 0.25 FT 21 0 FT 68 1 1 ** SET TYPE - CHAN ** ------------------------------ --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1209212 00 000 00 0 4 1 1 4 68 0000000000 AIBD AIT IN 1209212 00 000 00 0 4 1 1 4 68 0000000000 ATI0 AIT OHMM 1209212 00 000 00 0 4 1 1 4 68 0000000000 AT20 AIT OHMM 1209212 00 000 00 0 4 1 1 4 68 0000000000 AT30 AIT OHMM 1209212 00 000 00 0 4 1 1 4 68 0000000000 AT60 AIT OHMM 1209212 00 000 00 0 4 1 1 4 68 0000000000 AT90 AIT OHMM 1209212 00 000 00 0 4 1 1 4 68 0000000000 AFI0 AIT OHMM 1209212 00 000 00 0 4 1 1 4 68 0000000000 AF20 AIT OHMM 1209212 00 000 00 0 4 1 1 4 68 0000000000 AF30 AIT OHMM 1209212 00 000 00 0 4 1 1 4 68 0000000000 AF60 AIT OHMM 1209212 00 000 00 0 4 1 1 4 68 0000000000 AF90 AIT OHMM 1209212 00 000 00 0 4 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. AT30.AIT AF20.AIT 8582.000 2.173 2.145 AIBD.AIT AT60.AIT AF30.AIT END OF DATA 3.890 ATI0.AIT 2.267 AT90.AIT 2.140 AF60.AIT 2.272 AT20.AIT 2.584 AFI0.AIT 2.282 AF90.AIT 2.145 2.273 2.580 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-FEB-1998 09:19 PAGE: 13 FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER : EDIT .004 : FLIC : 001COl : 98/02/11 : 1024 : LO **** FILE HEADER FILE NAME : EDIT. 005 SERVICE : FLIC VERSION : 001COl DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 5 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- PEX $ 8582.0 4176.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): ll-JAN-98 8CO-069 1800 10-JAN-98 600 Il-JAN-98 8572.0 8570.0 3587.0 8570.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- CNL $ COMPENSATED NEUTRON HRCC-B 847 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 14 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # PAGE: 12.250 4169.0 4176.0 WA TER 9.90 55.0 8.8 5.3 BASED MUD 2.120 67.0 2.000 67.0 2.700 67.0 THERMAL SANDSTONE 2.65 1.5 Two standoffs used on the AITH Bowspring on Neutron for eccentralization This is a primary depth control log Nine standoffs run on DSI THIS FILE CONTAINS THE RAW OH DATA FOR 0.1667' SAMPLE RATE TOOLS, CLIPPED AT CASING. REMARKS: $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 3 4 5 6 7 66 66 73 66 66 73 65 0 0 64 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 PAGE: 15 ------------------------------ TYPE REPR CODE VALUE ------------------------------ 8 68 0.166 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1209212 00 000 00 0 5 1 1 4 68 0000000000 HDRA PEX G/C3 1209212 00 000 00 0 5 1 1 4 68 0000000000 PEFZ PEX 1209212 00 000 00 0 5 1 1 4 68 0000000000 RHOZ PEX G/C3 1209212 00 000 00 0 5 1 1 4 68 0000000000 HMIN PEX OHMM 1209212 00 000 00 0 5 1 1 4 68 0000000000 HMNO PEX OHMM 1209212 00 000 00 0 5 1 1 4 68 0000000000 RXOZ PEX OHMM 1209212 00 000 00 0 5 1 1 4 68 0000000000 RX08 PEX OHMM 1209212 00 000 00 0 5 1 1 4 68 0000000000 HCNT PEX CPS 1209212 00 000 00 0 5 1 1 4 68 0000000000 HCFT PEX CPS 1209212 00 000 00 0 5 1 1 4 68 0000000000 HGR PEX GAPI 1209212 00 000 00 0 5 1 1 4 68 0000000000 RHFT PEX CPS 1209212 00 000 00 0 5 1 1 4 68 0000000000 RHNT PEX CPS 1209212 00 000 00 0 5 1 1 4 68 0000000000 DPHZ PEX PU 1209212 00 000 00 0 5 1 1 4 68 0000000000 HTNP PEX PU 1209212 00 000 00 0 5 1 1 4 68 0000000000 HNPO PEX PU 1209212 00 000 00 0 5 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 8582.000 HDRA.PEX -999.250 PEFZ.PEX -999.250 RHOZ.PEX -999.250 HMIN. PEX 2.254 HMNO.PEX 2.331 RXOZ.PEX 2.325 RX08.PEX 2.521 HCNT. PEX 1995.529 HCFT.PEX 802.721 HGR.PEX 84.801 RHFT. PEX 759.186 RHNT.PEX 1985.293 DPHZ.PEX 60721.211 HTNP.PEX 24.432 HNPO.PEX 23.994 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-FEB-1998 09:19 PAGE: 16 FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER : EDIT. 005 : FLIC : OOlCOl : 98/02/11 : 1024 : LO FILE HEADER **** FILE NAME : EDIT. 006 SERVICE : FLIC VERSION : OOlCOl DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 6 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.0833 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- PEX $ 8582.0 4176.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 11-JAN-98 8CO-069 1800 10-JAN-98 600 11-JAN-98 8572.0 8570.0 3587.0 8570.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- CNL $ COMPENSATED NEUTRON HRCC-B 847 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 17 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # PAGE: 12.250 4169.0 4176.0 WATER 9.90 55.0 8.8 5.3 BASED MUD 2.120 67.0 2.000 67.0 2.700 67.0 THERMAL SANDSTONE 2.65 1.5 Two standoffs used on the AITH Bowspring on Neutron for eccentralization This is a primary depth control log Nine standoffs run on DSI REMARKS: THIS FILE CONTAINS THE RAW OH DATA FOR O. 0833' SAMPLE RATE TOOLS, CLIPPED AT CASING. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 ------------------------------ TYPE REPR CODE VALUE PAGE: 18 ------------------------------ 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) --------------------------------------------------------------------------------------- DEPT FT 1209212 00 000 00 0 6 1 1 4 68 0000000000 HCAL PEX IN 1209212 00 000 00 0 6 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- DATA DEPT. END OF DATA **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE 8582.000 HCAL.PEX 3.890 TRAILER **** : EDIT. 006 : FLIC : 001C01 : 98/02/11 : 1024 : LO **** FILE HEADER **** FILE NAME : EDIT. 007 SERVICE : FLIC VERSION : 001C01 DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE: LO LAST FILE LIS Tape Verification Listing Schlumberger Alaska Computing Center PAGE: 11-FEB-1998 09:19 FILE HEADER FILE NVMBER 7 RAW OPEN HOLE REPEAT PASSES Curves and log header data RUN NVMBER: 1 TOOL STRING NVMBER: 1 PASS NVMBER: 1 DEPTH INCREMENT: 0 . 5000 19 for each pass, tool string, and run in separate files. # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- AIT DSI PBX $ 8508.0 8201.0 8508.0 8179.0 7869.5 8179.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ---------------- --------- AIT CNL GR DSI $ ARRAY INDUCTION COMPENSATED NEUTRON GAMMA RAY DIPOLE SONIC # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): ll-JAN-98 8CO-609 1800 10-JAN-98 600 ll-JAN-98 8572.0 8570.0 3587.0 8570.0 TOOL NUMBER ----------- AITH HRCC-B 847 HRGD 842 DSST-B 12.250 4169.0 4176.0 WATER 9.90 55.0 8.8 BASED MUD 2.120 67.0 2.000 67.0 2.700 67.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # II-FEB-1998 09:19 PAGE: 20 THERMAL SANDSTONE 2.65 1.5 Two standoffs used on the AITH Bowspring on Neutron for eccentralization This is a primary depth control log Nine standoffs run on DSI REMARKS: THIS FILE CONTAINS THE RAW OH REPEAT DATA FOR TOOLS AT 0.5' SAMPLE RATE. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE ------------------------------ VALUE ------------------------------ 1 66 2 66 3 73 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 0 0 80 1 0.5 FT 12 0 FT 68 1 1 ** SET TYPE - CHAN ** ------------------------------ --------------------------------------------------------------------------------------- PROCESS (HEX) NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE --------------------------------------------------------------------------------------- DEPT FT 1209212 00 000 00 0 7 1 1 4 68 0000000000 TENS AIT LB 1209212 00 000 00 0 7 1 1 4 68 0000000000 SP AIT MV 1209212 00 000 00 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing 11-FEB-1998 09:19 PAGE: 21 Schlumberger Alaska Compu ting Center --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- CNTC PEX CPS 1209212 00 000 00 0 7 1 1 4 68 0000000000 CFTC PEX CPS 1209212 00 000 00 0 7 1 1 4 68 0000000000 TNRA PEX 1209212 00 000 00 0 7 1 1 4 68 0000000000 GR AIT GAPI 1209212 00 000 00 0 7 1 1 4 68 0000000000 RTNR PEX 1209212 00 000 00 0 7 1 1 4 68 0000000000 RCFT PEX CPS 1209212 00 000 00 0 7 1 1 4 68 0000000000 RCNT PEX CPS 1209212 00 000 00 0 7 1 1 4 68 0000000000 DEVI PEX DEG 1209212 00 000 00 0 7 1 1 4 68 0000000000 NPHI PEX PU 1209212 00 000 00 0 7 1 1 4 68 0000000000 TNPH PEX PU 1209212 00 000 00 0 7 1 1 4 68 0000000000 NPOR PEX PU 1209212 00 000 00 0 7 1 1 4 68 0000000000 TENS DSI LB 1209212 00 000 00 0 7 1 1 4 68 0000000000 PR DSI 1209212 00 000 00 0 7 1 1 4 68 0000000000 RSHC DSI 1209212 00 000 00 0 7 1 1 4 68 0000000000 DTSM DSI US/F 1209212 00 000 00 0 7 1 1 4 68 0000000000 DTCO DSI US/F 1209212 00 000 00 0 7 1 1 4 68 0000000000 GR DSI GAPI 1209212 00 000 00 0 7 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA DEPT. 8508.000 TENS.AIT 4574.000 SP.AIT 40.938 CNTC.PEX 2091.652 CFTC.PEX 880.315 TNRA. PEX 2.413 GR.AIT 57.866 RTNR.PEX 2.545 RCFT.PEX 829.613 RCNT.PEX 2079.664 DEVI.PEX -999.250 NPHI.PEX 29.479 TNPH.PEX 22.793 NPOR.PEX 22.392 TENS.DSI -999.250 PR.DSI -999.250 RSHC.DSI -999.250 DTSM.DSI -999.250 DTCO.DSI -999.250 GR.DSI -999.250 DEPT. 7869.500 TENS. AIT -999.250 SP.AIT -999.250 CNTC.PEX -999.250 CFTC.PEX -999.250 TNRA. PEX -999.250 GR.AIT -999.250 RTNR.PEX -999.250 RCFT.PEX -999.250 RCNT. PEX -999.250 DEVI.PEX -999.250 NPHI.PEX -999.250 TNPH.PEX -999.250 NPOR.PEX -999.250 TENS.DSI 4164.000 PR.DSI 0.362 RSHC.DSI 2.152 DTSM.DSI 191.914 DTCO.DSI 96.445 GR.DSI 44.163 END OF DATA ** **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER **** : EDIT .007 : FLIC : 001C01 : 98/02/11 : 1024 : LO LIS Tape Verification Listing Schlumberger Alaska Computing Center FILE HEADER FILE NAME : EDIT. 008 SERVICE : FLIC VERSION : 001C01 DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 8 RAW OPEN HOLE REPEAT PASSES Curves and log header data RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 11-FEB-1998 09:19 PAGE: 22 for each pass, tool string, and run in separate files. # FILE SUMMARY VENDOR TOOL CODE START DEPTH ---------------- ----------- AIT DSI PEX $ 8508.0 8201.0 8508.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ---------------- --------- AIT CNL GR DSI $ STOP DEPTH ---------- 8179.0 7869.5 8179.0 ARRAY INDUCTION COMPENSATED NEUTRON GAMMA RAY DIPOLE SONIC # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS ll-JAN-98 8CO-609 1800 10-JAN-98 600 ll-JAN-98 8572.0 8570.0 3587.0 8570.0 TOOL NUMBER ----------- AITH HRCC-B 847 HRGD 842 DSST-B 12.250 4169.0 4176.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 23 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # REMARKS: PAGE: WATER 9.90 55.0 8.8 BASED MUD 2.120 67.0 2.000 67.0 2.700 67.0 THERMAL SANDSTONE 2.65 1.5 Two standoffs used on the AITH Bowspring on Neutron for eccentralization This is a primary depth control log Nine standoffs run on DSI THIS FILE CONTAINS THE RAW OH REPEAT DATA FOR TOOLS AT 0.25' SAMPLE RATE. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 2 66 3 73 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 0 0 48 1 0.25 FT 21 0 FT 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 PAGE: 24 ------------------------------ TYPE REPR CODE VALUE ------------------------------ 16 0 66 66 1 1 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) --------------------------------------------------------------------------------------- DEPT FT 1209212 00 000 00 0 8 1 1 4 68 0000000000 AIBD AIT IN 1209212 00 000 00 0 8 1 1 4 68 0000000000 AT10 AIT OHMM 1209212 00 000 00 0 8 1 1 4 68 0000000000 AT20 AIT OHMM 1209212 00 000 00 0 8 1 1 4 68 0000000000 AT30 AIT OHMM 1209212 00 000 00 0 8 1 1 4 68 0000000000 AT60 AIT OHMM 1209212 00 000 00 0 8 1 1 4 68 0000000000 AT90 AIT OHMM 1209212 00 000 00 0 8 1 1 4 68 0000000000 AF10 AIT OHMM 1209212 00 000 00 0 8 1 1 4 68 0000000000 AF20 AIT OHMM 1209212 00 000 00 0 8 1 1 4 68 0000000000 AF30 AIT OHMM 1209212 00 000 00 0 8 1 1 4 68 0000000000 AF60 AIT OHMM 1209212 00 000 00 0 8 1 1 4 68 0000000000 AF90 AIT OHMM 1209212 00 000 00 0 8 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA DEPT. 8508.000 AIBD.AIT 3.913 ATlO.AIT 2.527 AT20.AIT 2.404 AT30.AIT 2.408 AT60.AIT 2.448 AT90.AIT 2.664 AF10.AIT 2.527 AF20.AIT 2.405 AF30.AIT 2.385 AF60. AIT 2.463 AF90.AIT 2.659 DEPT. 8178.750 AIBD.AIT 13.313 AT10.AIT 3.608 AT20.AIT 3.580 AT30.AIT 3.552 AT60. AIT 3.292 AT90.AIT 3.266 AF10.AIT 3.546 AF20.AIT 3.495 AF30.AIT 3.408 AF60.AIT 3.294 AF90.AIT 3.262 END OF DATA **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER **** : EDIT. 008 : FLIC : 001C01 : 98/02/11 : 1024 : LO LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 25 FILE HEADER FILE NAME : EDIT. 009 SERVICE : FLIC VERSION : 001C01 DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 9 RAW OPEN HOLE REPEAT PASSES Curves and log header data RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: O. 1667 PAGE: for each pass, tool string, and run in separate files. # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- PEX $ 8508.0 8179.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ---------------- --------- AIT CNL GR DSI $ ARRAY INDUCTION COMPENSATED NEUTRON GAMMA RAY DIPOLE SONIC # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): ll-JAN-98 8CO-609 1800 10-JAN-98 600 ll-JAN-98 8572.0 8570.0 3587.0 8570.0 TOOL NUMBER ----------- AITH HRCC-B 847 HRGD 842 DSST-B 12.250 4169.0 4176.0 WATER BASED MUD 9.90 LIS Tape Verification Listing Schlumberger Alaska Computing Center II-FEB-1998 09:19 PAGE: 26 MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # 55.0 8.8 2.120 67.0 2.000 67.0 2.700 67.0 THERMAL SANDSTONE 2.65 1.5 Two standoffs used on the AITH Bowspring on Neutron for eccentralization This is a primary depth control log Nine standoffs run on DSI THIS FILE CONTAINS THE RAW OH REPEAT DATA FOR TOOLS AT 0.1667' SAMPLE RATE. REMARKS: $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 0 FT 68 1 1 0 0 64 1 0.166 FT 16 LIS Tape Verification Listing 11-FEB-1998 09:19 PAGE: 27 Schlumberger Alaska Compu t ing Center ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1209212 00 000 00 0 9 1 1 4 68 0000000000 HDRA PEX G/C3 1209212 00 000 00 0 9 1 1 4 68 0000000000 PEFZ PEX 1209212 00 000 00 0 9 1 1 4 68 0000000000 RHOZ PEX G/C3 1209212 00 000 00 0 9 1 1 4 68 0000000000 HMIN PEX OHMM 1209212 00 000 00 0 9 1 1 4 68 0000000000 HMNO PEX OHMM 1209212 00 000 00 0 9 1 1 4 68 0000000000 RXOZ PEX OHMM 1209212 00 000 00 0 9 1 1 4 68 0000000000 RX08 PEX OHMM 1209212 00 000 00 0 9 1 1 4 68 0000000000 HCNT PEX CPS 1209212 00 000 00 0 9 1 1 4 68 0000000000 HCFT PEX CPS 1209212 00 000 00 0 9 1 1 4 68 0000000000 HGR PEX GAPI 1209212 00 000 00 0 9 1 1 4 68 0000000000 RHFT PEX CPS 1209212 00 000 00 0 9 1 1 4 68 0000000000 RHNT PEX CPS 1209212 00 000 00 0 9 1 1 4 68 0000000000 DPHZ PEX PU 1209212 00 000 00 0 9 1 1 4 68 0000000000 HTNP PEX PU 1209212 00 000 00 0 9 1 1 4 68 0000000000 HNPO PEX PU 1209212 00 000 00 0 9 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- DATA DEPT. 8508.000 HDRA.PEX -999.250 PEFZ.PEX -999.250 RHOZ.PEX -999.250 HMIN.PEX 3.602 HMNO.PEX 3.589 RXOZ.PEX 4.434 RX08.PEX 4.466 HCNT. PEX 2091.652 HCFT.PEX 880.315 HGR.PEX 57.866 RHFT. PEX 829.613 RHNT. PEX 2079.664 DPHZ.PEX 60721.211 HTNP.PEX 22.793 HNPO.PEX 22.392 DEPT. 8178.667 HDRA.PEX -0.005 PEFZ.PEX 2.599 RHOZ.PEX 2.421 HMIN.PEX 3.275 HMNO.PEX 2.547 RXOZ.PEX 2.534 RX08.PEX 3.071 HCNT. PEX 2507.751 HCFT. PEX 830.523 HGR.PEX 72.398 RHFT.PEX 694.397 RHNT. PEX 2400.276 DPHZ.PEX 13.875 HTNP.PEX 32.471 HNPO.PEX 32.214 ** END OF DATA ** **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER **** : EDIT. 009 : FLIC : 001C01 : 98/02/11 : 1024 : LO LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 28 FILE HEADER FILE NAME : EDIT. 010 SERVICE : FLIC VERSION : 001C01 DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 10 RAW OPEN HOLE REPEAT PASSES Curves and log header data RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.0833 # PAGE: for each pass, tool string, and run in separate files. FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- PEX $ 8508.0 8179.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ---------------- --------- AIT CNL GR DSI $ ARRAY INDUCTION COMPENSATED NEUTRON GAMMA RAY DIPOLE SONIC # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 11-JAN-98 8CO-609 1800 10-JAN-98 600 ll-JAN-98 8572.0 8570.0 3587.0 8570.0 TOOL NUMBER ----------- AITH HRCC-B 847 HRGD 842 DSST-B 12.250 4169.0 4176.0 WATER BASED MUD 9.90 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 29 MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # PAGE: 55.0 8.8 2.120 67.0 2.000 67.0 2.700 67.0 THERMAL SANDSTONE 2.65 1.5 Two standoffs used on the AITH Bowspring on Neutron for eccentralization This is a primary depth control log Nine standoffs run on DSI THIS FILE CONTAINS THE RAW OH REPEAT DATA FOR TOOLS AT 0.0833' SAMPLE RATE. REMARKS: $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 0 FT 68 1 1 0 0 8 1 0.083 FT 128 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-FEB-1998 09:19 PAGE: 30 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) --------------------------------------------------------------------------------------- DEPT FT 1209212 00 000 00 0 10 1 1 4 68 0000000000 HCAL PEX IN 1209212 00 000 00 0 10 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- DATA DEPT. 8508.000 HCAL.PEX 3.913 END OF DATA FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER : EDIT. 010 : FLIC : 001COl : 98/02/11 : 1024 : LO FILE HEADER FILE NAME : EDIT. 011 SERVICE : FLIC VERSION : 001C01 DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE: LO LAST FILE FILE HEADER FILE NUMBER 11 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- PEX DSI 4176.0 4176.0 3608.0 3565.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-FEB-1998 09:19 31 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ---------------- --------- AIT CNL GR DSI $ ARRAY INDUCTION COMPENSATED NEUTRON GAMMA RAY DIPOLE SONIC # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): # PAGE: ll-JAN-98 8CO-069 1800 10-JAN-98 600 ll-JAN-98 8572.0 8570.0 3587.0 8570.0 TOOL NUMBER ----------- AITH HRCC-B 847 HRGD 842 DSST-B 12.250 4169.0 4176.0 WATER 9.90 55.0 8.8 BASED MUD 2.120 67.0 2.000 67.0 2.700 67.0 THERMAL SANDSTONE 2.65 1.5 Two standoffs used on the AITH Bowspring on Neutron for eccentralization This is a primary depth control log Nine standoffs run on DSI REMARKS: THIS FILE CONTAINS THE RAW CH MAIN DATA FOR LIS Tape Verification Listing Schlumberger Alaska Computing Center # LIS FORMAT DATA 0.5' SAMPLING RATE. $ II-FEB-1998 09:19 PAGE: 32 ** DATA FORMAT SPECIFICATION RECORD ** TYPE ** SET TYPE - 64EB ** REPR CODE ------------------------------ VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 0 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 0 0 72 1 0.5 FT 14 0 FT 68 1 1 ------------------------------ ** SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1209212 00 000 00 0 11 1 1 4 68 0000000000 TENS AIT LB 1209212 00 000 00 0 11 1 1 4 68 0000000000 CNTC PEX CPS 1209212 00 000 00 0 11 1 1 4 68 0000000000 CFTC PEX CPS 1209212 00 000 00 0 11 1 1 4 68 0000000000 TNRA PEX 1209212 00 000 00 0 11 1 1 4 68 0000000000 GR PEX GAPI 1209212 00 000 00 0 11 1 1 4 68 0000000000 RTNR PEX 1209212 00 000 00 0 11 1 1 4 68 0000000000 RCFT PEX CPS 1209212 00 000 00 0 11 1 1 4 68 0000000000 RCNT PEX CPS 1209212 00 000 00 0 11 1 1 4 68 0000000000 NPHI PEX PU 1209212 00 000 00 0 11 1 1 4 68 0000000000 TNPH PEX PU 1209212 00 000 00 0 11 1 1 4 68 0000000000 NPOR PEX PU 1209212 00 000 00 0 11 1 1 4 68 0000000000 DTCO DSI US/F 1209212 00 000 00 0 11 1 1 4 68 0000000000 DTSM DSI US/F 1209212 00 000 00 0 11 1 1 4 68 0000000000 TENS DSI LB 1209212 00 000 00 0 11 1 1 4 68 0000000000 GR DSI GAPI 1209212 00 000 00 0 11 1 1 4 68 0000000000 RSHC DSI 1209212 00 000 00 0 11 1 1 4 68 0000000000 PR DSI 1209212 00 000 00 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 PAGE: 33 --------------------------------------------------------------------------------------- DATA DEPT. 4176.000 TENS.AIT 2488.000 CNTC. PEX 1251.897 CFTC.PEX 331.773 TNRA. PEX 4.037 GR.PEX 27.752 RTNR. PEX 3.870 RCFT.PEX 352.990 RCNT.PEX 1305.364 NPHI.PEX 48.905 TNPH.PEX 44.676 NPOR.PEX 41. 749 DTCO.DSI 127.701 DTSM.DSI 300.238 TENS.DSI 2658.000 GR.DSI 39.261 RSHC. DSI 2.351 PR.DSI 0.390 DEPT. 3565.000 TENS.AIT -999.250 CNTC.PEX -999.250 CFTC.PEX -999.250 TNRA.PEX -999.250 GR.PEX -999.250 RTNR. PEX -999.250 RCFT.PEX -999.250 RCNT. PEX -999.250 NPHI.PEX -999.250 TNPH.PEX -999.250 NPOR.PEX -999.250 DTCO.DSI -999.250 DTSM.DSI -999.250 TENS.DSI -999.250 GR.DSI -999.250 RSHC. DSI -999.250 PR.DSI -999.250 END OF DATA **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER : EDIT. 011 : FLIC : 001C01 : 98/02/11 : 1024 : LO **** FILE HEADER **** FILE NAME: EDIT. 012 SERVICE : FLIC VERSION : 001C01 DATE : 98/02/11 MAX REC SIZE: 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 12 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- PEX 4176.0 3608.167 LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-FEB-1998 09:19 34 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL ( FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ---------------- --------- AIT CNL GR DSI $ ARRAY INDUCTION COMPENSATED NEUTRON GAMMA RAY DIPOLE SONIC # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): PAGE: 11-JAN-98 8CO-069 1800 10-JAN-98 600 11-JAN-98 8572.0 8570.0 3587.0 8570.0 TOOL NUMBER ----------- AITH HRCC-B 847 HRGD 842 DSST-B 12.250 4169.0 4176.0 WATER BASED MUD 9.90 55.0 8.8 2.120 67.0 2.000 67.0 2.700 67.0 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TAPE SERVICE NAME DATE ORIGIN TAPE NAME CONTINUATION # PREVIOUS TAPE COMMENT 11-FEB-1998 09:19 PAGE: 35 TRAILER : EDIT .012 : FLIC : 001C01 : 98/02/11 : 1024 : LO TRAILER : EDIT : 98/02/11 : FLIC : 98031 : 1 : ARCO ALASKA INC, GNI #1, PRUDHOE BAY, API #50-029-22845-00 REEL TRAILER **** SERVICE NAME: EDIT DATE : 98/02/11 ORIGIN : FLIC REEL NAME : 98031 CONTINUATION # : PREVIOUS REEL COMMENT : ARCO ALASKA INC, GNI #1, PRUDHOE BAY, API #50-029-22845-00