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Home My WebLink About189-117 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~ //--7 Nu er o, We,, PAGES TO DELETE RESCAN ~'~olor items - Pages: [] Grayscale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DAT~A ~Diskettes, No~.~.j~ [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Bevedy Br~Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Bren Vincent~h~ Lowell by • n BP Exploration (Alaska) Inc. April 16, 2002 � O�r� 900 East Benson Boulevard WOO t P.O. Box 196612 Anchorage, Alaska 99519 -6612 (907) 561 -5111 Mr. Thomas Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 _ v i '" A: 9 :, lfl 7 Site Closure: Badami No.1 (PTD 189 -117) `'i'` and Badami No. 2 (PTD 191 -144) Alaska 0;1 & Gas Lens. �rrll ;ss(la . Anchorage Dear Mr. Maunder: Conoco Inc. (Conoco) transferred its Alaskan assets to BP (Exploration) Alaska Inc (BPXA) in 1994. As part of this transfer, BPXA assumed responsibility for the above - named exploration sites. The Alaska Oil and Gas Conservation Commission (AOGCC) has not been able to confirm location closure for the Conoco Badami No. 1 and No. 2 exploration wells, according to a letter sent to John Skopak, Conoco, from Blair Wondzell, AOGCC, dated November 30, 2000. In review of the Badami files, we have located information that confirms the closure of the Conoco Badami No. 2 well site (PTD 191 -144). We also have supporting information to confirm closure of the Conoco Badami No. 1 Well reserve pit. However, we have not found conclusive evidence the repair to the subsided area around the well was completed. We recommend a site visit to determine the status of the Badami #1 well site during the summer of 2002 with representatives from BPXA, AOGCC, and possibly other agencies. Following the site visit, BPXA will provide a rehabilitation plan (if necessary) for agency approval and work towards a satisfactory closure of the site. We have attached copies of the supporting information to this letter. This information is also summarized below. Badami No. 1 (PTD 188 -117) The November 30, 2000 letter to John Skopak, Conoco, indicated the Badami No.1 well was inspected by AOGCC in August 1994. The inspector noted a depression around the wellhead and an open reserve pit. A September 1994 letter to Mr. Zseleczky, BPXA, reported the depression to be 8 to 12 feet wide by 2 to 4 feet deep around the well location. The following revegetation report indicates the reserve pit has been backfilled S:\HSE\Permitting\Badami\Badami 1 and 2 Closure.doc • . Mr. Thomas Maunder, AOGCC April 16, 2002 Badami Nos. 1 and 2 Closure Page 2 and revegetated with color plates confirming. However, the color plates (presented on page 8 and 9) also show the possibility of a depression around the well. • Evaluation of Vegetation Establishment on Badami No. 1 Exploratory Wellsite, North Slope, Alaska (1999) prepared January 2000 (revised March 6, 2000) by Lazy Mountain Research. This report summarizes the results of a three -year revegetation attempt at the Badami #1 well site. The exploratory permit required a 30% vegetation cover on the reserve pit, which had been capped with local soil. This is the final report satisfy U.S. Army Corps of Engineers and Alaska Department of Natural Resources requirements. Badami #2 (PTD 191 -144) The November 30, 2000 letter to John Skopak, Conoco, indicated the Badami No. 2 well was "drilled from an ice island; because we have no documentation to confirm that there is no junk or equipment on the sea floor, the sea floor needs to be surveyed." The following is provided by copy to help show proper and complete location closure: • Approved Application for Sundry Approval to Abandon the well, dated 4/02/1992 • Conoco abandoned the well April 13, 1992 and submitted a Well Completion Report and Log to AOGCC. A few representative log entries (paraphrased) are listed below showing Conoco made every effort to properly close the Badami #2 well site. 0 4/14/1992 — cut casing and pull casing strings — release rig 0 4/15/1992 — clear liner, timbers, rig mats, etc. from site 0 4/16 & 4/17/ 1992 — operations shutdown due to weather 0 4/18/1992 — opened ice road to location 0 5/19/1992 — Dig up well cellar and clear location. Trim 6' of ice off pad. Retrieve all road reflectors from ice access road. End of Project. • Completion Report, for Land Use Permit LAS 13446 (Badami #2). In this report Conoco states, "Before final abandonment of the project site, all structures and facilities were removed, all debris was picked up, and all of the road markers and flags were retrieved." From the above, BPXA is confident the Badami No. 1 reserve pit and the Badami No. 2 well site were closed in accordance with 20 AAC 25. If you have any questions, please contact me at (907) 564 -4592 or Karen Wuestenfeld at (907) 564 -5490. We would be available to meet with you to discuss well closure at your convenience. Sincerely, 4 -1n4./vi k-41A4 O. — Shana Kane, Permitting Advisor HSE- Alaska S:\HSE\Permitting\Badami\Badami 1 and 2 Closure.doc • • Mr. Thomas Maunder, AOGCC April 16, 2002 Badami Nos. 1 and 2 Closure Page 3 cc.: (w/ attachments) John Skopak, Conoco, Inc. Attachments: Evaluation of Vegetation Establishment on Badami No. 1, 3/06/00 — revised Approved Application for Sundry Approval to Abandon Badami No. 2 Well Completion Report and Log for Badami No. 2 Completion Report submitted by Conoco to ADNR -Lands dated 5/21/92 S: \HSE\Permitting\Badami\Badami 1 and 2 Closure.doc • • ter' EVALUATION OF VEGETATION ESTABLISHMENT I ON BADAMI NO. 1 EXPLORATORY WELLSITE, NORTH SLOPE, ALASKA (1999) 0. I _ rJ'' m if • ,� - 7^ - 4 , 131 , � .r . m s ; . e rf s' ' 1 ' /s,\ ¢ r le.: to ,,, ___<,, t l-✓. b m r r ,L° Idti T4 ^` . 1 ' y p 0,° _'S + h� ! f ` mo t - : + i m v * 'a .. ! .. R , IX 14- tom- • rte -A .. X - , l + f.+ ♦kta . ..,- - •4 y+ _ '41. h `0 (P '' f `� . • y � ,` '� � Ato' G . ° ' � fi x ' : '''4 ' 1 jY . y ta'\ ,, "� 4. ' ; : ma y ^ a _ • i X {... • l` t 043 E A.\ "'4 d am S � , ti N . ° T. ' s... 4, r � ` F — • - F t y ' _J i ,w� .. .. : . te r' .. -, ' C '!. ei -- rt Y ,l. 1 A REPORT T0: BP EXPLORATION (ALASKA), INC. 1 ANCHORAGE, ALASKA 1 � � 1 FROM: �� E , JAY D. MCKENDRICK p- D 9 v 2O 2 LAZY MOUNTAIN RESEARCH 1 PALMER, ALASKA Alaska Olt & Gas Cons. Co1'i{ini Anchorage I 14 JANUARY 2000 REVISED 6 MARCH 2000 i 1 • • C I axe I Front cover: Ptarmigan nesting under standing dead of Descurainia hio'des among plant r and s g g g f sop i mo g pl t late prang growth of Cochlearia officinalis on a south facing slope of the Badami No 1 reserve pit mound d= fir: I • • III revegetation objective was to be achieved b SUMMARY objective by relying as much as possible on natural species and 1 After two revegetation attempts and four growing minimal applications of seed and fertilizer. The seasons, vegetation canopy on the Badami No. 1 1996 seeding consisted of an array of native plant reserve pit cap attained a cover of 33.2 % by the species, whose seeds had been harvested from end of the 1999 growing season. The renegotiated various sites on the North Slope for the Long -term permit requirements between BP Exploration Gravel Revegetation Project (McKendrick, et al., (Alaska), Inc. and the US Army Corps ofEngineers 1992). Plant colonization was judged to be I in 1996 were to achieve 20 -30% canopy cover in proceeding too slowly in 1997, and in 1998, three years. Cover suddenly increased from 6% in Puccinellia arctica seed and 10 -20 -20 fertilizer 1998 to over 30% in 1999 as a response to were applied. Canopy cover, plant densities, and I fertilizer, seeding Puccinellia arctica, and species present were measured on the site annually maturing and reproduction by plants colonized on during the 1996 -99 monitoring period. Repeat the mound of soil. The largest contributor (10 %) photography was used to document changes in the II to the canopy cover came from Cochlearia site's appearance through time. This is a report of officinalis, a small indigenous member of the the findings of monitoring at this site during 1999. mustard family. This species commonly occurs I along the seashore in this region. It is tolerant of saline soil conditions. Its common name is `scurvy- BACKGROUND grass,' because it was once relied upon by sailors I as a source of vitamin C following long voyages. Conoco, Inc. drilled the Badami exploratory well in The next most important contributors were 1989 -90. In January 1994, BP Exploration Descurainia sophioides (4.8 %), Puccinellia (Alaska), Inc. (BPX) acquired the oil field lease arctica (4.6 %), and Puccinellia langeana (4.0 %), from Conoco. The exploratory permit required a all indigenous species to the region, with 30% vegetation cover on the reserve pit, which had Descurainia and Puccinellia arctica having been been capped with local soil following drilling. By introduced to the site in seed applications in 1996 1996, the vegetation cover was still less than 5 %, I and 1998, respectively. Descurainia sophioides is and below permit stipulations. After negotiations also a member of the mustard plant family. between BPX and the US Army Corps ofEngineers (USACE), it was agreed that revegetation of the I Soil salinity, dryness and harsh weather are factors reserve pit cap should rely on indigenous plant i largely controlling vegetation establishment on this species and achieve: site. All of the predominant plant species I established at this site are tolerant of saline soils. • 5 percent decrease in bare ground in the first In spite of these less favorable soil and weather year conditions, vascular plants are continuing to invade • a positive rate of plant growth in the next two I. and reproduce on this site. Ptarmigan, Arctic years ground squirrel, caribou, and geese frequent the • 20 - 30 percent cover after 3 years (by 1999) site. It is expected the current positive trend in I vegetation establishment will continue. The Based on those requirements a revegetation and appearance of the site has also improved over the monitoring plan was designed to assist plant 1996 -99 monitoring period with most of that establishment and record those changes on the site. occurring in 1999. Canopy cover was still only 6% by the end of the 1998 growing season. INTRODUCTION Site Location and Conditions The 1999 growing season was the third since Badami No. 1 is located at N70° 09' 05"; W147° assisted revegetation was first attempted (1996) at 05' 20 ", about 26 miles east of the Prudhoe Bay oil I the Badami No. 1 exploration site. The field complex. It is the easternmost oil production 1 1 • • i facility on the Alaska North Slope. The plant species were used. The monitoring method 1 exploratory wellsite is situated just east of the was designed to record plant cover, density and Badami Production Facility pad, near the seacoast aspect changes through time. 1 in flat wet sedge meadow tundra. The reserve pit is north of the exploratory well and was excavated Assisted Revegetation below grade. Drilling wastes were deposited into The 1996 seed and fertilizer applications were 1 the reserve pit, and approximately 3,800 cubic designed for a 7,000 ft area, based on information yards of overburden was used to cover the pit. The prior to going to the field. The actual area was bare area was estimated to be approximately more than twice the estimate. Windy weather 16,400 ft in size (McKendrick, 1999). conditions on 9 July 1996 caused some loss of seed, a decidedly negative factor considering the Rhizomatous sedges are the predominant vascular seed and fertilizer applications were already 1 plants in the community. Low growth forms of the undersized for the area being treated. Based on willow (Salix planifolia ssp. pulchra var. pulchra) limited progress in plant establishment in 1996 and is the largest shrub in the vicinity. Lichens are 1997, it was decided to add seed of another native 1 relatively insignificant in the tundra. Natural soils grass, Puccinellia arctica, and more fertilizer in are medium textured alluvium over gravel. A peat 1998. This was accomplished 15 July 1998. The accumulation approximately 6 inches in thickness soil surface was raked to incorporate seed and 1 caps the profile. Undisturbed soils remain fertilizer into the soil. Despite precautions, the saturated during the growing season, owing to raking undoubtedly removed some plants already permafrost perching and the accumulation of peat, established on the reserve pit cap. 1 which has a high water holding capacity. Subsoils very likely contain salts, due to influences from the Monitoring Vegetation nearby ocean. Monitoring began in 1996 by establishing plots and 1 The reserve pit cap is much drier than the photopoints. The plant canopy cover was measured surrounding soils, and thus presents a habitat very using the walking point method (Owensby, 1973). different from that before exploratory drilling Five north to south transects consisting of 50 points each were read in 1998 and 1999. Twenty- 1 occurred. The climate is strongly influenced by the five square plots (0.25 m were staked with 5/8- ocean and ice cap. Northeasterly winds from off inch rebar in opposite corners, and plants in each the ocean affect the local weather. The weather is plot were inventoried annually 1996 -99. Two cooler than that at Deadhorse, delaying plant cam era points were staked in 1996, and photos phenology at Badami behind that for plants in the taken each year 1996 through 1999. Each year the Prudhoe Oil Field. Fog is common when the ocean site was examined, a listing of vascular plants 1 is open during summer. Caribou seek insect relief in the vicinity during the summer, and can often be present was compiled. observed standing on the elevated mound covering 1 the reserve pit. Arctic ground squirrel are attracted to the dry soil and burrow into it. Ptarmigan create Total canopy cover in 1998 was 6% dust beds in the dry soil, and one bird was found Total canopy cover in 1999 was 32% 1 nesting on the site in June of 1999 (cover photo). Geese and caribou graze plants on the mound, particularly borealis, young grasses and RESULTS 1 sedges. Plant Canopy Cover METHODS Total canopy cover in 1998 was 6 %, and 32% in 1 1999 (Table 1). Minor species differed in the cover Revegetation assistance was confined to minimal data between 1998 and 1999; however, the most use of fertilizer and seed. Only seeds of indigenous prominent species were the same. Cochlearia 1 2 1 I o t sophioides were the or about 24% of the total canopy in 1999, the first officinalis P two largest components of the canopy cover both year following its seeding. 1 years. Puccinellia arctica produced 7.6% cover, I Table 1. Sununary of 1998 and 1999 vascular plant canopy cover data from five walking point transects (50 points/transect) on the Badami No. 1 reserve pit cap. 1999 transect total hits out of 50 possible points read on five transects 1999 1999 Cover 1998 Cover 1 Plant Species Totals Percentages; ! Percentages by species by species by species 1 2 3 4 5 1 1 Arctagrostis latifolia 1 1 0.4 - 0.4 Artemisia borealis 1 1 0 4 ; 0.4 I Carex aquatilis cinalis and D es c urainia so 0.4 Cochlearia officinalis 11 2 5 1 6 25 10.0 1.2 I Descurainia sophioides 7 4 1 12 4.8' 0.8 Dupontia fisheri R 0.4 I Phippsia algida 2 2 • 0 8 Poa arctica 1 1 2 ,t,4, 0 8`: Puccinellia arctica 1 8 1 6 3 19 A '? 6' Puccinellia langeana 3 3 4 10 4.0, 0.4 Puccinellia phryganoides 1 1 4 0 . 4 Stellaria spp. 1 1 2 z 0.8. Standing Dead 3 1 1 5 • a 2 0 .` 1.6 ,I Transect Totals 22 23 9 11 15 80 Transect Percentages 44.0 46.0 18.0 22.0 30.0 32 0 6.0 I Plant Density 11 Total plant densities increased from 9 to 191 60% of the plant population on the reserve pit plants /m during the 1996 through 1999 mound in 1999. ' monitoring period (Table 2). Grass shoots (clumps I for caespitose growth forms) increased from 7 to Species Present 98 per square meter during the same period. Fobs Species to the species lists (Table 3) the total increased from about 2 plants /m in 1996, to 108 in number of species increased from 20 to as much as I 1998, and 92 in 1999. Cochlearia officinalis 32 in 1998, and to 26 in 1999. Increases occurred produced the greatest density (64/m overall in in both graminoid and forb growth forms. Shrubs 1999, followed by Puccinellia arctica (47 were not a significant component of this plants /m These two species accounted for nearly community. I j tiYl i 3 j • • 1 I 1 I Table 2. Plant density data by year from 1996 through 1999 in 0.25 m 2 plots on Badami No. 1 reserve pit cap. Plant Species Years I 1996 I 1997 I 1998 I 1999 Graminoids Arctagrostis latifolia 2.56 5.44 16.80 19.36 Carex/Eriophorum .16 .16 2.08 0.48 Dupontia fisheri 0.64 3.20 .16 11.84 Festuca baffinensis 0.96 Festuca vivipara .16 .16 Grass seedling 4.16 8.00 I Phippsia algida 2.72 4.32 4.96 8.96 Poa arctica 1.12 2.72 8.48 0.16 Puccinellia arctica 46.56 Puccinellia phryganoides .16 .16 .16 is Puccinellia langeana .16 2.40 1.28 Totals 7.52 16.32 39.20 97.60 Forbs Artemisia borealis .16 .16 .64 1.92 Astragalus alpinus .16 ii Braya purpurascens .80 .96 17.12 11.36 Cochlearia offtcinalis .64 .48 88.64 6432 Descurainia sophioides .16 1.92 14.4 Oxytropis boreale .16 .16 Totals 1.6 1.76 108.48 92.32 Grand Totals 9.12 18.08 147.68 190.92 1 1 1 1 1 4 1 • • I I Table 3. Listing ofvascular plant species found on Badami No. 1 reserve pit cap during 1996, 1998, and 1999. 1 Plant Species I 1996 I 1998 I 1999 I Graminoids (grasses and sedges) Alopecurus alpinus Seeded 1996 ✓ ✓ Arctagrostis latifolia ✓ ✓ ✓ I Carex aquatilis ✓ V ✓ Carex maritima ✓ Deschampsia caespitosa ✓ - Dupontia fisheri ✓ ✓ ✓ I Eriophorum an. ustifolium ✓ ✓ ✓ Festuca baffinensis ✓ ✓ ✓ Juncus spp. ✓ Phippsia al&ida ✓ ✓ ✓ Poa arctica ✓ ✓ ✓ Poa Rlauca ✓ Puccinellia arctica Seeded 1998 ✓ I Puccinellia lanReana Seeded 1996 ✓ ✓ ✓ Puccinellia phryQanoides ✓ ✓ ✓ Trisetum spicatum Seeded 1996 ✓ Graminoid Subtotal 9 13 13 I Forbs (broadleaved herbaceous plant) Artemisia borealis Seeded 1996 ✓ ✓ ✓ Astragalus alpinus Seeded 1996 ✓ ✓ Braga purpurascens Seeded 1996 ✓ ✓ ✓ Cardamine hyperborea ✓ ✓ Cerastium berinRianum ✓ ✓ I Cochlearia officinalis ✓ ✓ ✓ Descurainia sophioides Seeded 1996 ✓ ✓ Draba sop. ✓ ✓ Epilobium latifolium ✓ ✓ I Melandrium apetalum ✓ ✓ ✓ Minuartia rubella ✓ Oxytropis borealis Seeded 1996 ✓ ✓ Papaver spp. ✓ ✓ ✓ Polygonum viviparum ✓ ✓ Saxifraga oppositifolia ✓ ✓ Senecio congestus Seeded 1996 ✓ ✓ Stellaria longipes ✓ ✓ ✓ Forb Subtotal 10 17 12 Shrubs (broadleaved woody plants) I Salix glauca ✓ Salix ovalifolia ✓ ✓ ✓ Shrub Subtotal 1 2 1 1 Total Vascular Plant Species 20 32 26 1 I i • • 1 1 DISCUSSION AND OBSERVATIONS Soils (Figure 1). The perennial Brayapurpurascens was I The influence of salts on soil on the reserve pit was natural to the site and also included in the 1996 apparent as precipitate on the surface. This was seed mixture (Figure 2). Its population has most obvious at the southeast and northwest increased during the monitoring period, expanding 1 margins. Phippsia algida, often an indicator of from 0.8 to 11 plants/m2 Another mustard, saline soil conditions, was the dominant plant at the Descurainia sophioides, has affected the overall northwest margin of the mound. Origin of these aspect of the site by producing conspicuous tall 1 salts was not determined. Some are believed to growth (Figure 3). This biennial species was have originated from natural sources in subsoil introduced to the site in the 1996 seed mixture. It layers. Some may have originated in drilling developed basal rosettes in the summer of 1997. 1 wastes. The distribution is uneven, indicating that These matured in 1998 and produced a seed crop, both sources may have contributed to the condition. which resulted in more basal rosettes establishing Regardless of the source, it is fortunate the in 1999 (Figure 3). Thus, its population increased 1 condition is limited in extent. On the southeast from zero in 1996 to 14 plants /m by the end of the margin, much of the soil remained entirely bare, 1999 growing season. This particular plant species and apparently too saline for any species to was also seeded in 1996 at the Sequoia test well 1 colonize. Chunks of natural peat are mixed in the site southwest of Deadhorse, where it produced a overburden. When these occur on the surface, they remarkable canopy cover and significantly dry out and are poor habitats for plant colonization. benefited other plant species and ground squirrels 1 If the chunks are buried, they do not dry out and (McKendrick, 1999b). Draba macrocarpa is can contribute to plant rooting medium. The another member of the mustard family found on the mound is relatively dry, particularly on the south Badami site (Figure 3). Though a common and southwest slopes. In spite of that condition, perennial in the region on saline and dry sites, plants seemed to grow better on those slopes, Draba contributed less to the canopy cover and perhaps because they were somewhat sheltered -plant population than its cousins on the Badami from the cold northeast wind and warmed by the reserve pit cap. sun. Because the soil is drier than that of the surroundings, this site is not expected to produce a Members of the Compositae family are typically plant community similar to the undisturbed for an important colonizers on barren soils, partially indefinite period. It has the potential for owing to the easy dispersal of their seeds by wind. supporting the type of plants found on the well- Two members of that family at Badami No. 1 were drained margins of rivers and creeks in the vicinity. Senecio congestus and Artemisia borealis. Both 1 There are indications that strong winds have were included in the 1996 seed application. gradually removed soil fines. This probably occurs s Senecio first appeared in the species listing in during the winter and when the soil is driest. 1998. We cannot be certain whether or not that Consequently, establishing a plant cover is invasion was directly related to the 1996 seeding, desirable to limit that erosion. or if by natural processes. Artemisia (Figure 4) was present on the site in 1996. Its population was 1 Vegetation unchanged in the density data until 1998, when it Plants on the reserve pit mound consisted mostly of suddenly increased. This perennial appears to be indigenous pioneer species. That was consistent relatively long -lived and it develops slowly, with the revegetation objective of relying on natural requiring several years to achieve sexual maturity. species to vegetate the barren soil. The prominence Perhaps the recent increase in Artemisia plants on of salt- tolerant species conformed with the the site resulted from seed we applied, or may have 1 apparent soil salinity. The mustard (Cruciferae) resulted from reproduction by individuals already family is prominently represented in the cover and established in 1996. In 1998, the mature plant plant density data by Cochlearia officinalis shown in Figure 4 was just producing seed for the 1 6 1 1 • • first time and was most likely 3 -4 years of age. in 1998. From this seeding, a population averaging The immature plant shown in Figure 4 is in its nearly 47 plants /m established on the site between 1 second growing season, based on the single set of July 1998 and August 1999 (Table 2 and Figure 5). dead leaves at the base. That meant the seed This produced marked changes in the appearance germinated either late in 1996 or early 1997, of the site (Figure 6). Even though the young possibly a product of our first seed application. seedlings were grazed, they produced an acceptable Artemisia borealis is especially valued as forage canopy. This open stand of grass should provide by caribou. cover and protect the site and not interfere with invasion by other plant species. Grasses have been the plants most commonly used for revegetation over the years. This has been true Recolonization of barren sites in the Arctic occurs I on the Alaska North Slope, even though species of very gradually over time. Due to the absence of grass used are uncommon in the natural wet sedge annuals that produce copious quantities of seed, tundra complex. There are several reasons to use barren areas in the Arctic are typically invaded by I grasses for revegetation: perennials. Perennials expend their resources primarily on vegetative reproduction, rather than • Technology for producing, harvesting, producing large amounts of seed, especially in the threshing, and applying grass seed is well Arctic. Recolonization of bare areas in the Arctic I developed, coming from a long history of actually takes about the same time (25 -30 years) as j agricultural forage and pasture production as it does for a pine forest to form on abandoned I well as the turf industry. fields in the Piedmont region (Odum, 1959). The Arctic lacks the matrix of annuals to fill in spaces • Grasses are often aggressive, developing among the developing perennials, giving the quickly and produce masses of fibrous roots, appearance that little progress in plant occupation I which hold soil against erosion. is occurring. The photo on the inside back cover of this report shows a disperse array of perennial • A large array of grass species exist, providing a plants developing in a partially drained lake basin, I wide range of types suited to many between Badami and Prudhoe Bay. Each green environments. colony is the product of a single plant that established and expanded vegetatively outward to I However, the aggressive growth which favors form the circular pattern. In time those colonies will grasses for revegetation can also make them less coalesce and produce a solid wet meadow stand. desirable for tundra reestablishment, when those That same process of a few individuals establishing I grasses interfere with establishing other plant on open ground is occurring on the Badami No. 1 species desired for a particular site. Thus, grasses reserve pit. These few perennials are gradually that are easily established, but short- lived, are spreading by vegetative and sexual reproduction I probably better for tundra revegetation needs at the across the reserve pit cap. By adding Puccinellia present. Puccinellia arctica appears to be within arctica in 1998, we filled spaces among these that group. The species occurs naturally established plants, added to the canopy cover, and IIII throughout the Arctic and boreal regions of Alaska, improved appearance of the mound. The additional primarily in disturbed and/or slightly saline plant cover also protects the soil and benefits habitats. It appears to be a poor competitor with wildlife. other plants, unless the habitat is marginal for those other plants. It is a bunchgrass. Among the Wildlife various ecotypes tested there is significant Wildlife habitat is an important aspect in variability in growth form, adaptation, seed rehabilitating disturbed sites and revegetation on 1 production, and palatability to grazers. Four wildlands. That is true for the Alaska North Slope. ecotypes of Puccinellia arctica were applied to The most obvious animals in the area are caribou separate portions of the Badami reserve pit mound and geese that invade the vicinity during the 1 • • t I - . 4,..4..." F T -, — = . .. w y. < , ,_ - 'ctdT '� '�i'�Z T ` � } +htira`- -� •��,�5 • 4 � • h 'u i' - �' ` 4 t 2 -' r . - - , '4 a4 ,, �' vF ice^ .,_ a -°t `, - -u. i E:..:. - 1-' - r :: 1 ;' .- - 1 4 -i ) t . i > • 1� ; - � . ! t`' f'� 44.- . , Z 9 July 1996 0 .. .T.--Nf:,-X,-'-"' ,;. - '"" " *.t-'4Wi-4--7-1 , - ,.. . ''''. -,,---. xi' --..,:'-' 4- ', c'ff: ',.:-. --. _--- -, ',....,-.. ,,,,- :-!'- i ;--' - ' -.. .-: . ': , - ,'--' :-- :'- _:-.., '- ",: - - _ -'-7 .. - :_13" 7- - -,- ,__,: r .:::; - : : ::= ' ," : ::,, - .: - ',.---,.-: ' :5-' 7 , 7 - 2 71-::: :::::::- : -. '-' - --_- - .. ,---:: :,_ -._ ` - 2 t . . - „ , yx . . - - > . r:: -"`` ..�e , —... , ,,-,-. ; --.1-, f.f 3. om,.• ? .`l4'^” fS�"b Y� 5. tt} -) _tzrz Cc,: --, * ."-- ;:‘ - -_ -.-• ,.. -,...-...,....1. ..-.., - -, . ,,,,,L . :', ,,, ,_ , : :1 :, . . 5' 3 r dR -w 1:. y 't alt �.,, a'' "� .x 3.y ,, �. r •, :.g .1• � - '"tile . s c �w --t • '5 ::';:--f'''':-7-';: . '^.5 .,;� "` xx� <°� -ti.�+. � `" 's ue �. " �t � . ,,, * ay. Y "r te=• 3t R ` •.4` - ' .* y r.`+ v 50, FM,. k.-7.4:.,.. .." - ..- - -, - -1".. --- .- , Z irt_ H , s, " -: ft.^. ;.;_..., -..... .... .1 ..,. ,'V""•, ..- i 'N - 7::: , ,..: i..‘ -., ‘. ..... 7.....; ^!!'�cta::::'1 . .t_ . _S`'r.. r i , -? •�.�Z'.;a�.• .''' it t V " , ::...Y,. s,K -- .,a.,.. - . '�_.a.:, d 31 July 1997 j Figure 1. Four repeat photos south across reserve pit cap toward exploratory well marker from photopoint no. 1 at Badami No. 1 wellsite. This page 1996, 1997; facing page 1998, 1999. i 0 8 • • I I :‘.4"7.-'74 ` , x •TMs' " aR -�" .- a _ , `�."` " ` gy"""p ,R . r 4- 0 I : ...- t t r . '.. , ,•,. , _, .i ,. R ter' <r % - y l z i r R f I 15 July 1998 0 _ - , , ,,,,,,,,,,r,,,,k,7,,F=7, . .y--- ._ � - -` a - - ' \ a ten} v • -; - 30 August 1999 1 9 I • • I O eft " '-- i ,- - 1 = • n ts v . - t,1 i iv.," a b .... ■ sag °i�1 -f. -"' - - ' , °� � Vii: .t ` s ' d .a n 1/ ,,...„4- ' ,'''' .4 '•••-• ,• -.`` 7 ` - - ,e0 4. - , . k ,. ,s._) - °“. ...s... - 4 : `", - s ° � w _ � 4 • '' °�- �' bi . Cochlearia officinalis ' ' $ ,,...-ii. i �r - t o '�' y5 ME ,{ �" Rr '..ft�'. j r . _ip .J •r _. . 2*- - -;e...--. J. ` II , C • a r • , + - - - ! 3 - L../ -e _. s R Y e! � - .,ate ? ¢ p w ■ } X a r ♦ f � ice, +_;,+ • t M A - .' 'r ° "*. 'P ..,•• ,e i' • 3:3S Braya purpurascens Figure 2. (Upper) Cochlearia officinalis flowering on the Badami No. 1 reserve pit cap, 6 August 1998; (Lower) Braya purpurascens in bud stage on the Badami No. 1 reserve pit cap, 23 June 1999. 10 • • I • I -.. _ � I ' _ Descurainia � � � < I � ` . � sophio "' 4 I lY py"tQ YE k w .. •3: d� d - a . � 3 • . <' et, P4 - r _t I I W . T y I � T 1 �@6. + Y 7 .7 y -� .. Draba 17 4k... - ° • . i ��f a macrocarpa Q ' "'��° > , f III I c r •i t Ar + Figure 3. (Upper) First year basal rosette of Descurainia sophioides, 6 August 1998; (Lower) Draba macrocarpa in seed maturing stage, 6 August 1998. I 11 I i • - '- I . , .t ' 4 � r ', -:--1..-'+‘' '•'-F i2 R� ., 4 t r. y ^Y 'i '4 f 2� y � � 8 s y i yy t f'..� •. %7; 4-# ';.,.. * ma y," ' . i � . 3 ' v a', - , . S tom. .....s • a 7 .. .- f P •:I F • t i yy �.. ' may j x i.' . $ III / f lt4` e -i { a • R • X • Y s r R O 0. • -..� .. ♦ + - r ,.+ . S o - " � °w • : R t ` f � .* :.. ° - fig , d Y :: o *e r E I 3 - v o y Artemisia borealis (two views) 0 . _ - t - x a - . , 4 s i . A. I . . ,�;�' *•` �& - -}rte - - S d • ..+ t i--- r I Figure 4. (Upper) Artemisia borealis second ye of grow, June 1999. (Lower) Artemisia borealis in third or f ou rth year ar of growth, 6 A 2 u3 1998. th 12 1 J • • growing season. However, denizens on site year food, and the standing dead provided a certain around are the ptarmigan, Arctic ground squirrel, amount of camouflage for the nesting ptarmigan I and other small mammals. Perhaps more than any pictured on the cover of this report. We have other, these animals have benefited from the habitat regularly found ptarmigan in the vicinity. There dryness and vegetation on this site. Descurainia were 13 present on 30 August 1999, when I I sophioides seeds are harvested by squirrels for sampled the vegetation. s ' i i tit, l Y . f I . I s m , E is t ' , 1 ' `s! fi t - �' > O I ; 2 , le 13.' r _ �.. Puccinellia arctica I Figure 5. Puccinellia arctica seedlings 23 June 1999. Seed was applied July 1998. I CONCLUSIONS I Vascular plant canopy cover in 1999 exceeded margin remains largely barren. The type of plants 30 %, reaching the negotiated permit stipulations, on the site differ from the adjacent community within three years. Vegetation on the site is heavily because of habitat dryness. That difference is I influenced by members of the mustard family and expected to continue for an undetermined number recently by Puccinellia arctica, which was seeded of years. However, there are indigenous plant in 1998. Canopy cover, plant densities, species list species in the region suited to those conditions. I over time, and repeat photos all confirm there is a Those are anticipated to eventually invade. positive trend for plants on this site overall. Two Regardless of the vegetation that eventually small areas appear to be influenced by soil salinity. develops, some species of wildlife, particularly One of these on the northwest has been invaded by ptarmigan and Arctic ground squirrel will continue salt tolerant plants. The one on the southeast using the site. I , I 13 I S • I ' ...,..T:-,,:-.:-=-1,-.44-, V 3sf .fin a .ece`am'_ �. -c _ _ mar Y T ii Figure 6. (1) View west from center of Badami No. 1 reserve pit mound, 15 July 1998, at the time Puccinellia arctica seed was applied. (R) Same view 30 August 1999 showing the open stand of Puccinellia arctica grass I established from seed applied 15 July 1998. Tall plants are second year stage of Descurainia sophioides. I ACKNOWLEDGEMENTS Appreciation is expressed to individuals who have helped with this project, including: Joe Serra and Neil Hermon, Jr., Badami HSE, and the Badami camp support personnel; Christopher J. Herlugson and Michelle Gilders, both former Anchorage BPX HSE. BPX summer hires Tess Carr and Erica Herlugson assisted in arranging logistics, in 1996 and 1997. Dan Cooley and Bill Baker (Badami HSE summer hires) helped carry fertilizer to the site and raked in seed and fertilizer in 1998. Dan McKendrick and Peter C. Scorup helped apply seed and fertilizer in 1998 and recorded data during vegetation sampling. Steve McKendrick assisted I with inventorying the site in 1999. BPX funded the project and provided logistical support in transporting personnel, supplies and equipment between Deadhorse and Badami. Puccinellia arctica seed was purchased from Northern Native Seeds in Palmer, AK. Conce Rock and Dave Trudgen (Anchorage BPX HSE) assisted I with project coordination in 1999. Peg Banks edited and formatted this report. ' REFERENCES McKendrick, J.D., P.C. Scorup, W.E. Fiscus, and G. Turner. 1992. Gravel vegetation experiments B Alaska North Slope. Agroborealis 24(1):25 -32. I McKendrick, J.D. 1999. Revegetation monitoring update 1998 for the Badami No. 1 Exploration site ca. N70° 09' 05 W147° 05' 20 ". BP Exploration (Alaska), Inc. Anchorage, AK 16 pp + appendices. I McKendrick, J.D. 1999b. Evaluation of vegetation 1996 -99 at Sequoia No. 1 Exploratory site N 70° 00' 30"; W 149° 00' 04' approximately 26 SW Deadhorse, Alaska. BP Exploration (Alaska), Inc., Anchorage. 16 pp. I Odum, E.P., 1959. Fundamentals of ecology. W.B Sanders Co., Philadelphia. p 262. Owenby, CE. 1973. Modified step -point system for botanical composition and basal cover estimates. Rangelands 26(4):302 -303. 1 1 14 I • • A I I I i 0 I 1 I , r_ j il x 0 it � � a'r s4 -"»,.-- . ps+ � �'� �._;. -'vim 1+_ '� ++., '�°� �`;� Inside back cover (above): Aerial obli ue view of the margin of a artiall dra lake between Badami and q eO f P Y II Prudhoe Bay. Each circular patch of vegetation represents the vegetative expansion from a s plant colonizing the open habitat exposed after the lake drained This illustrates how few individuals are actually involved with the formation of wet sedge tundra plant communities. Outside back cover: Aerial oblique view of Badami Production Facility (south to north), 23 June 1999. The Badami No. 1 reserve pit m ound is at the extreme right edge of the image. Sea ice is near the shore, and vegetation is just beginning to grow. a III. ... „ „. , ., , ' ._ ,... oil nil Nil alp . amt ._ „ Ens gm ” gill ...., egg ..„ slit .. ago ......,.. . .. asp . min ens 0 • .. . . , ... . . . , , . • . „ , . . • . . . . - .. • . , . . . . . . . . . . . . . . , , , • ., . , .. .. - . • , . . . . , -- • , . . . . • . . . . . . . , • . , , . • . -. . .. • . . . . , - - . . . . . . -: . • ,. . • .. , . • • . , • . .. .. . .,... ,, . . .... . ,. . . . : . .. ' • ' -• •-. -:. , . • :.:, : ... .,- • . . , . , . . til . , . . . .. , , , ....' • . ' ' : ' . ': ut: , . ., . .. - •,,-,:-.•,.,..,... , . ,,,,,;. ,‘'‘ ',..„.., ...- ' ',., • ..„..„.. ,...,:,.,„ &......,,,k-,4-4t.,`,;,..?,,,,00,.._L.:,-,..,....'tk,:.4-:,.;,'. 1 ,'t:•,:; - .1 , ,, '' ,.• , ,,ittfrt ., S,,,'.,;■,-;„ ; :':•„:„.„.„:.a.t.-4i,„ . \•:, •'• • , A‘ ,tir 1, -.::,,,,,,,,,.,...--,-., 44..4 . t ,,,, -,:,- : . ,„ izar::'. *I gor,,,,,,,,74-70n-•!,.,,,,,,.,-4,11, ; '" : ‘ .•:t„,; ' -NY,-,.....in,—,,,,, ..,11,,, -,..„ , ..% -,,, ,....,., . i ;s i i .,,,,,,,,4 %,-„t! 7, ,. -,,,,ta, r;„ r f A 4 ,:,,F;;FOR:t!mor,t, c. ' ,n .t.,,,,,44 t.. - . ., , , i i .„,-.:,, • ,,,,,,,... , , , ..,. ... 20,44:— ...v7m3Nr.. • ' ''''''''';'''te '' !; ' • . t '•::',:" ', .N ts . r• ' ' t'v•41'''. •• ' ",•"' - .44 , ...e.or . .. . , .' , . ,. . , , .- .., ,,- , .,.., , ,,,, .,,,,. , 14 ,,,,,,t, ' '‘ i tt ' f..i .. ..V - tlil i $,i'.....:,,14.4.o., rd4;4%,::;' ....%.•.- M' -... . • . • ......'" r. . ....- -- _ ___ _,„, •. ----- , ,... ....... ... . . . Badami Production Facility P-~e: Badami Subject: Re: Badami #1 Date: Fri, 08 Mar 2002 09:30:42 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Goates, R. Neal" <R-Neal. Goates@conoco.com> Neal, I apologize for the delay. Things have been nuts up here as elsewhere. That doesn't excuse the delay, but it is life in the patch right now. Best wiShes. Tom "Goates, R. Neal" wrote: > Thanks Tom, > I appreciate your response. > Neal Goates > Remediation Project Manager > Mid-Continent BU, EP Americas, NG&GP Conoco Inc. 600 N. Dairy Ashford P.O. Box 2197 Houston, TX 77252-2197 (281) 293-3822 Fax (281)293-3305 Cell Phone: 832-465-4123 ..... Original Message ..... From: Tom Maunder[mai/to:tom maunder~_.admin, state, ak. us! Sent: Friday, March 08, 2002 12:05 PM To: Goates, R. Neal Subject: Badami #1 << File: Card for Tom Maunder >> Neal, This note confirms that to my knowledge all Conoco's Alaska properties were conveyed to BP. On the basis of that property transfer, Conoco should not be responsible for any further actions with respect to Badami #1, PTD 189-117, APl 50-029-22017-00. Conoco's request for no further action is hereby approved subject to the following conditions: Please be advised that AOGCC approval of this plan does not relieve Conoco of liability should their operation fail to adequately investigate and remediate contamination that pose a threat to ground water, surface water, human health or the environment. In addition, AOGCC approval does not relieve Conoco of responsibility for compliance with any other federal, state, or local laws and/or regulations. Please contact me with any questions. Tom Maunder, PE Sr. Petroleum Engineer 1 of 2 3/28/02 7:44 AM Harding ESE A MAcTEC COMPANY Harding ESE, Inc. 601 East 57th Place Anchorage, AK 99518 Telephone: 907/563-8102 Fax: 907/561-4574 Home Page: www.mactec.com October 9, 2001 53971 Mr. Tom Maunder Senior Petroleum Engineer ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Location Clearance Badami 1 and Badami 2 North Slope, Alaska RECEIVED Alaska Oil & Gas Cons. Cornmissiorl Anchorage Dear Mr. Maunder: Harding ESE is submitting this letter for Conoco Inc. (Conoco) in response to a letter from Blair Wondzell with the Alaska Oil and Gas Conservation Commission (AOGCC) dated November 30, 2000. The letter states that the AOGCC could not confirm Onshore Location Clearance (Title 20, Alaska Administrative Code, Chapter 25, Section 170 [20 AAC 25.170]) for Badami 1 or Offshore Location Clearance (20 AAC 25.172) for Badami 2. Badami 1 is on the coast of Mikkelson Bay on the North Slope of Alaska (Section 9, Township 9 North, Range 20 East, Umiat Meridian). The well was drilled in 1990 as an exploratory well, and its current status is plugged and abandoned. The vertical depth of the well was 12,911 feet. The unique American Petroleum Institute (API) number given to the well is 50-029-22017. Badami 2 was an offshore exploration well drilled in Mikkelson Bay (Section 30, Township 10 North, Range 20 East, Umiat Meridian). The well was drilled in 1992 and its current status is plugged and abandoned. The unique API number given to the well is 50-029-22230. Conoco's wells were part of the Badami prospect that was transferred to BP Exploration (BPX) in an assets exchange between the two companies in 1993. A copy of the assets exchange is attached. Conoco believes it is now the responsibility of BPX to verify that the requirements for Location Clearance at the Badami sites have been met. A letter from BPX to AOGCC dated November 8, 1994, discusses location clearance inspections of three sites, including Badami 1. The letter includes plans for corrective actions at the sites. A copy of the letter is attached. Conoco requests a response from AOGCC acknowledging receipt of this letter and confirming that no further action is required. October 11,2001 53971 Mr. Tom Maunder ALASKA OIL AND GAS CONSERVATION COMMISSION Page 2 If you have questions or need additional information, please contact Neal Goates with Conoco at (281) 293-3822 or me at (907) 563-8102 or ljjohnson~mactec.com. Yours very truly, HARDING ESE Lorri John~ Project En~ QC/TE/jm/W2486C Attachments Harding ESE A MACTEC COMPANY Sleve C. Nicandro~ Manager commercial Development ~3usiness Development [xploration Production November 2, 1993 Conoco Inc. 600 N. Dairy Ashford Rd. P. O. Box 2197, Oasis 3004 Houston, Texas 77252 Tel: (713) 293-2798 Fax: (713) 293-4414 BP Exploration Operating Company Limited Britannic House I Finsbury Circus London EC2M 7BA Attn: Dr. Phihp M. G. Nolan Manager, Acquisitions and Disposals Gentlemen: RE: BP/CONOCO - U. S. ASSETS EXCHANGE Conoco Inc. ("Conoco") on behalf of itself and its affiliates hereby offers BP Exploration & Oil Inc. ('BPXO") on behalf of itself and its affiliate, BP Exploration (Alaska) Inc. ("BPXA") the sale and purchase of certain assets generally described below. The essential terms of the proposal are: I. The Conoco assets to be acquired by BPXA or BPXO, as appropriate, are: (a) all of Conoco's undivided 64.38% working interest in the Milne Point Unit in Alaska and all the properties, both real and personal, relating thereto ('MPU"); (b) all of Conoco's interest in the Milne Point Pipeline Company Partnership and all the properties, both real and personal, relating thereto ("MPPCP'); all of Conoco's interest in the properties, both real and personal, relating to the acreage known as "the Badami area" in Alaska ("Badami'); all of Conoco's remaining North Slope Alaskan exploration acreage and the properties, both real and personal, relating thereto; and {e) all of Conoco's interest in the offshore Gulf of Mexico deep water acreage comprised of the 54 blocks listed in Schedule A to this letter, except for a reserved overriding roya. lty interest in tracts MC 79, MC 123, MC 124 and MC 211, as more fully 6eacfibed in Schedule C to this letter. .[ BP Exploration Operating Company Limited November 2, 1993 Page 2 e The following property is excluded from the Conoco assets to be transferred to BPXA and BPXO: (i) any Conoco property, not located on the North Slope of Alaska, except as provided in Section 3 of this letter; (ii) all seismic, geological, geophysical and geochemical information and data licensed from third parties, together with Conoco's proprietary interpretations of same; (iii) all of Conoco's intellectual property including but not limited to proprietary computer software, patents, trade secrets, copyrights, names, marks, and logos; and (iv) any other Conoco property of a kind or type not normally transferred as pan of a sale of producing oil and gas properties. The BPXO assets to be acquired by Conoco are: (a) a thirty-three percent (33%) interest in BPXO's wholly-owned offshore producing asset known as Mississippi Canyon 109 (FMC 109"); (b) a thirty-three percent (33%) interest in BPXO's interest in Mississippi Canyon 108 ("MC 108"); and (c) associated interests in any related BPXO and its affiliates' transportation and infrastructure assets and arrangements as may be necessary to allow Conoco and its affiliates to produce and transport to points of sale its share of production from MC 108 and MC 109 on a basis equivalent to BPXO and its affiliates. 3~ The following property is excluded from the BPXO assets to be transferred to Conoco: (i) any BPXO property located in the Gulf of Mexico, except as provided herein; (ii) all seismic, geological, geophysical and geochemical information and data licensed from third parties, together with BPXO's proprietary interpretations of same; (iii) all of BPXO's intellectual property including but not limited to proprietary computer software, patents, trade secrets, copyrights, names, marks, and logos; and (iv) any other BPXO property of a kind or type not normally transferred as part of a sale of producing oil and gas properties. Except as otherwise specifically provided in this letter, the Conoco assets and the BPXO assets each include a proportional interest in all associated facilities, equipment, and other real and personal property (or a proportionate share thereof) associated with those assets, including: (i) all associated wells, platforms, pipelines, facilities, gathering systems, tanks, injection systems, salt water disposal systems or wells, fixtures, pipe, supplies, and equipment, located on or used in connection with producing, gathering, storing, measuring, transporting, treating, processing, managing, operating or otherwise handling the crude oil, condensate and gas production from the assets; (ii) all transferrable contracts and agreements affecting the assets and other real and personal property, including without limitation, gas sales contracts, processing agreements, farmins, farmouts, operating agreements, right-of-way agreements, and surface leases affecting the assets; (iii) all proprietary seismic, geological, geophysical and geochemical data and information, provided, however, Conoco shall retain a license to use such data and information; and (iv) all other tangibles, miscellaneous interests or other assets on or used in connection with the assets, including without limitation, records, files, maps, and other information related to or used in connection with the assets. B~ Exploration Operating Company Limited November 2, 1993 Page 3 To the extent possible, this proposed transaction will be structured in such a manner as to avoid a nontaxable exchange. For the convenience of the parties, no existing tax partnership subject to the transaction will be terminated by either party prior to closing. A mutually acceptable Joint Operating Agreement covering MC 108 and 109 will be entered into by the parties upon closing. In addition, the parties agree that Conoco, for itself and as operator for the other owners in Mississippi Canyon Blocks 243, 199, 244, 245, 287, 288, 289, 290, and 333 and any other blocks with which said blocks may be unitized from time to time ("MC 243 Area"), shall have the right, but not the obligation, to utilize the MC 108/109 platform and facilities and the pipelines associated therewith ("109 Facilities") for the handling, processing, and transportation to the point of sale of all oil and gas production from the MC 243 Area, up to a level of 22,000 barrels per day of liquid hydrocarbons and 100 mmcfd of natural gas, commencing on or after January 1, 1998, under terms and conditions to be negotiated prior to the commencement of such usage. With the exception of third party usage for production from MC 108, (i) this tight shall be superior to any other third party usage rights in the 109 Facilities, and (ii) Conoco's consent shall be required before any other third parties may utilize the 109 Facilities for the benefit of any other blocks. The intent of the Conoco consent requirement is to ensure that all such third party usage is done at "arm's length" and to ensure that such third party usage does not prevent Conoco from utilizing the 109 Facilities (existing at that time or which could be installed, given platform weight and space constraints) for the processing of its production from the MC 243 Area up to the-volume limits set out above. Conoco shall have an option, to be exercised prior to closing, to receive from BPXO a guarantee: (a) that Conoco will receive its thirty-three percent (33%) equity share of the MC 108/109 flowstreams set out in Schedule B to this letter; such that, in the event that production shall be less than that set out in Schedule B, BPXO shall make up' the difference in cash, based upon recognized hydrocarbon price indices, PROVIDED HOWEVER THAT if production shall exceed that set out in Schedule B, then Conoco shall make up the difference in cash based upon recognized hydrocarbon price indices; and (b) that Conoco's responsibility for the capital expenditures, operating costs, liabilities, transport costs and abandonment costs incurred by BPXO in operating MC 108/109 shall be th/rty-three percent (33%) of those set out in Schedule B to this letter; such that, in the event that the same exceed thirty-three percent (33%) of those set out in Schedule B, Conoco shall have no liability in respect of the excess PROVIDED HOWEVER THAT if the same shall prove less than thirty-three percent (33%) of those set out in Schedule B, then BPXO shall be wholly entitled to the shortfall. The effective date for the proposed transaction is January 1, 1994. BP)La, shall employ at least fifty (50) Conoco personnel currently associated with the Conw. o assets which are the subject of this letter. BPXA shall employ these Conoco l~er'~tmel at substantially equivalent wages and benefits. More detailed terms and tt:n~litions of employment shall be negotiated as part of the definitive agreements BP Exploration Operating Company Limited November 2, 1993 Page 4 documenting this transaction. 9. This transaction is proposed subject to the following conditions: (a) The expeditious negotiation and execution by the parties of mutually acceptable definitive agreements, conveyances (including special warranties of title given by the granting party), and other legal documentation necessary to give effect to the transactions described above, in each case, with a view to closing all such transactions not later than December 31, 1993, each party to bear its own expenses in negotiating and closing the transact/on; (b) Each party having all reasonable access and opportunity to conduct a thorough due diligence review of the assets and/or interests to be acquired by it (the parties acknowledge that Conoco has not reviewed the records, data and information pertaining to the BPXO assets and will be confirming the 'assets during the negotiations); and (c) Compliance with all third party rights, both governmental and non-governmental, concerning which the parties shall endeavor to obtain appropriate waivers or consents, and compliance with all regulatory requirements, including anti-trust pre-notificatioa~ approvals under the Hart-Scott-Rodino Act. 10. The transaction contemplated by this letter is subject to and contingent upon management and appropriate board and partnership approvals of the parties. It recognized that such approvals are not assured, and the parties understand that failure obtain such approvals shall be without liability. It is further recognized that this letter not an agreement, and unless and until the aforementioned transaction documentation been executed, neither party shall be bound or obligated to proceed in any whatsoever, and either party may terminate negotiations without liability at any time reason. 11. Both parties shall keep the existence and terms of this letter strictly confidential closing, or such earlier date as is mutually agreed upon, except as to disclosure to parent, subsidiary or affiliated corporation or other affiliated entities necessary to the overall and/or any component transaction contemplated hereby. 12. This proposal supersedes all prior communications concerning the subject matter expires at 12:00 noon CST on November 3, 1993, and it requires acceptance and by BPXO to Conoco prior to expiration. Acceptance of this proposal is valid if by personal delivery, telex, telecopy or similar facsimile means or by courier or service. BP E,] Novej Page/ If th: : retur 7~ CO? ' BF T~ "BP Exploration Operating Company Limited November 2, 1993 Page 5 If the above is acceptable, please sign the enclosed duplicate in the space provided below and · return it to this office within the time period specified above. Very. truly yours, CONOCO INC. /Steve C N~candros Manager Commercial Development ,, davy of November, 1993 Schedule A-1 Conoco Leases - Alaska ' ADL/ WORKING NET CONOCO OCS DATE OF INTEREST REVENUE LEASE NO. NO. LEASE LESSOR LESSEE % INTEREST % DESCRIPTION · , ,, . .. '"' "' "' BADAMi ~ :'" ' ': ' :: PROSPECT · : ";. 22236g-000 367005 05/01/86 State of Conoco Inc. 66.67~ 58.33~ Tract 4EIA-05 Alaska T. !0N., R. lg E i Sec 25: All Protracted 1640 acs) Sec 26: All unsurveyed tide and submerged lands (258 acs); Sec 27: All unsurveyed tide and submerged lands (207 acs); Sec 34: All unsurveyed tide and submerged lands (171 acs); Sec 35: All unsurveyed tide and submerged lands 1110 acs); Sec 36: All unsurveyed tide and submerged lands (523 acs); T. 10 N., R. 19 E.(Tract A) Sec 26: All unsurveyed, fractional (382 acs); Sec 27: All unsurveyed, fractional (433 acs); Sec 34: All unsurveyed, fractional (469 acs); Sec 35: All unsurveyed, fractional (530 acs); Sec 36: All unsurveyed, fractional 1117 acs) ,, , 222370-000 367006 05/01186 State of Conoco Inc. 66'67~ i 58.33~ Tract 48A-06 Alaska T. 10 N., .R. 20. E. Sec 17: All Protracted (640 acs); Sec 20: All Protracted (640 acs); Sec 29: All Protracted (640 acs); Sec 30: All Protracted (620 acs); Sec 31: All Protracted (623 acs); Sec 32: All Protracted (640 acs); Sec 18: All unsurveyed tide & submerged lands (569 acs); Sec 19: All unsurveyed tide & submerged lands (603 acs); T. 10 N.. R. 20 E.{Tract A) Sec 18: All fractional unsurveyed (46 acs); Sec 19: All fractional unsurveyed (14 acs), A-1-4 BP EXPLORATION Exploration Department Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 8, 1994 Subject: Location Clearance Inspection - North Slope Wells Dear Commissioner Johnston: Reference is made to your September 2, 1994 letter, a copy of which is attached for your reference. At this time BPX plans for the noted wells are as follows: 1) BPX Ekvik #1 - Our current plan is to inspect the well site post break-up (circa July, 1995) with the purpose of establishing the status of tlie. marker post at the tundra level. Assuming the post is incorrectly positioned, we plan to return to the site in the Autumn (circa September or October) to rectify and make final clearance. 2) BPX Fawn Lake #1 - Our plan is the same as noted for the Ekvik well. 3) Conoco Badami #1 - BPX assessment indicates ponding around the well location appears extensive and could possibly enlarge. Our plan is to monitor changes in 1995 and obtain necessary permits for filling the depression in 1996-1997. If feasible we would prefer to perform this work in conjunction with Badami development gravel work. NOV -9 1994 0il & Gas Cons. Commission Anch0rcj~ Letter- Mr. D.W. Johnston, AOGCC November 8, 1994 Page 2 of 2 Please advise should these plans not appear satisfactory or shOuld you have any questions. Very truly yours, Land Manager, Alaska EPZ:Ibs cc: T. J. Obeney RECEIVED NOV -9 1994 Alaska Oil & Gas Cons. Commission Anchora..,,;e U ALASKA OIL AND GAS CONSERVATION COplPlISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 30, 2000 John E. Skopak Conoco Inc. P.O. Box 2197 Houston, Texas, 77252-2197 Re. Location Clearance Dear Mr. Skopak: We have your E-mail of October 5, 2000 concerning Conoco's two Badami wells Nos. 1 and 2. We have again reviewed our files; the Badami #1 (PTD 189-117) is an onshore well.and was last inspected by our. inspector in August of 1994 at which time he noted a depression around the well head and an open reserve pit, both of which need to be filled. Badami #2 (PTD 191-144) was drilled from an ice island; because we have no documentation to confirm that there is no junk or equipment on the sea floor, the sea floor needs to be surveyed. We can not confirm 20 AAC 25.17 Onshore Location Clearanc.e or 20 AAC 25.172 OffShore Location Clearance of either well at this time. Sincerely, Blair E. Wondzell,. P./~" Sr. Petroleum Engin6er L-lc-co2bad.doc '/07/2000 PERMIT LOC CLEAR API NUMBER 191-144 5-NOT-CLEAR 029-22230-00 189-117 5-NOT'CLEAR 029-22017-00 ALASKA WELLS LOCATION CLED~3%NCE STATUS WELL N~'~E BADAMI 2 BADAMI 1 WELL STATUS STATUS DATE TALLY OPERATOR P&_A 4/13/1992 CONOCO INC P&A 4/27/1990 CONOCO INC PAGE or Ot.X~~t-f ~ -To BP EXPLORATION Exploration Department Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: Location Clearance Inspection - North Slope Wells BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 8, 1994 Dear Commissioner Johnston: Reference is made to your September 2, 1994 letter, a copy of which is attached for your reference. At this time BPX plans for the noted wells are as follows: 1) BPX Ekvik #1 - Our current plan is to inspect the well site post break-up (circa July, 1995) with the purpose of establishing the status of the marker post at the tundra level. Assuming the post is incorrectly positioned, we plan to return to the site in the Autumn (circa September or October) to rectify and make final clearance. 2) BPX Fawn Lake #1 - Our plan is the same as noted for the Ekvik well. 3) Conoco Badami #1 - BPX assessment indicates ponding around the well location appears extensive and could possibly enlarge. Our plan is to monitor changes in 1995 and obtain necessary permits for filling the depression in 1996-1997. If feasible we would prefer to perform this work in conjunction with Badami development gravel work. RECEIVEI NOV -9 1994 Oil 8, Gas Cons. Commission Anch0rc,,3 Letter- Mr. D.W. Johnston, AOGCC November 8, 1994 Page 2 of 2 Please advise should these plans not appear satisfactory or should you have any questions. Very truly yours, Land Manager, Alaska EPZ:Ibs cc: T. J. Obeney RECEIVED NOV -9 1994 Alaska Oil & Gas Cons. Commission Anchora, :e ALASKA OIL AND GAS CONSERVATION COMMISSION September 2, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 SEP 8 - 199" Land Department (MB12-1) Pete Zseleczky, Mgr BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Location Clearance Inspections Eight (8) North Slope Wells. Dear Mr. Zseleczky: On August 24, 1994, our Inspector Lou Grimaldi accompanied Wade Srock, your reprensentaive, on location inspections of six BPX and two Conoco North Slope wells. Three of the wells were not ready for location clearance. On two BPX wells and one Conoco well he found problems on the locations to the extent that he could not recommend location clearance. The wells and the major problems are as follows: BPX Ekvik ~1 PTD 89-020 Casing stub is 1-2' above tundra level. BPX Fawn Lake 1 PTD 90-013 :damiPTD 91-144 #1 Casing stub is level with the tundra. Depression 8-12' wide x 2-4' deep around well location. Please advise the Commission as to your plans for these wells. Chairman~ ~ c: Rory Mayra, BP Environmental Blair Wondzell, PI Spvr, AOGCC RECEIVED NOV -9 1994 Alaska Uil & Gas Cons. Commission Anchom. :e hew/11 bp8 nsw 'b:" pr~'¢,¢ ?r. rr.?¥(,i,,,.~ '~EF" . · THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24 2000 P M C:LORruMFILM.~ L A T E E T E R IA L UN R HIS MARK E W D E E R AOGCC DETAILED W]~LT. LOG INVENTORY PERMIT NO. ~ ~ - //7 , LOG TYPE RUN # INTERVAL SCALE , , , , 02)C , , , 07) o~~ f /_ ~ ~ ~,,, ~) / ~VO ,L , , / 17) AOGCC DETAILED WELL LOG INVENTORY PERMIT NO. - LOG TYPE RUN # INTERVAL SCAL]~ .... ,,, ,, , ,,, =0) " 30) , %VO ,,, ,, ..... ~¢~(¢,~ ,, ,, ¢,, %¢0 35) ,,, , AOGCC DETAILED WELL LOG INVENTORY PERMIT NO. - LOG TYPE RUN # INTERVAL SCALE ,,, 37) 40) ~ ' ~ ~ ~f ~0~ , , ~( 44) lX ~ 45) 46) 47) 48) 49) . 5O) 51) 52) 53) 54) ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 2, 1994 Land Department (MB12-1) Pete Zseleczky, Mgr BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Location Clearance Inspections Eight (8) North Slope Wells. Dear Mr. Zseleczky: On August 24, 1994, our Inspector Lou Grimaldi accompanied Wade Srock, your reprensentaive, on location inspections of six BPX and two Conoco North Slope wells. Three of the wells were not ready for location clearance. On two BPX wells and one Conoco well he found problems on the locations to the extent that he could not recommend location clearance. The wells and the major problems are as follows: BPX Ekvik #1 PTD 89-020 Casing stub is 1-2' above tundra level. BPX Fawn Lake 1 PTD 90-013 Casing stub is level with the tundra. Conoco Badami #1 PTD 9~ Depression 8-12' wide x 2-4' F~// 7 deep around well location. Please advise the Commission as to your plans for these wells. David W.~Johnston ~ ~ '> Chairman ~ ~ C: Rory Mayra, BP Environmental Blair Wondzell, PI Spvr, AOGCC bew/llbp8nsw MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John, DATE: Chairm~ August 24, 1994 THRU: Blair Wondzell, ~~7.. FILE NO: P. I. Supervisor '//aW BDMLOCLR.DOC FROM' Lou Grimaldi, (J~ SUBJECT: Petroleum Inspector Location Clearance inspection Conoco Badami #1 Sec. 9, T9N, R20E, Umiat PTD #9.1--t,44, Wednesday,, August 24, 1994: I made a Location Clearance on Conoco exploratory well Badami #1. Wade Srock (BPX rep.) Accompanied me on my inspection. The location was very clean. There was a large 8-12' wide depression approximately 2-4' deep around where the well was drilled I think that this is excessive and should be filled in before a final clearance is given. I mentioned this to Mr. Srock but as this is a Conoco well BPX may not have this responsibility. The location had a large mound 10-12' high over the reserve pit which Wade told me was in remediation. The mound has the appearance of a Pingo but has no signs of vegetation growing on it. SUMMARY: I made a Location Clearance on Conoco exploratory well Badami #1. I recommend Badami #1 no.__t b~gr~nt,ed a final location clearance until the depression surrounding the well andTeserve pit iSSUes are satis-~fied.- - Attachments: Photographs STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment / Location Clearance Report ( Title 20 AAC 25, Article 2 ) , .. . . ......... FI, LE!NFORMAT!ON: Operator: Conoco Well Name: Address: PTD No.: APl No. 50- Surface Location: Unit or Lease Name: F L, F L Field and Pool: Section 9 ,T 9N ,R 20E ,M Umiat Downhole P&A Date: Badami#1 ... Inspection Date: 8/24/94 I ....... ....20.,AAC25.125 -ABANDONMENT MARKER: J Approval Date: Steel Post OD: (4" min) 4 "Length (10' min.) ft. Height Above Final Grade Level (4' min.) 5 Top of Marker Post Closed With: Welded (Welded, Cmt., Cap), Set: Distance Below Final Grade Level: ft. Side Outlets: All valves and nipples removed ? ~AII openings closed ? With (On Wellhead, Csg, In Cmt) Marker Plate Diameter: "Thickness: "Distance Below Final Grade Level: Marker Plate Attached To: Wellhead Cutoff Csg Other , i , , Information Beadwelded Directly to Marker Post or Blind Marker Plate: Operator: Conoco Inc. Well Name: Badami #1 Surface Location: 1800 S N L, 4280 Section 9 ,T N9 Inspection Date: PITS: Filled In: X Unit/Lease Name: Remarks: W E L ,R 20E ,MUM 20 AAC 25.t70 - LOCATION CLEANUP: Liners Removed or Buried: SURFACE CONDITION OF PAD AND / OR LOCATION ' Clean: Clean , , , , ( Note when different from file information) Approval Date: Debris Removed: Large mound 12+' over reserve pit ( Rough, Smooth, Contoured, Flat, Compacted ) Type & Quan. of Debris if any remaining on pad and / or location: TYPE AND CONDITION OF SURROUNDING AREA' Tundra ( Wooded,Tundra, Grass, Brush, Dirt, Gravel, Sand) Clean: Clean Type & Quan. of Debris if any remaining on surrounding area · TYPE AND CONDITION OF ACCESS ROAD AND SURROUNDING AREA: No evidence of access road ( Dirt, Gravel, Ice, Other) Clean: clean Type & Quan. of Debris if any remaining on access road or surrounding area · CLEANUP WORK REMAINING TO BE DONE · RECOMMENDED FOR APPROVAL OF ABANDONMENT: Yes No X (If "No" See Reason ) Distribution: orig - Well file c - Operator c - Database c- Inspector FI-000 (Rev. 3/93) Reason: Large mound 12+' over reserve pit, deep depression around marker 2-4' deep FINAL INSPECTION: Yes No X ,, INSPECTED BY: Louis R Grimaldi DATE: 8/24/94 BDMLOCLR.XLS David L. Bowler Conoco Inc. Division Manager Suite 200 3201 C Street Anchorage, AK 99503 November 1, 1990 Mr. Benjamin Thomas Alaska Department of Environmental Conservation 1001 Noble Street, Suite 350 Fairbanks, Alaska 99701 Dear Mr. Thomas' "ura,~e, °~j$$/oa On April 30, 1990, approximately 210 gallons of drilling mud (4% oil content, Ph 9.0, Chlorine 500 mg/1) were accidentally discharged onto the Conoco Inc. Badami Exploratory Well No. 1 ice pad. The discharge covered an area of approximately 800 square feet. The material melted through the pad and reached the tundra. The cause of the discharge was either a rig cellar overflow or a drain line that was accidentally displaced out of the rig cellar. The discharged material was recovered by digging up the tundra. The contaminated tundra was placed into a tank full of water in order to wash out the contaminates. The contaminatedwater was then taken to our Milne Point Facility and processed through the production system. The remaining tundra/soil was disposed of at the North Slope Borough Disposal Facility. Topsoil excavated from the reserve pit was used to replace the contaminated tundra. The discharge was reported to all applicable agencies. A site visit was made by Conoco and DNR personnel on September 20, 1990. No environmental damage resulting from the discharge was observed. If you have any questions, please call Bob Soptei at 564-7617. Yours very truly, David L. ~ Division Manager RJS Mr.~rren--Matumeak, NSB Ms. Martha Ipalook/Mr. John Hascal, NSB Mr. Frederick L. Smith, DNR Mr. Carl Lautenberger, EPA Field Safety, Training, and Compliance Coordinator, MPOC File 500.01 David L. Bowler Conoco Inc. Division Manager Suite 200 3201 C Street Anchorage, AK 99503 November 1, 1990 Dear Mr. Thomas' On February 12, 1990, approximately one gallon of antifreeze was accidentally discharged onto the Conoco inc. Badami Exploratory Well No. 1 ice pad. The discharge covered an area of approximately eight square feet and was contained on the ice pad. None of the spilled material reached tundra or water. Mr. Benjamin Thomas Alaska Department of Environmental Conservation 1001 Noble Street, Suite 350 Fairbanks, Alaska 99701 A heater hose on a truck burst, which allowed the antifreeze to leak onto the ice pad. The discharge was stopped by shutting off the truck and replacing the hose. The hose that burst was not made of arctic grade rubber. The discharged material was recovered using sorbants and shovels. The contaminated ice was melted and the additional glycol was recovered with sorbant pads. The water was used for rig operations and the contaminated pads were disposed of at the North Slope Borough Disposal Facility. The discharge was reported to all applicable agencies. A site visit was made by Conoco and DNR personnel on September 20, 1990. No environmental damage resulting from the discharge was observed. If you have any questions, please call Bob Soptei at 564-7617. Yours very truly, David L. Bowl'e~r Division Manager RJS/jcd cc Mr. Blair Wondzell, AOGCC Mr. Warren Matumeak, NSB Ms. Martha Ipalook/Mr. John Hascal, NSB Mr. Frederick L. Smith, DNR Field Safety, Training, and Compliance Coordinator, MPOC File 500.01 STATE OF ALASKA ALASKA 0IL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receipt of the following material which was transmitted via _ /zT~ is hereby acknowledged: QUANTITY DESCRIPTION Copy sent to YES s e n~r JO- Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (9O7) 564-7600 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: August 16, 1990 AUG $ lffi0 0il & Gas Cons. Commission Anchorage The attached letter has two points that require clarification for your records: The date of June 11, 1990 at the top of the letter is indeed incorrect; it should be July 12, 1990. This particular letter of transmittal was built by updating an earlier letter of transmittal to the AOGCC dated June 11, 1990. When the attached letter was printed on the morning of July 12, the erroneous date slipped by me. . The LIS tape mentioned in this letter is indeed the second tape of Badami well log data submitted to Bob Crandall. The first tape was hand delivered to Bob by me during early June. Unfortunately, it was not documented with a letter of transmittal. Bob should remember the original tape as it was inadvertently copied in an odd "back-up" format by Conoco's computer center in Houston. Bob called me in mid- June when he was unable to load the initial tape into AOGCC's computer. According to my daily work log, I called Conoco's Houston office to retrieve the original Badami LIS tape on the morning of June 26. The original tape was sent to me, and subsequently re-copied by Western-Atlas. I delivered the new copy to Bob on July 12, 1990 along with the attached letter. Should you have any questions or any further problems, please telephone me at (907) 564 - 7640. Sincerely, Steve Davies Staff Geologist lrl cc: R.F. Wheeler, w/attach. 390.08.07 ' *' ' ~.-" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,vlMISSION WELL COMPLETION OR RECOMPLETION REPORT OIL [] GAS [] sUSPENDED [] ABANDONED ~ SERVICE [] , :~. Name of Operator 7. Permit Number CONOCO, INC. 89-117 3. Address 8. AP~h~,jnbffr . 3201 C Street, Suite 200, Anchorage, Al~sska 99503 5o-~'7 "4. Location of well at surface I 00-~~ ~ ............. 9. Unit or Lease Name t 1800'FNL, 4280 FEL SEC TgN R20E ,! Badami At Top Producing Interval .~'/-'~~ [ 10. Well Number 3984' FNL, 4537' FEL SEC 4 T9N R20E i ~ERIFIED J~ At Total Depth ............ ,,~ 11. Field and Pool 3294' FNL. 4578' FEL SEC 4 TqN R2OE ' 5. Elevation in feet ~indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 30.7 'I ADT, 12. Date Spudded 13. Date T.D. Reached '14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore ] 16. No. of Completions 2 / 5/9C) 4/5/9n 4/2 7/ed feet MSL 17. T~)tal Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth whereSSSV set 21. Thickness of Permafrost 13595'MD (12911 'TVD) 11190' YES [~ NO []I feet MD 1900' 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20 94,0 K55 surf. 108' 36" 375 cf perm. reg. H3 - 3/8 72,0 N80 surf. 3512' 17 ½" 2869 cf Class E, 115 cf Class G 9 - .5/8 40,0 S95 surf, 10763' 12 ~" 825 cf Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD _ interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) --,, 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. _ DEPTH INTERVAL (MD) AMOUNT& KIND~F~~I~LUSED __ 27. PRODUCTION TEST __ Date First Production I Method of Operation (Flowing, gas lift, etc.) ~] owing (see I Date of Test Hours Tested PRODUCTION FOR !OIL-BBL GAS-MCF W~¥~¥-BBL CHOKE SIZE I GAs-oIL RATIO TEST PERIOD e -- Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. CORE 1: 12560.0'MD-12562.0' Cut: 2.0' Rec: 1.0' Silty Shale No Shows CORE 2: 12562.0--'~12656.0' Cut: 3.0' Rec: 3.0' Silty Shale No Shows CORE 3: 12606.0'-12666.0' Cut: 60.0' Rec: 57.5' Siltstone, Silty Very Poor Shows Shale CORE.4: 12666'0'-12704.0' Cut: 38.0' Rec: 39.5' Siltstone, Poor Shows Silty Shale CORE 5: 12824.0'-12884.0' Cut: 60.0' Rec: 59.5' Silty Sandstone, Poor Shows Sandy Siltstone Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Prince Creek Seebee Hue H.R.Z. Kekiktuk GEOLOGIC MARK[ MEAS. DEPTH 7,124 8,890 12,230 12,397 12,643 TRUE VERT. DEPTF MATION ,' E S'I"S 6,811 8,445 11,574 I1~736 11,977 Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS DST results 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Date INSTRUCTIONS General: This form is designed for submitting a complete and-correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, a~r 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 123: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Conoco Badami #1 AP I, # 50-(~3o~:-~(~t-7-- DST #1: 4/16/90 Production Test- 10,760 - 11,190' ~B~pen hole 1st flow- 12 hrs. duration 1000 BBL-Oil unk. MCF-Gas* 500 GOR 1100 FTP 1500 Csg. Press. 20/64" choke ~!SIP : 6322 psig FFP : 4380 psig _F~S~IP : 6130 psig * Gas meter not working properly Calculated 24-Hour Rate' 2670 BBL-Oil 1100 MCF-Gas 0 BBL-Wtr 2nd flow - 6 hrs. duration 600 GOR 2" choke FFP = 3320 psig 990 BBL-Oil 600 MCF-Gas 560 FTP 1500 Csg. Press. FSIP = 5865 psig Calculated 24-Hour Rate' 4100 BBL-Oil 2500 MCF-Gas 0 BBL-Wtr STRICTLY CONFIDENTIAL 200 BBL-Load Water 28 Degrees AP I 28 Degrees API DST #2' 4/21/90 Production Test' 10,760' - 10,883' MD open hole 15 hrs. duration 705 BBL-Oil 690 GOR 587 F.T. Press. 12/64" choke ISIP : 6240 psig FFP : 4220 psig Calculated 24-Hour Rate' 170 MCF-Gas 1500 Csg. Press. FSIP = 6175 psig 210 BBL-Load Water 1720 BBL-Oil 405 MCF-Gas 0 BBL-Wtr 27 Degrees API 8;300.000 7300.000 6300.000 5~00.000 4300.000 3300.000 2300.000 10.000 II DST NO. I -- PRESSURE AND TEHPERATURE VS. TIME GAUGE # ~006t AT JO. 750' MD (-~0, I75 76' TVDRB) I i i ] 20 30.)00 I 40.000 I I I Ttme (hour I I I I I I I I DST ~0. 2 -- PRESSURE AND TEhiPER~TURE VE. TINE GAUGE ~ ~[008! AT ~.0, 745' MD ilo, f, 7).:l.' TVDRBm 7 oo.®o /I 4000. lO0 8.000 t3. 000 't8.0~0 2~. ~00 28.000 33,00,0 :lEt. 000 43.000 48. 105. 000 ' Time (hours) Ii' I I I I III I1'-II II IIII I I IIII S{Indl'lJ(:~l~ll~l .OAS FLOW RATE CALCULATION ' . LIQUID FLOW RATE CALCULATIONS F = Me,er K= Volume .. .~.., ' . Corr. FactorReduction Factor PSC /~/.,7_~'z*l~ ~' PR~ -: r ' =TE~~ ;~ ;~F' ' ~ 024x{14'73~/~ ''~:~':METER:~'" ~ F(l~BSW)(1--Shr60)1440 TANK:~= ~ K(1 BSW).1440 OIL ~ (ASTM~,gniti~ - ~ __ 14.73 ~+~,::,,*~? ~=FuFb:F'.~__.FpVYv.,.....~.:~__U='r ~] ~ 520 / ~tmin D12~Petrol~m . ,~.,~ . .., . .' -~'. :': ~' L~:~ ' ' . ~? ~:" ~ ~'~,~- ::~'-T~.A.~q "~"~<~ ,'::/ .~?~'~,'~, '~'., .,~ ~.c '"'..'=' ~' ' '~', '? ':""~','~ " .... .; " · "~'",'~ ~' ' ' .... ~' '~' " - ' 'L~:,"~ ': ' :' :'~!~ ~':~"{'~;~' ~ ". ~ ~ ' ~'~. ' ~ ' [ · ~ N · ~ N ' · ~ ' ', ~' ' ~ ' ~ ' ' · · - ~ ,: BBL , L ~1 ~ ~ ' ' ~ APl ~ ' FR~ 8BL F '~ '" ' . 8BL ~ 8BL '" ~ ' BBL ''' ' "~ "Y ''~ .... ,'~.,,,,:~'.,: .~/~ ~ ~, /a~a ~/~ .,.. .... ~F~ ~~..~.~/~.~ ~.~.,~ ~. ...... ,' .... I' :. ,. ....... , ,, ~,,~.~ .......... ~;.,:,,,,,,,v , ,,~., ~ : .~5~ · ~,/ ~' I/a~ ~/~ ~":':'."~'~," .~ ~'.' ';:'~""~ ,' '~ ~:'' "'~ "' :~ 7'":" :' :"'~"~"' .... ~' :' ':~ "'~ ' '~ ::"' ' ~':~'" ............... """" ' ' ' ' ~'~ :'"~;~':"~ ' "~' ~ - )' ~ .... ~ ;, , , , · '~: , ~ ~'~, .~5.',,. .... , L. ,; · ,,: ,..,. . · . .. .~ ~ - ,.~¢, .:,.... :.:; .' , , . . ,, · ,,, .... :. ..... . .... . ,=-.. ,.?~?,?. . , ??.::../. :.. .... ~:. ~. ~o ~ ~ //~ ~z~~ · :. /~/:'~,~/~< ,~:. r~. ~.*~ ~z .,'z .~: ~s~: ~/~.. '~/. r~** /z~.~ ~ , · , .. ~.: ~ oeoo ~-t ~ ~/~ ~z~ ." ' .. .::'. -~' .... ' .:".' ~'. '..._~.~ ~: ,~ ~g~ :.'. ::: .:"'' ' :.'< c: , L .:. ~ ~2. ,~ ~ . f,' . ~ ,' .,:'" ~ . ~ ' ' "' ' ' CUMU~IVE ~ SEP ~L ~AL ~ · '"',~.' ~ ... ~.~,.~IN G~-~L,. · ~ ~ID OIL ~ ~ i ~ GOR2 ~ ~LR ' TLGR ,;?:,:?,:,.,.:~ . . . _ . ..: : .,::.,:,~,... , . , . ,,~.-:z,., · .., ~ :' "~: ~.'L ':~', . , .. , ~ . · $1M~iMCmdlMal GAS FLOW RATE CALCULATION .~: ~. LIQUID FLOW RATE CALCULATIONS F - Mete, K · vo~um, , Corr. FactorRa~uct.on Factor - ~ . ~ F (1 BSW)(I - Sh~ ~0) 1440 TANK: ~" ~ K (1 - BSW) 1440 O~L ' ' ::'~.: FIELD READING~ ~: ~'O .~: ,~ '! '. __ ~ ~~ ?tm .~ ~ T T~~ APl ~~T ~~ '--~ ~ ~ ,., ~m~ ~,~ .,:-.,,~-.,,.. ~' "' " "' :' ' .'v:."' ': .~.'". ~:'/~'~".~'. ',.,~',~'~" .':,:' '~*~.~',:' ? 7': ',4..., -'.~,.... :' ' ' ' : . ~. ~;';~',., ' ' . . ~g'..,,; : · C~ · . . ' P ' ' ..... .................... '," "' '~ .... : ..... ~ ," ,.. .. .... ,..... r~' , .:~ · ~':' ,.-;.:~',{"...:',,~ ..'. :. '.'{/: '.~ '-' {' .'~.'. :' '. "'. :~t,'.'" ..'-..~ ' . . ' '~ .: : ' ,~;'~;[~.~'~ ' ~ . : :~. ',~,~ . '.'. ' .. ~ .~/~¥ .' ~' ¥-~:.'.'" '.',.:;t g. '.' ', ..... ....' .'...,'..... ,~ , ' " , ": .;~;'t~':~ ' ~ '.. ??~.,f' . ~:~" ~' ' . """: "~ "? '~ ....... ·' ...... : ,"~: . t.;'.E'...".: '. ~' · . ~ . . . :.. ... : ~ ...: ' .'. ....· ..' :,~. ~ '~; ,'~ . ,'' , . ... ~,: : ,.:,.,~ ~iE:~,~;,: . :.~..,..~./: . ~ . .' . .... ~ '.' ..... . .,.. '~,.. . ~ ~'.. .... , ~:~y..,~,':~ . ..:=.,.,.~:&:., ' Flu~: . ~ , . ~.. ~lm: - ~ , · '. ":'?-'., '/..~ .' . ~, ...;' '.'. .. :'.: ' . : .. · .'. ,. "."~ ~, .... ' ' ~.~'~'.'t ',?', . .'.. ". ' .. ,. . ....' . . .. ..... · ..... . · ' .~ :~, ~.,~ t.r. . .. ,,.-,. ~ ,. . . : ...':.:,:.: '.~ ,,..~... ~ ~...:: ..-.. .~.:, ·: ~ .~,. ...: ~.~?~?.?::. t::,~....... ~: in . - " ':',' :.' . . ' = . ' , ' .;~'. '.'t . '~.~..'~. ~: m · ' '" ~, :. · ' ::'~'.iG:"~., ' ':?: ,. ~.: . ' ~, ' :'~' · "":' · :, ;',~" :4 , '::'...~ :,. ' '~ ..... ' · . f~:~::}.:,~ ~ .,..:.-. -- .~. '.,.:. . -:: .., . · . . . ,~.. .,.'.: ..;:; ' · , , . ~ . '..~':. ,b':' ,' '" .. ~: ~ " -.. '.:.' '...~ . . .- .- ;..~. . ~ u~ ~ ~ING -- · 1~ ~ __ : ~E~. ?' :'~ " ~ : ~ ~ ~.,.. E~NS ~.:~..L~~ :,~;:.. ~L '.:~.~-m~.. SOLUT~N~N ~-0~L~T~O" ~T~ ' . · -- B~STB ~: : .? .-:':, ,.~: ,~ ... ':..: . .., ....: ~ .'. · :?:~..:~::.,~:,:.. , :..-.,~-...: ,... ~.~ .. ~ , '".T .~'~ .t. '..,", ,, . ' , ...~ . ~.~ .. " ' "' ' . ,~;~'. :,; ,~<':. , :': :{7 :"~ ' -- '' ~.' ~ "' .... , ". ~.:-.... .: .. ........ . . . .. ~ ~ ,~; ~'.:.:?~.~.' ~:',:':':.. . , t ... ~..,: ,~ ~ . . ~~ , ~A~ FLOW RATE CALCULAT~ · ,,~ v'Y./,,,??<~_.PS~_~ F,,--PRESS a~SE FAct FT,= 4~0 + ~c TEMp I~SE F.~CI' '~: :' · -X-~, /'14.73\ / 460 + T..\,~ ~, 520 ! ';i ~'! F (1 - BSW)(1 - Shr 60) 1440 LIQUID FLOW FIATE CALCULATIONS TANK: Qo F:M .... K - Volume 14,73 · . Fu Fb=Fti'F~ FPv y~ FU",024 x \T! : ~i~TE'R' ~Qo ~ C .... F ..... Red ...... -- ~ "'~' At mi~ ' ~ K (1 - BSW) 1440 OIL {ASTM ~ ~ ~ ~h Ch , : .: ~ · PSIG IN i · BBC' AP~ ~ ~':' ~ APl % FR~ BBL BBC BB~ BBC ~--.. .~ ,. ~' .: , , .. .'. ?~'~.:,:~ :3,''~ ,~~ ~' r i ' i i ' : , , i ' , - -, ~... ,, . _ ~" .~ /~50 ...... .:..... ,,.-.. , .:,.,.. .:' . ., ... ,' ~ . . ,, ~.,..,. u~: .::,'~ 2~ , ." ~:., .... .., :. ': . . . :: .' ~ ~ ::/~ ~ ~ ~ .... , :: .:.:'.. . ~: ~/~ ~5~ ' . ' ~ " ' .,." . ".:" ', .... '" ' : ' " '" ' ' ~::':~':.',':: ' . :, ~ , ~ ~1t~ ~ ': . '.,' .':" "::"~: ',.':',, ..," : , ' , ., ~.: ~ ,:~1/~ ~h,l ~ /1~ ~t~z ; '.. ' "" ' ' '' ~. ~ ~ FL~NG ~ SUPER ~ ~ ' CUMU~TIVE ~ SE~ O~L ~AL LI~4D G~ WATER ~: CL~K ~E~ ~FCE ~E ~ M~ . ~E ~ ~IF~E ~MR G~ COMPR. ~P~[ PR~. ' ' .~ FL~ ~AL ,~-~ G~IN G~-OIL ~ L~UID OIL TWE ~ ~F. ~ . ~ ~ . F~ F~ ' F~ F~ F~R ~ . E~ENS ~;:,~ ~ G~ ,~T~ ..S~UT~ON RATIO .~ RATIO ~T~O .' 'v . · . , . ~..,. ~ ~ ~':'" ' ' .',t," ':" ': · ~// .~ ~..... - ...:, , . ~.-,,~- ,-.:.'~" "., ? , ." ...,,. ~ :..'.:: .:.:i:.-. ,:." ',' ~. ~-~ ,'~ . ~. -~* : , ,, L .~~ ', ' -' ~- .:...', ?,(.~.. ~ "~':>.F ..... ~: ~ i. , , , , , StlndlMCeadlllem (]AS FLOW RATE CALCULATION LIQUID FLOW RATE CALCULATIONS F = Meter K = Volume ,~ Corr. FactorReduction Factor : ' ~Q ~ (ASTM ~,gnlt~on /~ ~ ;,._ 14,73 ;.~+~ Og. FuFbFtfFgFpvY~ FU",024x[~]x[ 8?0 ] METER(';~- ~ F(1 BSWl(1-Shr60}1440 TANK:Qo- K(1-BSW) 1440 OIL ~'~ CI.(X:K I~ ~ ~ I~ ~ ' :~'EI~ ":'. ¢:' ¢ ' ";'' ":~ .... :' ""~" ¢ ~E~' ~:'.~E' : OIL . "' '' ;' '"' .... '" .... ' ': . ~ ¢o ' ' ' To~ · BSW ' "~' 8~rl K ¢ ~ ~ : ~'~ ' BSL ' ~ 8BL ' ' ~SI6 IN ~F PSI8 fN ~ , ' ' ~P~ .. ' ~F BBL APl.~ ~ ~ ' APt ~ CRAC 8BL . ~D .' BBL . .. ~, .. · . . . . ~ , ~,~,,,.. . B - , , ,t , ',., , ,. . ,,., .. , .,. :,~;~.,;~?,; , . e:~,.~*~ ~/E¢ ~ ~¢~)~' ...' . .'. ......~ ~,: '.".. .. '.'::~ .,' .... ,.. : .~ ~,,?/ ~'¢~¢ .:'-"~:.. ,~<" , ~¢~-~ .~7¢~ re, ¢~'x ¢*¢~,r'".'r2 ¢~,¢ ' . :,';":"".' ~L: :'~! / ~ ~A ', ' ' ; : ' ' ' ' ' · ":' ' ': ' ' '/'~:~:":' ~' ?':,,~ ' - ~ ~: in . ~s u~ · ~. UN~ ~iC F~ING ~ SUPER ~ , ~ .". CUMU~TIVE ~ $EP OIL ~AL ~lD ~ WATER ' ~ G~. OIL ~ L~UID ~L ~: ~K ~ ~iRCE~F~E ~ M~ SEE ' ~ ~IF~E TEMFG~ C~PR. EXPOS. PRESS, ,. '" ~:,' . ~ .:L G~IN ~E ~ DIFF. ~ TE~ PRE~ ' F~ F~R F~ F~R F~R ~ E~ENS. ' ~ .... ~ ~LUT~N RATIO ~ ~TIO ~T~ ~ J PJI~ IN iN He e PSIA ~IM 9DIU ODIM ~lU O~M OOlM ] . ~ .... ~: ;. '. ,~.. ]j.~".. _ ~ ~, ~/ . . ~ ,~ ,' , ~' ~ 'r. ,,,". :,. ' ' ' -- ,-' . . ,. . . ,~, ,. ~:- -~ :..:..., ,.: . · .... GAS FLOW RATE CALCULATION ) LIQUID FLOW RATE CALCULATIONS F = Meter K = Volume PRES~BA~EFACTTEMPBASEFACT /14.73% 14~0 + Tlc% ' ~': e~. :~min Corr. FactorReduction Factor 1473 J~'.,. 480 + 0F Og" FU Fb Ftf Fg Fpv Y~ FU ' .024 x [--¢'~-) x [ ~?0 ] ' METE~' ~ F (1 - BSW)(1 - Shr 60) 1440 TANK: Qo = ·K (1 - BSW) 1440 OIL (ASTM Oe0,gmlt,on erVicei PAGE FIELD READINGS .-.. .' DATE ~ . . ~ ~ oF = BBL APl ~ % APl ' ~ T T ~ ~ ss~ Ssu~~ , ' ~: · . ,.' , ~: , ,,- ...' , .,", ., .... ':,. .." . ,.::./:.,:.:, , : _ . ~ ~ .. . · ,.. ..'~.: , I1~ 1/ .... ~ .... ~ .__ ~ ~: C[~K ~ O~E ~IF~ ~ M~ ~' ~ff - ~ FLYING ~ SUPER ~ME DIFE G~ ~ SEP C~ PRE~8. ~ ~ WATER G~ C~PR. EXPOS. ' .' ' ~ ~ ~AL ~- ~L G~ IN G~- OIL L~IO OIL , ' ', ~ ~MP ~ ' ~ r' ' CUMU~TIVE~P S[POIL ~AL ~l ~ ~ ~ ~ ,' .' F~R ~ ~ F~ E~ENS. · ' ': ~ · ' -' ~ .' ~ ~UTION ~TIO ~TIO~TIO .. ~ ~;'~t. i ~ :" / .. r,~ / . ~: ~ , 2~/ ' : .... .. , ... . · __ , . c/co ~.~ ~/~,f, ~-I ..<2-1 G/~-I tgZ'j /,. z~ z __ ~ . ..., .... ~ ' ~., .~..,:,., ,; ' :;_..~ :.. ~ g ~ ~. ..... .~ -- · : :,, LIQUID FLOW RATE CALCULATIONS F = Meier K= Volume PSt ,,_,,L,.'fi/~,..~7__.~.._.._~_ PRESS BA~E FACT TEMP BASE FACT 024 X (14.73~ /'4~0_.~__~_~'~' ',' ME,TE~.,: AQ~ ~ C .... F ..... Red ...... F .... ~<~ /w~ ~¢ Fp.- 14,73 FT.=~o+~: :::. Qg-FuFbFtfFgFpvY~ FU=. \'-~c/x\ 520 / Go" F(1-BSW)(1-Shr60)1440 TANK:Qo= K(1-BSW) 1440 OIL (ASTMOL%lgnation "" ¢~- ' At rain ~t man -- D12~ Petrol~m FIELD READINGS' ~ ~ -- ~ °F .. BBL. APl 'F . ~ . APl . = i u.: .--: .:, . : ..: ,. · : =~ in ' ~:':' "' """ : :"> ' '"" ~:' in ~'~"~; :'// '~ J~'~J~ /:~ ~N II( ~ ,.. .':. ': ', ~ .:' ..--.;:.,_~-:'. :; .... ~.: /~'~ ~ ~' '~ r~'/,,. ,.,~,:' ~p ~f,,v~ ~ ~ .. ~ .... ., . .... .' /,. ~: CL~K ~ OR[F~E ~IF~E ~ ~ ~E ~ ~ . ~IN~G~ COMPR.SUPER G~ ~ESS. ' ~ME S~ ~FE ~V~ TE~ TEME ~L SEP OIL~-~L ~AL ~1~ L~UID G~ WATER OIL ~ ~r ~E~ , ~R F~R F~R F~R ~ :' ' ,... FL~. r,,:: ~AL ~IN E~ENS. :.~-: - ~ ~.~' ~ '; ~UTION RATIO ~ ~TIO ~TIO ........ ~c~ ~ -- ~ .....,,...< . ..~ ' :. · . . ~ ~- ~ · .,. ~ .: .,:'.:. ... _ ? .,:.. ,(. ~. .,, P~¢ ] a-/. ~ PS~ PRESSI~ASEFACT TEMP BASE FACT ~ . LIQUID FLOW RATE CALCULATIONS F = Me,er K = Volume (14.73~ x [~'" .~ TER' ~ F (1 - BSW)(1 - Shr 60) 1440 TANK: ~ - K (1 - BSW) 1440 OIL ......... {ASTM F ROM g AUG 3 '90 i4:20 FROM CONOCO 713-293-4787 PAGE 003 , m ri "ffM 'NI '=l'JlO DIF!~, IN. , , /"7':'"'- .. ,% i imm immB LL III II I I II -,/ · ~ / I IIIII PUT :)It ..--~ I IIII I I oo p- I Cd I CO o o z o i iI I I ! '"'--/...t I ' I I II ,. _--.~..~ .-....' -.. \-..-.. .... ..',.. ---..-~x~., --..... '. ..~;"-., '-~x."- _,.,- --,~-~ ~-,~. --.-.. \ ':,".'- _. ',.~-:". ,, '-~ '-- x.---: -. . '., -. - --...~-~"- ..... : -:.--... ,,,. ~ ,,~ . _~, . '% . , .--;. - ~.. -. ~... -" \ . __-< ... \' -._'. ~. - _ . . 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'/ ...-~__...--._ -! . , . .. ../.....t.__..-.... ..... ... ' -'<'2--.. ": .:'':' :'/ '"': ' "" - ' · .;_ ...'"'~'.."< .'" · '. . .' i: "..' .."'Z'-.: ' ' .. ' ~. ' ../....._.:.:.~..~......./.....'/-. -.-.,~- ...,.- ..: .:-?..-'_/~....'?. -.-:/,. ../. ..' ?' '-'-'"'"' ~ /."-' ..'"--i-'.- /' · .. _./'.:,. x:~..- .--.'/ .' .. /:~ ' :....~::y.: .... "- - - / 'N.- '.-'/_ ' ;,-~'. - e.: ~ ' .' -,.-/ .... · .- . : ~ .- .- . .. / .' ...~ ....~...' ,_- . ~. .: .. ~ .' ..~?' .' //, ~. ~.:.. / ..--..'-,.. X-..'.~ .'.' .";: ..:..'-'~. :' .'/ '. '-'. ~'./'. '- -" ':' ..' -."Z "-" ;/-~<::'.x." /' . /~:.:..'-.: "- "":~- '/..'._'?' :'..-,X,- ...,. / .... .. ~:-.:.:.~ 11 IIII III III. AN r,- *.- C~-ART NO M-5OOO.H Z ./' FIViqr'.l r-'lqhll'hr-'~ 7 I ':I-?'=1':I-,..17R7 P,;::, G F 171171 7 III III I I II I I II I I I II Iit III Conoco Badami #1 API# 50-~-20017 DST #1' 4/16/90 Production Test' 19 hrs. duration 1990 BBL-Oil 500 GOR 750 F.T. Press. 20/64" & 2" choke Calculated 24-Hour Rate' 2800 BBL-Oil 1400 MCF-Gas 1000 MCF-Gas 1500 Csg. Press. 0 BBL-Wtr STRICTLY CONFIDENTIAL 200 BBL-Load Water 28 Degrees API DST #2' 4/21/90 Production Test- 15 hrs. duration 705 BBL-Oil 690 GOR 587 F.T. Press. 12/64" choke Calculated 24-Hour Rate- 1720 BBL-Oil 405 MCF-Gas 170 MCF-Gas 1500 Csg. Press. 0 BBL-Wtr 210 BBL-Load Water 27 Degrees API BADAMI EXPLORATION WELL-DAILY DRILLIING REPORTS 2/6/90- Day 1' Spudded 19'30 2/5/90, drilled and surveyed to 550'. drilling at 550'. Now 2/7/90' Day 2' Drilling at 1435' TVD progress 885'. Drilled and surveyed to 791', tripped for new bit, reamed to bottom, drilled to 1435'. 2/8/90- Day 3' Drilled to 1703'MD. Pulled out of hole and picked up mud motor. Drilling and building hole angle at 2064'MD. MD progress 629' TVD progress 628' ~ · 2/9/90' Day 4- Drilled with motor from 2064' MD (2063' TVD) to 2560'MD (2547' TVD). Trip for new bit. Working on iron roughneck. MD progress 496' TVD progress 484' 2/10/90' Day 5- TD-2708'MD, 2693'TVD Progress-148'. Repairing rig, TIH, drill to 2708'MD, Motor quit, POOH. 2/11/90' Day 6' TD-3528'MD, 3477'TVD Progress-820'. Tripped in hole, drilled and surveyed to 3528', short trip, repair rig. 2/12/90- Day 7' TD-3528'MD, 3477'TVD, Progress -0- Repair rig, POOH, Ran logs, Now tripping in hole. 2/13/90' Day 8- Circulate BU, POOH, RU and run 89 joints 13 3/8" casing, set at 3512'MD. RU and cement with 716 barrels of cement. Displace cement with 500 barrels mud. Cement circulated to surface. WOC. 2/14/90' Day 9' Depth- 3528'MD, Progress' -0-. ND diverter, Heat and weld on adapter. NU. 2/15/90' Day 10' Nipple up and test blow out preventors. 2/16/90' Day 11- Continue to nipple up and test BOPs. 2/17/90' Day 12- Depth- 3560'MD, 3507'TVD, 32' prog. Finished nippling up and testing BOPs, drilled out cement, shoe and 10' of formation. Ran leakoff test to 12.5ppg. Now drilling at 3560'. 2/18/90' Day 13- Depth- 3853'MD, 3780'TVD, 293' prog. Drilled to 3631', POOH for BHA change, TIH and drilled to 3853'. Now cleaning up mud due to contamination with spud mud. 2/19/90- Day 14' Depth- 4222'MD, 4125'TVD, 369' prog. Finished cleaning up mud, drilled and surveyed to 4222', POOH for BHA change. 2/20/90' Day 15- Depth' 4731'MD, 4593'TVD, Prog' 509'. Finished out of the hole, PU new BHA, TIH, drilled to 4731', short trip to shoe, hole very tight. ~EC~iV[D 2/21/90' Day 16' Depth' 5385'MD, 5194'TVD, Prog' 654' Finished short trip, drilled to 5385', POOH, pulling somewhat tight. PU new BHA, TIH. 2/22/90: Day 17: Depth: 5610'MD, 5399'TVD, Prog: 225'. Finished in hole, reamed to bottom, drilled with motor to 5610', circulate and condition hole, POOH, PU packed BHA, TIH to shoe, repair rig. TIH to bottom, reamed motor run. 2/23/90' Day 18' Depth- 6,610'MD, 6314'TVD Prog- 16060100' Drilled and surveyed to 6137' short trip, dri'lled to ", POOH for new bit. 2/24/90- Day 19' Depth- 6920'MD, 6597'TVD, Prog- 310'. Finish trip for BHA, repair rig, TIH, drill and survey to 6920'. 2/25/90- Day 20' Depth- 7513 'MD, 7139'TVD, Prog' 593'. Drill and survey to 7513' trip for new bit , · 2/26/90' Day 21- Depth- 8230'MD, 7794'TVD, Prog' 717'. Finished bit trip, drill and survey to 8230'. 2/27/90' Day 22' Depth- 8,690'MD, 8,215'TVD, Prog' 460'. POOH for new bit. Repair rig and slip drilling line. TIH, drill and survey to 8,690' MD. 2/28/90- Day 23- Depth- 9,030'MD, 8,526'TVD, Prog' 312'. Drill and survey to 8,718'MD. POOH for new bit. Repair mud pump. TIH, drill and survey to 9,030'MD. 3/1/90' Day 24' Depth' 9550'MD, 9001'TVD, Prog- 477'. Drilled and surveyed to 9550'. 3/2/90- Day 25- Depth- 9630'MD, 9123'TVD, Prog' 80'. Drilled to 9577', POOH, test BOPs-OK, PU new motor and BHA, TIH, drill to 9630'. 3/3/90' Day 26- Depth' 9840'MD, 9318'TVD, Prog' 210'. Drilled to 9730', lost 500psi, trip for washout, POOH, PU new BHA, TIH, drill to 9840' 3/4/90' Day 27' Depth- 10302'MD, 9689'TVD, Prog' 462'. Drill and survey to 10302', 5 hours rig repair, raise MW to 10.0 3/5/90' Day 28- Depth' 10768'MD,.10033'TVD, Prog' 466'. Drill to 10520', raise MW to 10.6 Drill to 10676', short trip. Drill to 10768', circulate and condition mud. 3/6/90: Day 29: Depth: 10768'MD. 10173'TVD (corrected), Prog: -0-. Circulate and condition gas cut mud. Shut in well, no pressure. Circulate and raise mud weight to 11.1. Short trip to 9403' ream last 15' to TD. Circulate and condition heavily gas cut mud. Close annular and circulate through choke while raising mud weight to 11.5ppg. 3/7/90: Day 30: Depth: 10770'. Circulated and conditioned mud, lost 125 bbls while circulating on choke. Observe well, no flow, spot 95 bbls 12.5 mud on bottom. POOH, SLM +2'. RU and log run #1- GR/LSAC/DIFL/SP, Logs would not go below 10,755'. 3/8/90: Day 31: Depth: 10770'MD. 10175' TVD. Prog: -0-. Finished log run #1, log run #2, ZDL/CN/GR/DELI-Cal. RU and run SWCs. 50 shot, 42 recovered, 2 lost. RD loggers and PU BHA. 3/9/90: Day 32: Depth: 10770'MD. 10174' TVD. Prog: -0-. Finished PU BHA, TIH to shoe, break circulation, TIH to 7005', break circulation, TIH to TD, wash 10' to bottom. Circulate and condition mud on choke, raise mud weight to 11.7. 3/10/90: Day 33: Depth: 10,770'MD, 10,174'TVD, Prog: O. Circulate and condition mud to 11.7ppg, spot 90 barrels of 12.5ppg mud on bottom. Pull 10 stands and observe well. POOH. Change rams, RU and begin running 9 5/8" casing. 3/11/90: Day 34: Depth: 10,770'MD, 10,174'TVD, Prog: O. Finish running casing to TD, washed down last joint. Circulate bottoms up, gas increased from 250 units to 4000 units. RU and pump 5 bbls water, 28 bbls spacer and 147 bbls (700 sks) 15.6ppg cement. reciprocate casing throughout. Set casing at 10,763' MD, 10,168'TVD. RD cementers. Evacuate water from cellar and grout in foam around conductor. RU and run gyro while WOC. 3/12/90: Day 35: Depth: 10,770'MD, 10,174'TVD, Prog: O. Finish running gyro survey, set slips, ND and NU. Test BOPs and related equipment to 5000 (3000 Hydril) /250psi. Laydown 8" BHA, PU 6 1/2" BHA and TIH. 3/13/90: Day 36: Depth: 10,890'MD, 10,284'TVD, Prog: 120. TIH, test casing to 2550psi-OK. Drill float, cement and shoe. Had false high level H2S alarm, secured well, determined alarm was false. Drilled 11' of formation, tested formation to leak-off, 14.6 ppg. Drilled to 10,819, lost 400 psi pressure, POOH, had leak in slip area 37 stands in. TIH, drilled to 10,845, circulated up drilling break, well trying to flow, circulated out gas, well dead, now drilling at 10,890'. CI-: 1200 3/14/90: Day 37: Depth: 11,200'MD, 10,577'TVD, Prog: 315'. Drilled to 11,022', circulated out connection gas and increased MW to 12.0ppg. 3/15/90: Day 38: Depth: 11,420'MD, IO,803'TVD, Prog: 220'. 11,420'. Drilled to 3/16/90: DaY 39: Depth: 11543'MD, 10,925'TVD, Prog: 133. POOH, TIHw/ new bit, drill from 11420 to 11543. CI-: 1100 3/17/90: Day 40: Depth: 11,770'MD, 11,143'TVD, Prog: 227'. Drilled to 11,770'. 3/18/90: Day 41: Depth: 11,980'MD, 11,347'TVD, Prog: 210'. POOH for new bit, Test BOPs to 250/5000psi, Hydril to 250/2500psi, all OK. PU new PDC bit and mud motor, TIH. Wash down last 35' (10' of fill). Drill to 11,980'. CI-: 1100 3/19/90' Day 42' Depth: 12,232'MD, 11,592'TVD, Prog: 252' Drilled to 12,232', ROP dropped drastically, samples showed 'darker shale (top of Hue?). Circulate, POOH, laydown motor, PU new bit, TIH. 3/20/90- Day 43' Depth- 12,537'MD, 11,889'TVD, Prog' 305' Finished in hole, reamed last stand, drilled to 12,537'. W~ight was allowed to decrease to 11.9ppg. Background and connection gas increased and the size of the shale cuttings increased. Weight increased back up to 12.0ppg. Estimate core point at 12,560'. 3/21/90- Day 44- Depth' 12,562'MD, 11,914'TVD, Prog' 25'. Drilled to core point at 12,560' Circulated and conditioned hole, POOH. PU core barrels an~ bit. TIH, wash down last 10'. Core to 12,562' (2'), barrel jammed. Attempt to unjam barrel, no success. POOH. C1- 1100 3/22/90: Day 45: Depth: 12,565'MD, 11,917'TVD, Prog: 3'. Finished out of hole, core barrel jammed due to fractured core. TIH, core to 12,565' (3') in 4 hours, short trip, attempt to core, no success. POOH, core barrel jammed with fractured core. Laydown core barrel, PU new BHA and bit, TIH. C1- 1100 3/23/90: Day 46: Depth: 12,605'MD, 11,956'TVD, Prog: 40'. Finished in hole, reamed last two joints, had 15' fill on bottom. Drilled to 12,605', circulated and conditioned, raised mud weight to 12.5ppg due to shale instability. POOH, PU core barrel and bit. C1- 1000 3/24/90' Day 47' Depth' 12,655'MD, 12,006'TVD, Prog' 50'. PU core bit and barrel, TIH, circulate down last joint. Core from 12,605'to 12,652', shut down for invalid H2S alarm. Core to 12,655'. 3/25/90: Day 48: Depth: 12,666'MD, 12,016'TVD, Prog: 11'. Core to 12,666', POOH to 4033', laydown grade E drill pipe. Laydown core, PU new inner barrel, test BOPs, manifold and accumulator, all OK. TIH, PU S-drill pipe, SLM. CI-: 1100 3/26/90' Day 49' Depth' 12,704'MD, 12,054'TVD, Prog' 38'. Finish in hole, picking up S drill pipe, circulate down to bottom, core from 12,666' to 12,704', bit quit drilling, circulate and condition, POOH. C1-' 1000. 3/27/90' Day 50' Depth' 12,710'MD, 12,060'TVD, Prog' 6'. POOH, laydown core and BHA. PU new bit and BHA and TIH. TIH to 12,526', reamed to bottom, drill to 12,710'. C1-' 1000. 3/28/90: Day 51: Depth- 12,822'MdD~ 12,173'TVD, Prog:rclu~2a't Drill top12,716' check for flow, ill to 12,726', ci e bottoms u . Drili to 12,744', check for flow, drill to 12,764', circulate bottoms up. Drill to 12,806', check for flow, drill to 12,822', circulate bottoms up. POOH, PU core bit and barrel. 3/29/90: Day 52: Depth: 12,884'MD, 12,234'TVD, Prog: 60'. Trip in hole with core bit, ream down last 5 joints. Core to 12,884'. Pump out first joint, POOH. CI-: 1000. 3/30/90: Day 53: Depth: 12,915'MD, 12,265'TVD, Prog: 31'. Finish out of the hole with core #5, recovered 60'. TIH with new BHA, repair remote BOP panel, ream from 12,814 to 12,884, circulate bottoms up, drill to 12,915'. Cl-: 1000. 3/31/90: Day 54: Depth: 13,123'MD, 12,469'TVD, Prog: 208'. Drill to 13,123' 4/1/90: Day 55: Depth: 13,137'MD, 12,483'TVD, Prog: 14'. POOH, PU new bit, test BOPS and all related equipment-OK. TIH, ream from 13,091 to 13,123, drill to 13,137'. CI-: 900. 4/2/90: Day 56: Depth: 13,281'MD, 12,624'TVD, Prog: 144'..Drill to 13,281'. 4/3/90: Day 57: Depth: 13,315'MD, 12,654'TVD, Prog: 34'. Drilled to 13,308', circulated and conditioned mud. POOH, PU new bit and new jars, TIH, drill to 13,315'. CI-: 900. 4/4/90: Day 58: Depth: 13,497'MD, 12,834'TVD, Prog: 182'. Drilled to 13,497'. 4/5/90: Day 59: Depth: 13,595'MD, 12,930'TVD, Prog: 98'. Drilled to 13,595', short trip to casing shoe at 10,763', TIH to TD, circulate and condition for logging. CI-: 900. 4/6/90: Day 60: Depth: 13,595'MD, 12,930'TVD. POOH to log. RU and TIH with DIL-BHC-GR, could not get below 12,330'. POOH, tool dragging. TIH to 12,324', ream interval to 12,354', hole tight. Circulate and condition mud, trip gas peaked at 5000, TIH to TD. CI-: 900. 4/7/90: Day 61: Depth: 13,595'MD, 12,930'TVD. Circulate and condition mud, raise mud weight to 12.8ppg. POOH, work tight spot at 12,230', drag has decreased. Finish out of hole. RU and run in hole with logs to 13,108', could not go deeper. Attempted to log up, tool stuck when density arm opened up. Could not get indication of arm closing, and line parted 4' above rope socket with 5200 lbs tension(weak point set at 8000 lbs. Where line parted in bridle, rated to 14,000 lbs). Tested BOPs and related equipment-OK. PU fishing assembly and TIH. CI-: 800. 4/8/90: Day 62: Depth 13,595'MD, 12,930'TVD. TIH with fishing assembly to top of fish. PU kelly and work down over fish. Latched fish and pulled free with 20,000 overpull. POOH with fish, break out fish. PU new bit and BHA, TIH to 12,300', ream hole and circulate and condition mud. CI-: 800. 4/9/90: Day 63: Depth 13,595'MD, 12,930'TVD. Ream tight spots down to 13,128'. Circulate and condition mud, lowering fluid loss and raising pH. Short trip to casing shoe, tight spot at 13,080, work through tight spot. TIH to TD, no tight spots. Circulate and condition mud, POOH, no tight spots. C1- 800. 4/10/90: Day 64: Depth: 13,595'MD, 12,930'TVD. Finish out of hole. RUwireline and run logs. #1-DIFL-ZDL-CNL-GR-Cal, #2-ArrayAcoustic, #3- Dipmeter. Minor tight spots. RD Western Atlas, RU Halliburton for SWCs. Cl-: 800. 4/11/90: Day 65: Depth: 13,595'MD, 12,930'TVD. Finish RU Halliburton Logging. Run #4-SWC(rotary) core barrel jammed after two cores. Run #5- SWC, attempt 32, recover 24. RD HLS, PU BHA, TIH to TD, no tight spots. Circulate and condition mud. CI-: 800. 4/12/90: Day 66: Depth: 13,595'MD, Final Calculated TVD: 12,922,. Final BHL, 3784'N, 275'W of surface. Finished circulating and conditioning mud. Drop multishot, POOH. RU and run log #6- VSP, from 13,570'. C1- : 800. 4/13/90: Day 67: PBTD +/- 11,100'MD. Finish run #6-VSP. PU cement sub and 3 1/2" DP. TIH with 5" DP. Respot HW and DCs. Finish in hole with DP. Circulate BU, set plug #1 from 13,396' to 13,002' with 39 bbls cement. PU to 13,000', set plug #2 from 13,000' to 12,500'. POOH to 11,316'. Set plug #3 to 11,100' with 30 bbls cement. POOH to 9 5/8" shoe, circulate bottoms up. POOH laying down excess 5" DP and 3 1/2" tail pipe. Cl-: 800. 4/14/90: Day 68: PBTD 11,190'MD. Finish laying down 3 1/2" DP and finished POOH. PU RTTS and TIH to 10,750'. Set RTTS and test 9 5/8" casing to 3500 psi-OK. Circulate bottoms up, hold H2S drill, POOH. PU bit and TIH. Tag top of cement plug at 11,190'MD. Set down 25,000 lbs on cement-OK. Cl-: 800. 4/15/90: Day 69: PBTD 11,190'MD. PU to 11,000', circulate bottoms up. POOH. Test all BOPs and related equipment-OK. Laydown excess drill collars and HW. PU DST assembly, TIH with DST assembly, filling with diesel. Switched over to filling drill pipe with water due to excess foaming of diesel. Testing drill pipe and assembly to 5000 psi every 20 stands. C1- 800. 4/16/90: Day 70: PBTD 11,190'MD. Finish in hole with test assembly. RU test head and test manifold. Pressure test all surface equipment. RU and run initial flow and build up, begin final flow period. 4/17/90: Day 71: PBTD 11,190'MD. Continue with DST #1. C1-700 4/18/90: Day 72: PBTD 11,190'MD. Finish final build up for DST #1. Attempt to open Omni valve-no good. Shear open reversing valve and reverse out. Could not open bypass on RTTS, release packer and bullhead rathole fluid into formation. Circulate and condition well, circulate until BGG down to reasonable levels. POOH. 4/19/90' Day 73' PBTD 11,190'MD. Finish POOH, lay down test tools, TIH, stand backHW, finish in hole, circulate and condition mud. C1-'900 4/20/90' Day 74' PBTD 10,883'MD. Circulate and condit~ion mud. RU and pump 38 barrels of cement from 11,190'to 10,850'. PU 10 stands, circulate and condition mud, POOH. PU bit and DCs, TIH to 10,831', PU kelly, set down 20,000 lbs and wash down to 10,883' Circulate and condition mud, POOH. PU test tools and begin TiH for DST #2. CI-: 800 4/21/90- Day 75- PBTD 10,883'MD. PU test tools and TIH, testing to 5000 psi. RU and test surface equipment, set packer at 10,733'. Begin DST #2. C1 -' 800 4/22/90- Day 76- PBTD 10,883'MD. Continue DST #2. C1-' 800 ,. 4/23/90' Day 77' PBTD 10,660'MD. Finish final build up, bullhead fluid below packer into formation, circulate and condition well. POOH. PU EZSV and TIH. Set at 10,713'MD, PU and circulate down 5 bbls water, 26.6 bbls cement. Sting into EZSV and pump all except 5 bbls cement below retainer. PU and spot 5 barrels cement above retainer.~ POOH 6 stands and reverse out to surface. Close annular and pressure up to 2600 psi for 30 minutes-OK. POOH, laying down drill pipe. ._ 4/24/90' Day 78' Finished laying down drillP~ipe. TIH with HW and laydown same. Clean out pits and test tanks and inject liquid in 9 5/8" X 13 3/8" annul us. 4/25/90. Day 79- Clean pits, waste water tanks, dewatering unit tanks and celler. Injecting all liquids into annulus. TIH with DP to 200'. 4/26/90: Day 80: Finished cleaning pits and injecting into annulus. RU and established injection into 13 3/8" X 9 5/8" annulus at 5BPM. Mix and pump 200 sacks Permafrost cement, displaced to 1423'. SI annulus with 500 psi. WOC, PU casing cutter and TIH to 190'. Bled pressure off annulus and cut 9 5/8". POOH with cutter and ND BOPs. Dewatering unit released at noon-4/25/90. 4/27/90' Day 81' Finish ND BOPs, PU spear, TIH and retreive 9 5/8" casing, POOH and laydown casing. ,TIH and set bridge plug in 13 3/8" casing at 178'. Cut 13 3/8" casing and remove wellhead. TIH and pump 240 sacks permafrost cement from 178' to surface. Release rig at 3PM, 4/26/90. Note- Temp yesterday was up to 37F with some rain. ~ ._ Conoco Inc. Suite 200 3201 C Street Anchorage, Al( 99503 (907) 564-7600 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 June 11, 1990 Dear Mr. Grant: The following is my description of cores 1 and 2 from Conoco's Badami # 1 well, which is located in Section 9, T 9N, R 20E on the North Slope of Alaska. These data are strictly CONFIDENTIAL. LITHOLOGIC DESCRIPTION-- CORE #1 Cut: 2.0', Recovered: 1.0' 12,560.0'- 12,651.0' Silty shale: dark gray to black, very firm to hard, brittle, slightly calcareous, common minute flakes of mica, subfissile. Fluorescence: none. Solvent cut fluorescence: dull yellow. Solvent cut: clear, but leaves pale amber ring around spot dish. LITHOLOGIC DESCRIPTION-- CORE #2 Cut: 3.0', Recovered: 3.0' 12,562.0' - 12,565.0' Silty shale: black, hard, brittle, slightly calcareous, common flakes of mica, subfissile. Fluorescence: none. Solvent cut fluorescence: light yellow. Solvent cut: clear to very pale brown; one sample left a faint amber ring around spot dish. Should you have any questions, please telephone me at 564 - 7640. Staff Geologist SFD(lrl) R. F. Wheeler 390.08.07 DAVIESI\CORI&2AO Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: June 11, 1990 RECEIVED JUN 1 1990 .Oil & Gas Cons. Commissl_or~ chorage The following is my description of core #3 from Conoco's Badami # 1 well, which is located in Section 9, T 9N, R 20E on the North Slope of Alaska. These data are strictly CONFIDENTIAL. LITHOLOGIC DESCRIPTION-- CORE #3 Cut: 60.0 feet Recovered 57.5 feet. 12,606.0' - 12,637.8' Siltstone: dark gray, very dark gray, and black; hard, homogeneous, slightly calcareous. Lower boundary gradational. Fluorescence: generally none, but some samples display a spotty, faint to bright yellow. Solvent cut fluorescence: faint yellow, less commonly light yellow, with scattered, slow streams. Solvent cut: clear, but generally leaves a very faint brown ring in spot dish. 12,637.8' - 12,638.4' Siltstone: black to dark gray, hard, very slightly calcareous, homogeneous, contains minor erosional surfaces. Beds are draped over a very large, hard siltstone cobble. Lower boundary sharp, irregular. Fluorescence: none. Solvent cut fluorescence: slow, pale milky yellow. Solvent cut: clear, leaves light brown ring on spot dish. 12,638.4' - 12,641.8' Silty shale: black to very dark gray, as 12,606.0', but with scattered, thin (<8 mm thick) lag deposits of medium sand- to pebble-sized quartz, chert, and siltstone rip-up clasts. Lower contact sharp. Fluorescence: none. Solvent cut fluorescence: scattered, very slow, very pale yellow streams. Solvent cut: clear. 12,641.8' - 12,642.0' Siltstone: medium brown to buff, bedding distinctly crenelate. Lower boundary gradational. 12,642.0'- 12,642.7' Sandy siltstone: dark brown to dark gray, somewhat mottled in appearance. Common pebble-sized chert grains and rip-up clasts of siltstone. Lower contact smooth. 12,642.7' - 12,643.0' Granular conglomerate: siltstone matrix as above, with very abundant granules and scattered pebbles of quartz, chert, and rip-up clasts of siltstone. Lower boundary irregular, sharp. 12,643.0' - 12,653.0' Silty shale: black to dark gray, very firm, slightly calcareous, subfissile. Internal bedding vague, chaotic. Lower boundary gradational. Fluorescence: none. Solvent cut fluorescence: none to very slow, faint milky yellow. Solvent cut: clear. 12,653.0' - 12,661.0' Shale and silty shale: black to dark brownish-gray, very firm, non- calcareous; organic shale which becomes siltier downward. Internal bedding is slightly irregular to wavy. Lower contact sharp. Fluorescence: none. Solvent cut fluorescence: instantaneous, very faint milky white to slow, pale yellow. Solvent cut: clear. 12,661.0' - 12,663.4' Silty shale: as above, but very slightly calcareous. Internal bedding poorly displayed, irregular. Fluorescence: none. Solvent cut fluorescence: slow to very slow, very faint milky white. Solvent cut: clear. Should you have any questions, please telephone me at 564 - 7640. Staff Geologist SFD(lrl) CC: R. F. Wheeler 390.08.07 RE EIV£D dUN 1 3 '~990 .0Il.& Gas Cons. ,, ~nchorago DAVIES\COR3AOGC Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: RE( EIVED JUN 1 3 i990 0it & Gas Cons. Anchorage June 11, 1990 The following is my description of core #4 from Conoco's Badami # 1 well, which is located in Section 9, T 9N, R 20E on the North Slope of Alaska. These data are strictly CONFIDENTIAL. LITHOLOGIC DESCRIPTION-- CORE #4 Cut: 38.0 feet, Recovered 39.5 feet. 12,665.3' - 12,669.7' Shaly siltstone: very dark gray, hard, non-calcareous, sub-fissile, trace very fine quartz sand, trace biotite. Scattered laminae of coal and medium gray sandy siltstone. Internal bedding wavy to slightly irregular. Lower boundary gradational. Fluorescence: none. Solvent cut fluorescence: none. Solvent cut: clear. 12,669.7'- 12,676.4' Muddy siltstone, siltstone, and silty shale: dark gray to black, hard, subfissile to fissile, non-calcareous. Common to abundant coal and carbonized plant fragments, scattered very fine quartz sand, trace biotite. Common wavy to slightly irregular, very thin beds (average 10 mm) of sandy siltstone. Scattered small scale syn-depositional faults. Lower boundary sharp. Fluorescence: none. Solvent cut fluorescence: none. Solvent cut: clear. 12,676.4'- 12,690.1' Siltstone, silty shale and shale: gray to black, hard, blocky to fissile, non-calcareous, occasionally very siliceous. Abundant to common coal and carbonized plant fragments, trace to abundant biotite, trace quartz sand. Scattered, very thin beds (5 to 10 mm thick) of siltstone. Irregular to wavy internal bed boundaries, with a few small syn- depositional faults. Lower boundary gradational. Fluorescence: none. Solvent cut fluorescence: typically none, but one sample is very faint white to yellow-white. Solvent cut: clear. 12,690.1'-12,692.8' Siltstone: medium to dark gray, very firm, subfissile, slightly calcareous. Common small carbonized plant fragments, trace biotite. Internal bedding ranges from homogeneous to poorly defined, with medium gray laminae resulting from slight grain size changes. Lower boundary sharp. Fluorescence: none. Solvent cut fluorescence: none. Solvent cut: clear. 12,692.8'- 12,697.4' Silty shale: very dark brownish-gray to black, very firm, subfissile. Trace disseminated pyrite, trace biotite. Highly organic: coal occurs in abundant very thin (lmm) seams and is also disseminated throughout. Lower boundary sharp. Fluorescence: none. Solvent cut fluorescence: very slow, very faint milky yellow. Solvent cut: clear. 12,697.4'- 12,699.1' Sandy siltstone: medium gray and medium brown, hard. Internal bedding consists of poorly to well developed very thin laminae (average 1 mm); bed boundaries are wavy to slightly irregular. Abundant horizontal burrows, 1 1/2 to 8 mm in diameter are concentrated along bed boundaries. Lower boundary sharp. 12,699.1'- 12,700.6' Siltstone: dark gray, hard, homogeneous, trace very fine quartz and possible trace pyrite. Common contorted bedding with scattered, small, syn-depositional faults. Scattered subhorizontal stylolites. Common, very thin (1/2 mm), irregular fractures filled with silica. Base of interval has common horizontal burrows. Lower boundary sharp. Fluorescence: none. Solvent cut fluorescence: very slow, scattered streams, pale milky yellow. Solvent cut: clear. 12,700.6'- 12,704.5' Siltstone: dark gray to black, hard, homogeneous; non-calcareous, cement is amorphous silica. Trace of medium to coarse quartz sand, possible trace disseminated pyrite. Interval ranges from homogeneous to bedded with thin (1 to 6 mm), dark gray layers of muddy siltstone. Fluorescence: none. Solvent cut fluorescence: very slow, very faint streams of moderately bright milky yellow. Solvent cut: clear. Should you have any questions, please telephone me at 564 - 7640. Steve Davies Staff Geologist SFD(lrl) R. F. Wheeler 390.08.07 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: June 11, 1990 RE( EIVED JUN I 3 1990 .Oil .& Gas Cons. t;ornmission :Anchorage The following is my description of core #5 from Conoco's Badami # 1 well, which is located in Section 9, T 9N, R 20E on the North Slope of Alaska. These data are strictly CONFIDENTIAL. LITHOLOGIC DESCRIPTION-- CORE #5 Cut: 60.0 feet, Recovered 59.5 feet. 12,824.0'-12,825.5' Sandy siltstone: dark brown, hard, homogeneous, well cemented, non-calcareous, abundant very fine sand. Small amount of oil and gas bleeding from scattered parting planes. Upper 0.4 feet of interval are rubble. Fluorescence: very dull gold patches corresponding to bleeding oil and gas. Solvent cut fluorescence: rapid, milky yellow. Solvent cut: clear, but leaves very faint brown ring in spot dish. Tuff: light gray, hard, homogeneous, subfissile, non-calcareous. Present in rubble zone. Fluorescence: bright light yellow. Solvent cut fluorescence: none. Solvent cut: clear. 12,825.5'- 12,826.9' Siltstone: medium gray, hard, homogeneous, non-calcareous. Upper 0.6 feet of interval are rubble. Scattered erosional surfaces with thin zones (< 2 inches thick) of pebble-sized rip-up clasts of siltstone, coaly plant fragments, and very fine sand imbedded in a white, non-calcareous (tuff?) matrix. Lower boundary sharp. Fluorescence: overall - none; white (tuff?) matrix: uniform pale yellow. 12,826.9'- 12,830.6' Sandstone: medium to light brown, firm, very fine, subangular, non- calcareous, poorly sorted with common silt, trace glauconite. Internal bedding consists of subhorizontal to slightly inclined laminae. Scattered syn-depositional microfaults, contorted bedding, and minor erosional surfaces. Scattered stylolites; lower contact is a stylolite. Oil stain: upper 0.9' has uniform very light brown stain. Fluorescence: uniform, very faint dull gold. Solvent cut fluorescence: scattered slow milky yellow streams, solvent turns moderately bright milky yellow. Solvent cut: clear, may leave pale brown ring in dish. 12,830.6' - 12,831.4' Siltstone and silty sandstone: light to dark gray to medium brownish- gray, hard, homogeneous, well cemented, non-calcareous. Abundant silt, abundant rip-up clasts (3 to 10 mm) of siltstone. Faint, subhorizontal internal structure with scattered stylolites. Lower contact gradational. 12,831.4' - 12.835.4' Silty sandstone: medium gray, medium grayish-brown, light brown, firm, very fine, subangular, poorly sorted with abundant silt and rare siltstone rip-up clasts. Common carbonized plant fragments. Internal structure poorly displayed, homogeneous to faint subhorizontal laminae. Lower boundary gradational. Fluorescence: uniform, very dull gold. Solvent cut fluorescence: rapid, uniform milky yellow, solvent becomes moderately bright milky yellow. Solvent cut: clear. 12,835.4'- 12,838.4' Silty sandstone: medium grayish-brown to medium brown, firm, very fine, subangular, poorly sorted with common silt, trace mica, and trace glauconite. Upper 1.0' shows even, parallel, slightly wavy laminae and highly contorted bedding with scattered, irregular erosional surfaces. Lower portion is homogeneous. Lower boundary is a stylolite. Fluorescence: uniform very faint dull gold. Solvent cut fluorescence: rapid, uniform milky yellow, solvent becomes moderately bright milky yellow. Solvent cut: clear. 12,838.4'-12,840.7' Sandy siltstone: medium gray to light brownish-gray, hard, lithology as above, but slightly finer average grain size; sand content increases downward. Subhorizontal internal structure poorly developed. Scattered stylolites. Lower boundary smooth, sharp. Fluorescence: uniform very dull gold. Solvent cut fluorescence: slow, uniform pale dull yellow; becomes moderately bright yellow. Solvent cut: clear. RECEIVED dUN I 3 1990 Alaska Oil & Gas Cons. uommission Anchorage 12,840.7' - 12,841.5' Silty sandstone: medium brown, hard, very fine with abundant silt. Contorted internal structure at top of interval, grades downward to faint, subhorizontal laminae. Lower boundary gradational. 12,841.5' - 12,842.3' Sandy siltstone: medium gray, homogeneous, abundant very fine sand, scattered carbonized plant fragments, trace glauconite. Lower contact is gradational. Fluorescence: uniform, very dull gold. Solvent cut fluorescence: slow, uniform dull yellow. Solvent cut: clear. Silty sandstone: dark brown to medium brown, very fine grained, subangular, poorly sorted with very common silt, well cemented, slightly calcareous, abundant biotite. Dark to medium brown sand grains set in a white (tuff?) matrix. Fluorescence: none. Solvent cut fluorescence: none. Solvent cut: clear. 12,842.3'-12,843.5' Silty sandstone: medium brown, very fine, poorly sorted, well cemented, slightly calcareous. Upper 0.3 feet show some mildly contorted bedding. Lower portion of interval shows well to very poorly developed subhorizontal laminae. Lower boundary gradational. 12,843.5'-12,844.3' Sandy siltstone: as 12,838.4'. Interval between 12,843.7' and 12,844.0' is rubble. Some contorted beds in lowest 0.1 feet. Lower contact is sharp, slightly irregular and appears erosional. 12,844.3' - 12,845.0' Silty sandstone and siltstone: mediumbrownish-gray and medium gray, hard, well cemented, non-calcareous, wavy interbeds 1/4 to 1/2 inch thick; siltstone becomes dominant downward. Common subhorizontal stylolites. 12,845.0'- 12,846.8' RECEIVED JdN 1 5 '~990 Alaska Oil & Gas Cons. G0.m01ioSk0Jl Anchorage Siltstone and slightly sandy siltstone: medium gray and medium to light brown, hard, common very fine sand, poorly sorted, well cemented. Siltstone dominates. Common mica, glauconite, and carbonized plant fragments. Parts along subparallel, slightly irregular surfaces. Internal bedding surfaces smooth to slightly wavy, subhorizontal and subparallel. Scattered very thin, slightly irregular laminae of dark gray mudstone. Scattered stylolites. Lowest portion shows poorly developed, very small scale ripple foresets. Sample from 12,845.0' shows some parting surfaces that are coated with a thin (1/5 to 1 mm thick) layer of black asphaltic oil. Lower contact is gradational. Fluorescence: uniform very dull gold; asphaltic oil does not fluoresce. Solvent cut fluorescence: slow, uniform milky yellow, with scattered slow streams; becomes moderately bright milky yellow. Solvent cut: clear. 12,846.8' - 12,847.6' Sandy siltstone: medium gray to light gray brown, hard. Contorted bedding in upper 0.8' and at base of interval; remainder displays scattered, smooth, subparallel, subhorizontal laminae. Lower boundary sharp and straight. 12,847.6' - 12,848.1' Siltstone: medium to light grayish brown, hard, poorly sorted with occasional very fine sand, common mica, trace glauconite. Parts along subconchoidal surfaces. Very poorly developed subhorizontal laminae. Lower boundary is a low amplitude, irregular erosi6nal surface. Fluorescence: none. Solvent cut fluorescence: slow, uniform dull yellow, becomes moderately bright yellow. Solvent cut: clear. 12,848.1- 12,850.0' Sandy siltstone: light brown, hard, homogeneous, scattered very faint subhorizontal bedding. Abundant, small "ball and pillow" structures occur from 12,849.1 to 12,849.3'. Lower contact gradational. 12,850.0' - 12,852.9' Siltstone and slightly sandy siltstone: medium to light brown, hard, homogeneous with some scattered subparallel, subhorizontal laminae. Parts along smooth, subparallel surfaces. Abundant carbonized plant fragments. Lower boundary gradational. Fluorescence: uniform, dull yellow-gold. Solvent cut fluorescence: very slow, uniform dull yellow, becomes moderate yellow. Solvent cut: clear. 12,852.9' - 12,854.0' Silty mudstone and mudstone: black to very dark gray, hard, brittle, non-calcareous, subfissile, trace mica. Internal bedding is poorly to well R E C [ IV E D displayed: even, parallel, subhorizontal laminae. Contains scattered, thin lamina (1/2 mm) of very fine grained, non-calcareous sandstone, having a trace of glauconite. Lowest 0.4' is a hard, homogeneous, dUN 1 5 19~0 __h~i~hly carbonaceous mudstone. Lower boundary is gradational. ^laska 0il & t~as Cons. G0.nll!l/~rescence: none. Solvent cut fluorescence: slow, uniform dull ^nch0ra[i~t "~' yellow; becomes very pale milky yellow. Solvent cut: clear. 12,854.0'- 12,857.5' Sandy siltstone: as 12,852.9', but slightly coarser average grain size. Organic rich--common coal stringers throughout sample at 12,856.0'. Internal bedding poorly to well developed, smooth to slightly wavy, subparallel laminae. Fluorescence: none. Solvent cut fluorescence: very slow, diffuse, pale milky yellow; becomes uniform pale milky yellow. Solvent cut: clear. 12,857.5' - 12,861.4' Mudstone: black to very dark gray, hard, non-calcareous, subfissile, parts along smooth, subparallel, subconchoidal surfaces. Sample at 12,859.0' contains common coal, common mica, and displays a trace of bleeding oil. Fluorescence: none. Solvent cut fluorescence: very pale dull yellow. Solvent cut: clear. 12,861.4'- 12,864.4' Siltstone and mudstone: very dark gray to black, hard, subfissile, carbonaceous, non-calcareous. Laminated siltstone and mudstone, with siltstone dominating. Irregular internal bedding surfaces. Scattered evidence of soft sediment deformation (ball and pillow structures, one micro-fault). Fluorescence: none. Solvent cut fluorescence: none. Solvent cut: clear. 12,864.4'- 12,867.0' Siltstone and mudstone: as above, but with rolled and slumped internal bedding that has apparent inclination from 15 to 40 degrees. Fluorescence: none. Solvent cut fluorescence: single slow, milky yellow stream; solvent eventually becomes pale milky yellow. Solvent cut: clear. 12,867.0'- 12,873.0' Siltstone: very dark gray to black, hard, homogeneous, subfissile, non-calcareous, common carbonized plant fragments, trace mica. Scattered laminae of very dark gray siltstone. Some scattered contorted internal bedding. Fluorescence: none. Solvent cut fluorescence: none to extremely pale milky yellow; becomes uniform very faint milky yellow. Solvent cut: clear. 12,873.0' - 12,882.7' Silty mudstone: black, hard, subfissile, trace mica. Upper 1.3' and lowest 5.1' show poorly displayed, slightly inclined parallel bedding. Next 3.3' show slightly irregular internal boundaries with irregular bed thickness. Some soft sediment deformation is visible (irregular bedding, micro-faults). Fluorescence: none. Solvent cut fluorescence: none to very faint milky yellow. Solvent cut: clear. 12,882.7'- 12,883.5' Shale: very dark gray to black, hard, subfissile, occasionally slightly silty, non-calcareous, common carbonized plant fragments, trace mica. Poorly displayed, subhorizontal internal bedding. Fluorescence: none. Solvent cut fluorescence: none to uniform, very slow, very dull yellow. Solvent cut: clear. RECEIVED dUN 1 b 1990 Alaska Oil & Gas Cons. comm'tss/or~ Anchorage Should you have any questions, please telephone me at 564-7640. Staff Geologist SFD(lrl) R. F. Wheeler 390.08.07 DAVIESI\CORSAOGC RECEIVED JUN 1 3 1990 glas~ 0il & Gas Cons. co~nmission gnchorago CONOCO ALASKA INC. WELL: BADAMI #1 FIELD: WILDCAT ROUTINE CORE ANALYSIS MAY 1990 FILE 70076 RE( EIVED JUN t Alaska Oil & Gas Anchorage 4450 WEST 50TH AVENUE ANCHORAGE, ALASKA 99502 Mr. Rick Wheeler CONOCO, IN~. 3201 C Street, Suite 200 May 21, 1990 Re: .Core Analysis File: No 70076 Dear Mr. Wheeler. Enclosed is a final core analysis report for routine core analysis and sidewall core analysis tests performed'on material from the Wildcat Badami #1 well. Laboratory procedures have been enclosed for your reference. We appreciate this opportunity to be of service and trust these data prove beneficial to the assesment of this well. Sincerely, · P~oleu~ Testing~Services, ~}o~'l~Peter T.~Schuyler President InC · I PETROLEUM TESTING SERVICES,INC. File: 70076 Date: May 1990 Well: BADAMI #1 Field: Wildcat State: Alaska Client: CONOCO, INC. ROUTINE CORE ANALYSIS 1. Drill ~" diameter plug and trim to right cylinder. 2. Extract water and hydrocarbons from sample using Dean-Stark toluene method. Record produced water volume. 3. Vacuum dry at 150°F until weight is stable. Allow sample to cool and weigh to the nearest 0.01 gram. 4 Measure bulk volume using mercury immersion method. ~ Law helium porosimeter. 5 Measure sand grain volume using a Boyle~.~ Calculate porosity, saturations, and grain density. 6 Mount samples in a hydrostatic Hassler-type sleeve using a confining stress of 300 psi. 7 Measure permeability with nitrogen gas using a calibrated flow tube-type permeameter. I I I I t I I I I I I J J ! ! J ........ J J J PETROLEUM TESTING SERVICE, INC. Page No. File No. Date 1 70076 May 23, 1990 COMPANY CONOCO, INC. CORE TYPE 4 inch MUD TYPE WATER BASE HELIUM AIR OIL WATER TOTAL DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN ft. PERCENT mci. RATIO %PV %PV %PV CORE NO. 1 (12560.00 - 12562.00) : REC. (12560.00 - 12560.95) 12560.3 3.2 <0.1 0.02 2.3 95.9 98.2 CORE NO. 2 (12562.00 - 12565.00) : REC. (12562.00 - 12565.00) 12562.55 3.8 <0.1 0.22 15.7 72.4 88.1 12563.05 4.6 <0.1 ** 0.03 3.1 95.9 99.0 12564.55 5.4 <0.1 0.22 15.7 70.1 85.8 CORE NO. 3 (12606.00 - 12666.00) : REC. (12606.00 - 12663.40) 12606.55 2.0 <0.1 0.76 35.7 46.9 82.6 12609.65 3.5 <0.1 0.90 28.5 31.7 60.2 12610.85 3.0 <0.1 0.68 28.0 40.8 68.8 12611.25 2.9 <0.1 0.63 26.2 41.7 67.9 12612.15 2.2 <0.1 1.14 46.3 40.5 86.8 12614.65 2.2 <0.1 0.42 26.1 62.9 89.0 12615.3 2.6 <0.1 0.49 23.9 48.8 72.7 12617.55 4.1 <0.1 1.71 42.1 24.6 66.7 12618.35 3.1 <0.1 0.05 2.3 44.0 46.3 CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc 2.57 2.62 2.53 2.67 2.81 2.68 2.68 2.70 2.67 2.67 2.97 2.70 WELL BADAMI #1 FIELD WILDCAT COUNTY NORTH SLOPE STATE ALASKA LITHOLOGY Sltst;m dk gry, ct-stt w/ct-tams,pyr~fnt odor, it stn,ye[ fluor. Clst;m dk gry, cl-stt w/sit [ams,carb, n odor,strkd m stn,strkd yet fluor. Ctst;m dk gry, c[-stt w/sit lams,carb,n odor,strkd m stn,strkd yet fluor. Ctst;m dk gry, ct-slt w/sit tams,carb, n odor,strkd m stn,strkd yel fluor. Sst;olv gry, cl-vfsd,pyr,n odor,strkd m stn,strkd,yel fluor. Sst;olv gry, cl-vfsd,pyr,fnt odor, it stn,brt yet fluor. Sst;o[v gry, c[-vfsd,pyr,n odor, lt stn,strkd yet fluor. Sst;o[v gry, cl-vfsd,pyr,n odor, It stn,strkd yet fluor. Sst;otv gry, ct-vfsd,pyr,n odor, lt stn,strkd yet fluor. Sst;o[v gry,c[-vfsd,carb inc[,n odor,n stn,d[ brn fluor. Sst;o[v gry, cl-vfsd,carb inc[,fnt odor,n stn,dl yet fluor. Sst;o[v gry, cl-vfsd,pyr,fnt odor, lt stn,brt ye[ fluor. Sst;olv gry,c[-vfsd,pyr,n oder,n stn,cut fluor. ** FRACTURED, ESTIMATED AIR PERMEABILTY I I I I I ! } I I j PETROLEUM TESTING SERVICE, INC. Page No. File No. Date 2 70076 May 23, 1990 COMPANY CONOCO, INC. CORE TYPE 4 inch MUD TYPE WATER BASE CORE ANALYSIS APPARENT HELIUM AIR OIL WATER TOTAL SAND GRAIN DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN DENSITY ft. PERCENT md. RATIO %PV %PV %PV gm/cc CORE NO. 3 (CONTINUED) (12606.00 - 12666.00) : REC. (12606.00 - 12663.40) 12619.45 3.6 <0.1 0.10 4.0 42.1 46.1 2.70 12620.15 3.9 0.80 0.51 16.3 31.7 48.0 2.71 12621.5 3.4 <0.1 0.35 14.3 41.1 55.4 2.70 12622.9 3.8 <0.1 1.90 36.2 19.0 55.2 2.69 12623.8 ?.1 <0.1 0.43 8.7 20.3 29.0 2.69 12624.5 2.6 <0.1 0.25 13.3 53.5 66.8 2.68 12625.7 3.1 <0.1 0.41 20.1 49.0 69.1 2.67 12626.75 3.5 <0.1 0.74 26.0 35.1 61.1 2.98 12627.35 7.0 <0.1 2.28 22.0 9.6 31.6 3.19 12628.35 3.1 <0.1 0.71 29.7 42.0 71.7 2.67 12630.4 3.1 <0.1 0.90 33.6 37.3 70.9 2.67 12631.6 3.9 <0.1 0.42 18.1 42.9 61.0 2.70 12632.05 3.9 <0.1 1.41 45.7 32.3 78.0 2.70 12634.65 3.6 <0.1 0.23 11.8 51.7 63.5 2.69 12635.05 3.1 <0.1 0.30 18.3 60.0 78.3 2.66 12636.55 1.6 <0.1 0.11 9.1 80.0 89.1 2.67 12637.4 2.8 <0.1 0.51 22.8 44.4 67.2 2.67 12641.3 3.4 2.9 0.08 6.2 74.5 80.7 2.67 12642.6 1.8 <0.1 0.06 5.4 90.5 95.9 2.60 WELL BADAMI #1 FIELD WILDCAT COUNTY NORTH SLOPE STATE ALASKA LITHOLOGY Sst;otv gry, ct-vfsd,pyr,n oder,n stn,sptd yet fluor. Sst;otv gry, ct-vfsd,pyr,n oder,n stn,sptd yet fluor. Sst;otv gry,ct-vfsd,pyr,n oder,n stn,sptd yet fluor. Sst;oLv gry, ct-vfsd,pyr,fnt odor, tt stn,strkd yeL fluor. Sst;otv gry,ct-vfsd,pyr,n oder, tt stn,strkd yet fluor. Sst;otv gry, ct-vfsd, pyr,fnt odor, it stn,strkd yet fluor. Sst;otv gry,ct-vfsd,pyr,n odor,n stn,strkd yeL fluor. Sst;otv gry,ct-vfsd, pyr-catc,fnt odor, it stn,strkd brt yet fluor. Sst;otv gry,ct-vfsd,pyr-catc, fnt odor, it stn,strkd brt yeL fluor. Sst;otv gry,ct-vfsd,pyr,fnt odor, tt stn,strkd yet fluor. Sst;otv gry,ct-vfsd,pyr,n odor,n stn,dL gtd fluor. Sst;otv gry,ct-vfsd,pyr,n odor,n stn,sptd yet fluor. Sst;otv gry,ct-vfsd,pyr catc,fnt odor,n stn,sptd brt yeL fluor. Sst;otv gry,ct-vfsd,pyr catc,n odor,n stn,sptd dt gtd fluor. Sst;otv gry, ct-vfsd w/pbts,n odor,n stn,sptd dL gtd fluor. Sttst;otv gry,ct vfsd,carb,n odor,n stn,sptd dt gtd fluor. Sst;otv gry, c[ vfsd,pyr,n odor,n stn,sptd d[ gld fluor. Sst;otv gry w/dk strks,c[ sit tams,n odor,strkd Lt stn, strkd yet fluor. Sttst;tt gry,ct-vfsd w/pbts,carb,n odor,n stn,sptd,yet fluor. PETROLEUM TESTING SERVICE, INC. Page No. File No. Date 3 70076 May 23, 1990 COHPANY CONOCO, INC. CORE TYPE 4 inch MUD TYPE NATER BASE CORE ANALYSIS APPARENT HELIUM AIR OIL WATER TOTAL SAND GRAIN DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN DENSITY ft. PERCENT md. RATIO %PV %PV Y~V gm/cc CORE NO. 3 (CONTINUED) (12606.00 - 12666.00) : REC. (12606.00 - 12663.40) 12647.6 1.7 <0.1 0.05 4.4 88.5 92.9 12649.35 1.6 <0.1 0.07 6.0 89.5 95.5 12654.5 1.2 <0.1 0.07 6.0 84.2 90.2 CORE NO. 4 (12666.00 - 12704.00) : REC. (12665.30 - 12704.60) 12665.7 1.3 <0.1 0.06 5.4 85.7 91.1 12674.85 2.9 O. 20 O. 09 4.8 54.2 59.0 12679.4 3.0 <0.1 0.03 2.4 68.7 71.1 12681.75 3.6 <0.1 0.13 5.9 46.6 52.5 12682.65 3.8 0.40 0.04 1.8 41.3 43.1 12683.7 3.6 <0.1 0.06 2.0 35.1 37.1 12684.75 3.1 <0.1 1.03 20.5 20.0 40.5 12685.85 3.3 <0.1 0.38 10.8 28.3 39.1 12686.5 1.2 <0.1 0.00 0.0 95.0 95.0 12687.65 1.4 <0.1 O. 12 9.9 82.6 92.5 12688.6 5.4 <0.1 ** 0.31 5.6 18.0 23.6 12688.85 1.5 2.8 0.06 4.8 83.3 88.1 12690.5 3.4 0.70 0.10 2.1 22.2 24.3 2.63 2.62 2.56 2.61 2.61 2.65 2.61 2.67 2.59 2.54 2.65 2.55 2.54 2.70 2.58 2.61 ** FRACTURED, ESTIMATED AIR PERMEABILTY WELL BADAMI #1 FIELD WILDCAT COUNTY NORTH SLOPE STATE ALASKA LITHOLOGY Sltst;o[v gry, cl-vfsd,carb, n odor,n stn,sptd dl gld fluor. Sltst;olv gry, cl-vfsd,carb, n odor,n stn,sptd dl g[d fluor. Sltst;olv gry, cl-vfsd,carb [ams,n odor,n stn,sptd d[ g[d fluor. Sltst;o[v gry, cl-vfsd,carb incl,n odor,n stn,n fluor, It cut. Sst;o[v gry, c[-[ams,carb,n odor,n stn,n f[uor, Lt cut. Sst;o[v gry, c[-vfsd,carb, n odor,n stn,n fluor, lt cut. Sst;o[v gry, c[-vfsd, carb incL,n odor ,n stn,n fluor, It cut. SLtst,olv gry w/dk strks,c[ vfsd,carb inc,n odor,n stn,[t cut. Sst;oLv gry w/dk strks,cL-vfsd,carb-inc[,n odor,n stn,n fluor, It cut. SLtst;dk gry w/dk strks,vfsd,carb inc[.n odor,n stn,dk g[d fluor. SLtst/dk gry w/dk strks,vfsd,carb incl.n odor,n stn,dk gld fluor. Sltst;o[v gry w/dk strks,carb Lams,n odor,n stn,n fluor, It cut. Sltst;dk gry w/dk strks,vfsd,carb incl.n odor,n stn,dk gld fluor. S[tst;o[v gry,vfsd,pyr,n odor,n stn,dk gLd fluor. Sltst;olv gry, cl-Lams vfsd,carb-incl,n odor,n stn,n fluor, It cut. Sltst;oLv gry w/dk strks,c[-vfsd,carb incL,n odor,n stn,dk g[d fluor. PETROLEUM TESTING SERVICE, INC. Page No. File No. Date 4 70076 May 23, 1990 COMPANY CONOCO, INC. CORE TYPE 4 inch MUD TYPE WATER BASE CORE ANALYSIS APPARENT HELIUM AIR OIL WATER TOTAL SAND GRAIN DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN DENSITY ft. PERCENT md. RATIO %PV ~J~V %PV gm/cc CORE NO. 4 (CONTINUED) (12666.00 - 12704.00) : REC. (12665.30 - 12704.60) 12691.2 3.9 <0.1 ** 0.06 1.8 30.2 32.0 2.63 12692.5 4.1 <0.1 0.00 0.0 1.4 1.4 2.67 12693.55 7.3 3.6 0.00 0.0 10.8 10.8 1.47 12694.45 9.0 1.4 0.00 0.0 13.9 13.9 1.43 12695.75 5.6 1.0 ** 0.00 0.0 12.5 12.5 1.42 12696.6 3.4 <0.1 ** 0.00 0.0 1.8 1.8 2.00 12697.2 1.6 <0.1 ** 0.00 0.0 12.0 12.0 2.00 12697.8 3.0 <0.1 0.46 22.8 50.0 72.8 2.90 12698.55 4.8 <0.1 0.07 3.0 42.1 45.1 2.63 12698.8 3.6 <0.1 0.16 11.8 75.9 87.7 2.57 12701.4 2.9 <0.1 0.23 10.1 44.4 54.5 2.56 12702.55 6.1 <0.1 1.14 1.1 0.0 2.1 2.56 12702.95 8.7 <0.1 1.26 27.3 21.7 49.0 2.59 12703.2 3.2 <0.1 0.34 20.1 58.8 78.9 2.56 CORE NO. 5 (12824.00 - 12884.00) : REC. (12824.00 - 12883.50) 12824.7 24.9 8.3 0.11 7.3 64.9 72.2 12825.3 26.7 12. 0.05 3.3 62.3 65.6 2.65 2.68 ** FRACTURED, ESTIMATED AIR PERMEABILTY WELL BADAMI #1 FIELD WILDCAT COUNTY NORTH SLOPE STATE ALASKA LITHOLOGY Sttst;olv gry,vfsd,n odor,n stn,dk g[d fluor. Sst;otv gry, slt-vfsd,n odor,n stn,n fluor C;dk brown,n odor,n stn,spt g[d fluor. C;dk brown,n odor,n stn,n fluor. C;dk brown, n odor,n stn,n fluor. C;dk brown,c[-s[t,n odor,n stn,n fluor C;dk brn,c[-s[t,n odor,n stn,n fluor. Sltst;gry,vfsd,pyr,fnt odor, It stn,brt ye[ fluor. Sst,o[v gry, s[t-vfsd,carb incl,n odor,n stn,dk gld fluor. Sltst,o[v gry, c[-[ams vfsd,carb inc[,n odor, It syn,dk gld fluor. S[tst,o[v gry, s[t--vfsd,carb inc[,n odor,n stn,dk g[d fluor. S[tst;dk gry w/dk strks,c[-vfsd,pyr,n odor,n stn,dk g[d fluor S[tst;dk gry, s[t [ams,carb inc[,n odor, It stn,dk g[d fluor S[tst;olv gry, cl-vfsd,carb-inc[,fnt odor, It stn,g[d fluor. Sst,dusky brn,cl-vfsd,carb-incl,fnt odor, lt stn,gld fluor. Sst;dusky brn,c[-vf-fsd, fnt odor,m stn,dk gld fluor. PETROLEUM TESTING SERVICE, INC. Page No. File No. Date 5 70076 May 23, 1990 COMPANY CONOCO, INC. CORE TYPE 4 inch MUD TYPE WATER BASE CORE ANALYSIS APPARENT HELIUM AIR OIL WATER TOTAL SAND GRAIN DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN DENSITY ft. PERCENT md. RATIO %PV %~V %PV gm/cc CORE NO. 5 (CONTINUED) (12824.00 - 12884.00) : REC. (12824.00 - 12883.50) 12826.5 13.3 <0.1 0.10 2.3 23.1 25.4 2.68 12827.55 26.3 9.2 0.00 0.3 62.8 63.1 2.67 12828.45 27.1 9.7 5.02 11.4 2.3 13.7 2.69 12829.75 21.3 2.5 0.14 8.1 56.5 64.6 2.66 12830.15 18.3 3.8 0.08 5.1 63.1 68.2 2.71 12831.6 18.7 1.2 0.19 10.3 53.5 63.8 2.75 12832.9 20.1 1.0 0.21 12.2 59.4 71.6 2.62 12833.1 18.9 0.70 0.33 18.2 54.5 72.7 2.61 12834.25 14.4 0.80 0.38 17.4 45.7 63.1 2.69 12835.9 19.5 2.7 0.16 9.1 56.2 65.3 2.60 12836.65 16.9 2.0 0.12 7.2 61.2 68.4 2.73 12837.95 23.9 4.5 O. 12 5.9 50.5 56.4 2.63 12838.4 6.1 <0.1 0.91 18.8 20.6 39.4 2.63 12839.9 12.5 <0.1 0.33 15.1 45.1 60.2 2.60 12840.9 22.2 2.8 0.12 6.7 57.1 63.8 2.60 12841.4 19.0 1.0 0.24 13.1 55.4 68.5 2.62 12842.45 19.0 1.4 0.06 4.1 66.0 70.1 2.60 12843.3 15.9 0.60 0.17 10.6 62.0 72.6 2.66 12844.55 6.7 1.0 * 0.61 26.3 43.3 69.6 2.59 * FRACTURED WELL BADAMI #1 FIELD WILDCAT COUNTY NORTH SLOPE STATE ALASKA LITHOLOGY Sst;otv gry,vfsd,n odor,n stn, tt gtd fluor. Sst;dusky brn,ct-vf-fsd,n odor,m stn,gtd fluor. Sst;brn,vf-fsd, n odor,n stn,ye[ fluor. Sst;dusky brn w/dk strks,c[-[ams vf-fsd, n odor,m stn,dk g[d fluor. Sst;gry w/dk strks,vf-fsd,pyr,ft odor,m stn,dk g[d fluor. Sst;gry w/dk strks,vf-fsd,pyr,fnt odor,m stn,dk g[d fluor. Sst;gry,vfsd,carb inct,fnt odor,m stn,dk g[d fluor. Sst;gry,vfsd,carb inc[,fnt odor,m stn,dk g[d fluor. Sst;gry, vfsd, pyr,n odor,m stn,dk gtd fluor. Sst;gry w/dk strks,vfsd,carb-incL,fnt odor,strkd m stn,gtd fluor. Sttst;gry w/dk strks,vf-fsd,pyr,fnt odor,strkd m stn,gLd fluor. Sst;dusky brn,vfsd, fnt odor,strkd m stn,dk gtd fluor. Sst;otv gry, ct-tams,n odor,n stn,g[d fluor. Sttst;gry w/dk strks,ct-vfsd,carb-tams,fnt odor,strkd m stn,gtd fluor. Sst;gry,vfsd,carb-inct,fnt odor,strkd m stn,dk gtd fluor. Sst; gry w/dk strks,vfsd, carb-inct,fnt odor,strkd m stn,dk gtd fluor. Sst;gry gry w/dk strks,vfsd,carb-incl,fnt odor, it stn,dk gtd fluor. Sst;gry w/dk strks,vfsd,carb incl,fnt odor, it strkd m stn,gtd fluor. Sst,orr gry w/dk strks,vfsd,carb,n odor,dk stn,gtd fluor. PETROLEUM TESTING SERVICE, INC. Page No. File No. Date 6 ?0076 May 23, 1990 COMPANY CONOCO, INC. CORE TYPE 4 inch MUD TYPE WATER BASE CORE ANALYSIS APPARENT HELIUM AIR OIL WATER TOTAL SAND GRAIN DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN DENSITY ft. PERCENT md. RATIO %PV ~J~V %PV gm/cc CORE NO. 5 (CONTINUED) (12824.00 - 12884.00) : REC. (12824.00 - 12883.50) 12845.25 8.9 <0.1 0.16 9.3 57.8 67.1 2.60 12846.55 9.2 <0.1 0.84 17.1 20.4 37.5 2.64 12848.0 12.0 <0.1 0.32 15.8 48.7 64.5 2.56 12848.6 13.8 <0.1 0.34 5.6 16.4 22.0 2.61 12849.15 14.7 <0.1 0.09 4.4 51.5 55.9 2.60 12850.0 15.6 <0.1 0.09 3.6 40.8 44.4 2.66 12851.5 2.2 <0.1 0.48 25.4 52.8 78.2 2.56 12852.65 1.6 <0.1 0.25 17.6 69.2 86.8 2.60 12853.75 3.0 0.20* 0.08 2.3 30.6 32.9 2.64 12854.65 2.9 <0.1 0.09 2.5 28.3 30.8 2.61 12856.1 3.3 3.2 0.05 2.1 43.6 45.7 2.63 12859.9 1.7 <0.1 0.00 0.0 32.1 32.1 2.56 12867.3 0.7 <0.1 0.00 0.0 50.0 50.0 3.27 12874.95 1.0 <0.1 0.00 0.0 100.0 100.0 2.57 12881.3 2.1 0.50 0.00 0.0 50.0 50.0 2.60 12883.2 1.7 <0.1 0.00 0.0 51.9 51.9 2.61 WELL BADAMI #1 FIELD WILDCAT COUNTY NORTH SLOPE STATE ALASKA LITHOLOGY Sst;otv gry w/dk strks,cl-vfsd stt-tams,carb, n odor,strkd m stn yet fluor. Sst;orr gry, stt-vfsd,carb-inct,n odor,n stn,yet fluor. Sst;orr gry w/dk strks,ct-vfsd,carb inc[,fnt odor,strkd tt stn,ye[ fluor. Sst;orr gry,vfsd,carb-inct,n odor,n stn,dk gtd fluor. Sst;orr gry w/dk strks,ct-tams vfsd, carb, n odor,strkd tt stn,dk gtd fluor. Sst;orr gry w/dk strks,ct-tams vfsd,carb, n odor,strkd tt stn,dk gtd fluor. Sttst;otv gry w/dk strks,vfsd,carb-tams,n odor,n stn,dk gtd fluor. Sst;otv gry w/dk strks,stt-tams vfsd,n odor,n stn,dk gtd fluor. Sttst;dk gry, c[ [ams-vfsd,carb, n odor, it stn,gtd fluor. Sttst;o[v gry w/dk strks,vfsd,carb inct,no odor,strkd dk stn,dk gtd fluor. Sttst;o[v gry w/dk strks,vfsd, carb, n odor,dk stn,dk gtd fluor. Sttst;dk gry w/dk strks,ct-vfsd,carb incl,n odor,n stn,n fluor. Sttst;dk gry,c[ [ams,pyr,n odor,n stn,n fluor. Sttst;otv gry w/dk strks,stt-tams vfsd,carb inc[,n odor,n stn,n ftuor,n cut Sttst;otv gry w/dk strks,c[ [ams,carb, n odor,n stn,n ftuor,n cut. Sttst;otv gry w/dk strks,c[ [ams,carb incl,n odor,n stn,n ftuor,n cut * FRACTURED I i i i ) I t I i I I t ) ~ I J i i PETROLEUM TESTING SERVICE, INC. Page No. Fire No. Date 7 70076 May 23, 1990 COMPANY CONOCO, INC. CORE TYPE 4 inch MUD TYPE WATER BASE WELL FIELD COUNTY STATE BADAMI #1 WILDCAT NORTH SLOPE ALASKA HELIUM AIR OIL WATER TOTAL DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN ft. PERCENT md. RATIO %~V %PV %PV CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc LITHOLOGY TYPE OF EXTRACTION - DEAN STARK TOLUENE EXTRACTION CONFINING PRESSURE ON THE PERMEAMETER = 300 psi OIL GRAVITY ESTIMATED BY VISUAL FLUORESCENCE = 30 A.P.I. PETROLEUM TESTING SERVICE, INC. Page No. File No. Date 1 70076 May 24, 1990 COMPANY CONOCO, INC. CORE TYPE 4 inch MUD TYPE WATER BASE HELIUM AIR DEPTH POROSITY PERMEABILITY O/W ft. PERCENT md. RATIO 8026.0 24.9 18. 0.03 8622.0 23.0 2240. 0.11 8623.0 24.1 1110. 0.02 8728.0 26.1 400. 0.01 8735.0 26.1 55. 0.11 8736.0 27.1 1090. 0.04 8769.0 25.5 <0.1 ** 0.03 8775.0 INSUFFICIENT MATERIAL 8826.0 INSUFFICIENT MATERIAL 8827.0 25.9 255. 0.01 8850.0 23.8 205. 0.05 8851.0 27.6 1250. 0.06 8872.0 24.2 20. 0.02 8873.0 25.9 123. 0.02 8887.0 24.0 12. 0.01 SIDEWALL CORE ANALYSIS APPARENT OIL WATER TOTAL SAND GRAIN SATN SATN SATN DENSITY %PV %PV %PV gm/cc 2.7 83.3 86.0 2.63 9.0 82.9 91.9 2.63 2.3 91.4 93.7 2.58 0.9 82.6 83.5 2.64 8.6 78.6 87.2 2.58 3.3 85.2 88.5 2.9 82.7 85.6 1.4 96.6 98.0 4.9 93.0 97.9 4.4 79.5 83.9 1.9 92.9 94.8 1.9 90.3 92.2 0.7 98.8 99.5 9300.0 NO SAMPLE 9843.0 26.3 10. *~ 0.06 5.7 90.9 9845.0 27.8 10. ** 0.33 24.5 73.3 9848.0 24.8 90. 0.18 15.2 84.1 96.6 97.8 99.3 WELL FIELD COUNTY STATE BADAMI #1 WILDCAT NORTH SLOPE ALASKA ** FRACTURED, ESTIMATED AIR PERMEABILTY 2.65 2.67 2.66 RECOVERED INCHES LITHOLOGY 0.55 Sst;gry,vfsd, gd odor,dk stn, gld fluor. 0.9 Sst;gry, vfsd, gd odor,dk stn gld fluor. 0.75 Sst;olv gry,c[ vfsd,carb, gd odor,n stn dk gld fluor. 0.3 Sst;olv gry,vfsd,fnt odor,n stn dk gld fluor. 0.8 Sst;olv gry, cl-vfsd,carb, n odor,n stn,sptd dk gld fluor'. 0.8 0.7 0.8 Sst;oLv gry,vfsd,fnt odor,dk gld fluor. Sst;gry,vfsd, fnt odor, lt stn,sptd dk gld fluor. 2.68 2.58 2.57 2.62 2.59 0.75 0.6 0.65 0.8 0.6 Sst;gry,vfsd, n odor, lt stn,dk gld fluor. Sst;gry,cl-vfsd, lt odor,n stn,dk gld sptd yel fluor. Sst;olv gry,vfsd,carb,n odor,lt stn w/dk gld sptd fluor. Sst;gry, vfsd,carb,n odor,n stn,[t fluor. Sst;o[v gry.fsd-vfsd, lt odor,n stn, Lt fluor. Sst;gry,vfsd,carb, lt odor, lt stn, lt fluor. 2.53 2.48 2.67 0.3 0.3 0.7 Sst;olv gry,vfsd,C- lams, lt odor, lt stn,gld fluor. Sst;olv gry w/dk strks,vfsd,C lams,lt odor,m stn,gld fluor. Sst;olv gry, fsd-vfsd,n odor, lt stn,gld fluor. PETROLEUM TESTING SERVICE, INC. Page No. FiLe No. Date 2 70076 May 24, 1990 COMPANY CONOCO, INC. CORE TYPE 4 inch MUD TYPE WATER BASE HELIUM AIR OIL WATER TOTAL DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN ft. PERCENT md. RATIO %PV %PV %PV 9850.0 26.5 451. 0.03 3.2 96.0 99.2 9993.0 23.9 113. 0.06 5.4 93.6 99.0 9995.0 24.2 45. ** 0.88 46.4 52.6 99.0 10349.0 27.5 46. 0.03 2.7 96.2 98.9 10350.0 23.8 334. 0.03 2.7 94.8 97.5 10354.0 24.8 2~5. 0.02 2.1 96.0 98.1 10361.0 26.6 225. ** 0.02 1.9 96.4 98.3 10368.0 INSUFFICIENT MATERIAL 10369.0 27.6 201. 0.02 2.3 95.6 97.9 10375.0 27.7 200. ** 0.04 3.4 95.2 98.6 10388.0 NO SAMPLE 10389.0 10471.0 10472.0 10476.0 10488.0 25.0 354. 0.02 2.3 96.7 99.0 INSUFFICIENT MATERIAL INSUFFICIENT MATERIAL INSUFFICIENT MATERIAL INSUFFICIENT MATERIAL 10489.0 INSUFFICIENT MATERIAL 10773.0 13.9 2.3 0.25 16.1 64.7 80.8 SIDEWALL CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc 2.59 RECOVERED INCHES LITHOLOGY 0.55 Sst;olv 2.60 2.60 2.66 2.59 2.59 0.5 Sst;o[v 0.3 Sst;o[v 0.8 Sst;oLv 0.7 Sst;o[v 0.75 Sst;olv 2.65 2.58 2.64 0.3 Sst;o[v 0.5 Sst;otv 0.3 Sst;otv WELL BADAMI #1 FIELD WILDCAT COUNTY NORTH SLOPE STATE ALASKA gry,vfsd,'carb incl,n odor,m stn,gld fluor. gry,vfsd,carb incl,n odor, Lt stn,ye[ fluor. gry,vfsd,carb incl,n odor,m stn,yeL fluor. gry, fsd-vfsd, lt odor,dk stn,ye[ fluor. gry,vfsd,carb incl,n odor,m stn,gld fluor. gry,cl-fsd,carb, lt odor,dk stn,ye[ fluor. gry,slt-fsd,[t odor,dk stn,ye[ fluor. gry,vf-fsd,carb, lt odor,dk stn,yel fluor. gry,vf-fsd,carb, lt odor,dk stn,ye[ fluor. 2.54 0.65 Sst;o[v gry,vf-fsd,carb, lt odor,dk stn,yel fluor. 2.63 1.2 Sst;olv gry,vf-fsd, gd odor,m syn,dL brn fluor. ** FRACTURED, ESTIMATED AIR PERHEABILTY PETROLEUM TESTING SERVICE, INC. Page No. Fire No. Date 3 70076 May 24, 1990 COMPANY CONOCO, INC. CORE TYPE 4 inch MUD TYPE WATER BASE HELIUM AIR DEPTH POROSITY PERMEABILITY O/W ft. PERCENT md. RATIO 10814.0 17.2 42. 0.87 10829.0 19.7 77. 0.12 1084)4.0 12.7 3.1 0.33 10920.0 15.0 2.4 0.20 10927.0 14.8 13. 0.41 10953.3 8.8 10. ** 0.37 10965.0 19.6 60. 0.17 11003.0 9.7 0.90 0.45 SIDEWALL CORE ANALYSIS APPARENT OIL WATER TOTAL SAND GRAIN SATN SATN SATN DENSITY %PV %PV %PV gm/cc 31.6 36.4 68.0 2.53 3.8 30.8 34.6 2.66 19.8 60.9 80.7 2.63 7.7 38.2 45.9 20.1 49.2 69.3 22.0 60.2 82.2 5.9 34.2 40.1 24.6 55.2 79.8 11012.0 9.1 0.60 0.34 22.8 66.7 89.5 11805.0 4.9 <0.1 0.11 9.5 83.3 92.8 11823.0 8.3 0.70 0.09 8.2 88.1 96.3 11839.5 5.5 <0.1 0.03 3.3 95.7 99.0 12730.5 11.8 0.70** 0.38 5.7 15.0 20.7 8.2 78.6 86.8 6.0 52.6 58.6 13.5 65.8 79.3 1.3 70.9 72.2 7.7 82.6 90.3 WELL FIELD COUNTY STATE BADAMI #1 WILDCAT NORTH SLOPE ALASKA 12764.0 4.7 0.50** 0.10 12807.0 8.2 <0.1 0.11 12813.0 9.0 <0.1 0.21 12902.0 14.2 <0.1 0.02 13065.0 17.1 1.5 0.09 RECOVERED INCHES LITHOLOGY 1.25 Sst;olv gry w/dk syrks,carb kams,gd odor,m stn, brt ye[ fluor. 0.6 Sst;o[v gry,vf-fsd,carb lams,gd odor,m stn,ye[ fluor. 1.15 Sst;o[v gry, f-vfsd,gd odor, lt stn,dl brn fluor. 2.69 2.55 2.68 2.66 2.62 0.6 1.2 1.1 0.55 1.1 Sst;olv gry,vfsd,carb incl,gd odor, lt stn,ye[ fluor. Sst;dusky brn w/dk strks,vfsd,carb-[ams,gd odor,m stn,d[ brn fluor. Sst;o[v gry, c[-vfsd, pyr,gd odor,m stn,dl brn fluor. Sst;o[v gry,vf-fsd,carb inc[,gd odor,dk stn,g[d fluor. Sst;o[v gry w/dk strks,vfsd, carb inc[,gd odor,m stn,d[ brn fluor. 2.52 2.63 2.68 2.68 2.70 1.1 0.5 0.5 1.2 0.3 Sst;o[v gry w/dk strks,vfsd,C lams,gd odor, Lt stn,d[ brn fluor. Sst;o[v gry,cL-vfsd,[t odor,m stn,gld fluor. Sst;oLv gry,c[-vfsd,[t odor, Lt stn,d[ brn fluor. Sst;o[v gry,vfsd, Lt odor, lt stn,d[ brn fluor. Sst;hvy min,qtzt,fnt odor, Lt stn, sptd ye[ fluor. 2.35 2.66 2.61 2.64 3.16 0.3 0.3 0.8 0.55 1.2 Sltst;C-lams,fnt odor,n stn,strkd brn fluor. Sst;dk lan~,qtzt,fnt odor, lt stn,strkd yel fluor. Sst;cl-vfsd,fnt odor, lt stn,strkd ye[ fluor. Sst;slt vfsd, lams,fnt odor,n stn,strk yel fluor. Sst;slt fsd,pyr,fnt odor, lt stn,sptd gld fluor. ** FRACTURED, ESTIMATED AIR PERMEABILTY PETROLEUM TESTING SERVICE, INC. Page No. File No. Date 4 70076 May 24, 1990 COMPANY CONOCO, INC. CORE TYPE 4 inch MUD TYPE WATER BASE HELIUM AIR OIL WATER TOTAL DEPTH POROSITY PERMEABILITY O/W SATN SATN SATN ft. PERCENT md.' RATIO ~PV %PV %PV 13147.5 10.2 0.20 0.05 2.9 56.4 59.3 13217.0 12.1 0.10'* 0.00 0.0 20.0 20.0 13262.0 11.6 <0.1 ** 0.07 3.7 57.4 61.1 13431.0 3.4 <0.1 0.13 6.0 47.4 53.4 13435.0 5.7 <0.1 0.23 6.3 27.8 ~4.1 FRACTURED, ESTIMATED AIR PERMEABILITY WELL FIELD COUNTY STATE BADAMI #1 WILDCAT NORTH SLOPE ALASKA SIDEWALL CORE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc 2.81 2.86 2.71 2.64 2.70 RECOVERED INCHES LITHOLOGY 0.4 Sst;c[ vfsd,pyr,fnt odor, It stn,sptd ye[ fluor. 0.3 Sst;vf-fsd,pyr,fnt odor,n stn,n fluor. 0.55 Sst;vf-fsd,pyr,fnt odor, It stn,brt ye[ fluor. 0.6 Sst;vf-fsd,qtzt,fnt odor,n stn,sptd ye[ fluor. 0.4 Sst;vf-fsd,hvymin,fnt odor,n stn, sptd ye[ fluor. TYPE OF EXTRACTION - DEAN STARK TOLUENE EXTRACTION CONFINING PRESSURE ON THE PERMEAMETER = 300 psi OIL GRAVITY ESTIMATED BY VISUAL FLUORESCENCE = 30 A.P.I. These results must be used with caution. Sidewall samples are obtained by impact coring. This method can fracture hard formations, thereby possibly increasing the porosity and permeability. In soft formations, impact coring can compact the samples, resulting in decreased porosity and permeability. Drilling mud may penetrate fractures and soft formations, thereby affecting the porosity, permeability, fluid saturation, grain density and cation exchange capacity results. ** FRACTURED, ESTIMATED AIR PERMEABILTY PETROLEUM TESTING SERVICE, INC. PERMEABILITY AND POROSITY HISTOGRAM CLIENT: CONOCO, INC. STATE: Alaska FIELD: Wildcat WELL: Badami ~1 FILE No.: 70076 DATE: May 24, 1990 DEPTH INTERVAL, ft: 12560.- 12883. 100 9O ~ 80 o 70 la. 60 ~ 3o ~ 2O · [ ,,[ , [ t I'd' [ . [ · r , I "~ · [ ' ["' ~ ' [....~..j,,,..~'] · 'i · [ · I · [ · [ · [ · [ · , , Cumulative Frequency · ' ........ ,N~thmefic Mean 7.1 ./ ..... Median Value 3.6 · · · · · · : 100 -~- ' 90 80 70 >2 6O ~ §0 0 3O >. 20:5 10 :~ 0 0 100 0 21 4, 8,1 ,8 10 12,l& 1,POROSITY,l,~20 22 2&percenf26 2~ 30 32 34 3~ ,3~ 40 42 44 ~ 100 , : /~- ........ Geometric Mean .2 80 ~ -~ 80 , : ! · oe 70 , ~ .--.-.-.. Median Value .1 ~ ~o ~ ~~o ~o ~ §~o ~o .~ ~20 20 PERMEABILITY, millldarcles PETROLEUM TESTING SERVICE, INC. GRAIN DENSITY- POROSITY CROSSPLOT CLIENT: CONOCO, INC. STATE: Alaska FIELD: Wildcat WELI.~ Badami #1 FILE No.: 70076 DATE: May 24, 1990 DEPTH INTERVAL, ft : 12560.- 12883. 3.50 3.00 ~ 2 50 Z 2.00 1.50 i I i I I #a a a adp a # un' a - ~. ~ .......... - } - ! , I, I I I ] I 0 1 0 2O 3O 4O 5O POROSITY, percenf PETROLEUM TESTING SERVICE, INC. POROSITY - PERMEABILITY CROSSPLOT CLIENT: CONOCO, INC. STATE: Alaska FIELD: Wildcat WEI_I~ Badami ~1 FILE No.: 70076 DATE: May 24, 1990 DEPTH INTERVAL, It : 12560.- 12883. lO0 10 .1 .01 0 1 0 20 30 40 50 POROSITY, percenf Sw Name BADAMI-01 BADAMI~01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI~01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI~01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 Api Num 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 Company Code SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY Survey Date Survey Type Code Meas Depth Inclination Azimuth Subsea Depth 11-Mar-90 GYRO 0.00 0.00 0.00 -30.00 11-Mar-90 GYRO 100.00 0.85 29.60 70.00 11-Mar-90 GYRO 200.00 0.82 27.50 169.99 11-Mar-90 GYRO 300.00 0.65 58.90 269.98 11-Mar-90 GYRO 400.00 0.65 25.40 369.97 11-Mar-90 GYRO 500.00 0.78 55.80 469.96 11-Mar-90 GYRO 600.00 0.75 67.60 569.96 11-Mar-90 GYRO 700.00 0.72 78.20 669.95 11-Mar-90 GYRO 800.00 0.85 72.20 769.94 11-Mar-90 GYRO 900.00 0.63 64.70 869.93 11-Mar-90 GYRO 1000.00 0.78 65.40 969.92 11-Mar-90 GYRO 1100.00 0.60 69.30 1069.91 11-Mar-90 GYRO 1200.00 0.55 58.40 1169.91 11-Mar-90 GYRO 1300.00 0.55 63.40 1269.91 11-Mar-90 GYRO 1400.00 0.50 51.80 1369.90 11-Mar-90 GYRO 1500.00 0.58 52.20 1469.90 11-Mar-90 GYRO 1600.00 0.62 43.80 1569.89 11-Mar-90 GYRO 1700.00 1.70 42.50 1669.87 11-Mar-90 GYRO 1800.00 3.17 38.40 1769.78 11-Mar-90 GYRO 1900.00 5.55 36.10 1869.48 11-Mar-90 GYRO 2000.00 8.07 31.60 1968.77 11-Mar-90 GYRO 2100.00 9.97 19.40 2067.53 11-Mar-90 GYRO 2200.00 11.00 2.70 2165.89 11-Mar-90 GYRO 2300.00 11.30 358.20 2264.00 11-Mar-90 GYRO 2400.00 12.60 359.60 2361.83 11-Mar-90 GYRO 2500.00 13.12 357.40 2459.32 11-Mar-90 GYRO 2600.00 14.52 357.40 2556.43 11-Mar-90 GYRO 2700.00 15.25 356.40 2653.07 11-Mar-90 GYRO 2800.00 15.55 356.80 2749.48 11-Mar-90 GYRO 2900.00 15.73 3.58 2845.79 11-Mar-90 GYRO 3000.00 16.05 359.40 2941.97 11-Mar-90 GYRO 3100.00 16.07 2.80 3038.07 11-Mar-90 GYRO 3200.00 16.63 9.10 3134.03 11-Mar-90 GYRO 3300.00 17.57 15.30 3229.62 11-Mar-90 GYRO 3400.00 18.53 21.40 3324.70 11-Mar-90 GYRO 3500.00 19.08 23.70 3419.37 11-Mar-90 GYRO 3600.00 19.77 25.80 3513.67 11-Mar-90 GYRO 3700.00 20.63 0.21 3607.71 11-Mar-90 GYRO 3800.00 21.12 15.30 3701.21 11-Mar-90 GYRO 3900.00 21.22 9.10 3794.47 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-0t BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar~90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 11-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 11-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 7700.00 7800.00 7900.00 8000.00 21.63 21.47 21.27 21.88 22.32 22.52 22.62 22.82 22.88 22.95 23.12 23.02 23.13 23.77 23.38 22.72 22.13 21.87 21.50 21.32 20.95 20.78 20.68 20.77 20.33 20.02 20.40 20.58 20.78 21.18 21.57 21.85 22.22 22.52 22.95 23.23 23.00 22.58 22.27 22.27 22.12 3.80 358.60 353.80 353.40 353.9O 354.4O 354.50 354.4O 354.40 355.70 356.20 357.60 3.59 0.50 3.57 351.40 347.30 347.80 347.90 347.70 347.10 345.90 346.10 3.45 345.10 344.90 3.45 344.80 345.70 345.90 347.40 348.50 348.80 349.60 3.49 3.49 348.80 349.10 349.10 349.30 349.70 3887.57 3980.59 4O73.72 4166.71 4259.37 4351.81 4444.15 4536.39 4628.54 4720.65 4812.68 4904.68 4996.69 5088.44 5180.09 5272.16 5364.61 5457.32 5550.25 5643.35 5736.62 5830.06 5923.59 6017.21 6110.94 6204.81 6298.75 6392.52 6486.08 6579.45 6672.57 6765.48 6858.17 6950.65 7042.94 7134.93 7226.98 7319.17 7411.61 7504.15 7596.74 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI~01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 5O0292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 11-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 11-Mar-90 GYRO 1 l-Mar~90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 11-Mar-90 GYRO 1 l-Mar-90 GYRO 11-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 11-Mar-90 GYRO 1 l-Maro90 GYRO 1 l-Maro90 GYRO 1 l-Mar-90 GYRO 11-Mar-90 GYRO 11-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 11~Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 11-Mar-90 GYRO 1 l-Mar-90 GYRO 1 l-Mar-90 GYRO 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 9000.00 9100.00 9200.00 9300.00 9400.00 9500.00 9600.00 9700.00 9800.00 9900.00 10000.00 10100.00 10200,00 10300.00 10400.00 10500.00 10600.00 10816.00 10909.00 10994.00 11097.00 11192.00 11285.00 11378.00 11471.00 11563.00 11659,00 11780.00 11876.00 11969.00 12063.00 12160.00 21.68 21.53 21.53 21.37 21.17 20.95 2O.65 21.25 21.75 22.25 22.62 22.75 23.40 23.82 24.43 22.52 21.57 21.60 21.70 21.92 22.22 22.32 22.30 22.50 22.58 22.63 22.38 21.50 20.78 19.50 18.10 16.70 0.15 15.18 14.30 13.88 13.30 13.38 13.60 13.80 14.10 350.40 350.90 352.20 3.53 353.30 354.20 354.40 354.10 353.50 354.10 353.90 354.20 353.90 353.70 353.80 354.40 354.70 354.80 354.30 354.40 354.30 354.40 354.50 353.90 353.90 353.70 352.70 3.53 352.70 354.10 354.40 355.10 354.10 353.70 355.50 355.90 357.30 356.60 356.90 355.50 356.20 7689.53 7782.50 7875.52 7968.64 8061.86 8155.18 8248.66 8342.05 8435.09 8527.81 8620.24 8712.51 8804.50 8896.13 8987.40 9079.12 9171.81 9264.79 9357.74 9450.58 9543,25 9635.79 9728.31 9820.76 9913.12 10005.44 10204.99 10291.29 10370.60 10467.30 10557.23 10645.98 10737.65 10829.56 10918.53 11011.64 11129.25 11222.66 11313.10 11404.42 11498.56 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 BADAMI-01 5O0292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 500292201700 SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY SPERRY 1 l-Mar-90 11-Mar-90 1 l-Mar-90 1 l-Mar-90 11-Mar-90 1 l-Mar-90 1 l-Mar-90 1 l-Mar-90 1 l-Mar-90 11-Mar-90 1 l-Mar-90 1 l-Mar-90 11-Mar-90 1 l-Mar-90 11-Mar-90 GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO 12250.00 12344.00 12441.00 12562.O0 12658.00 12756.00 12880.00 12980.00 13068.00 13166.00 13254.00 13349.00 13441.00 13542.00 13595.00 14.18 13.10 12.10 10.50 10.10 10.30 10.50 10.60 10.68 10.68 10.80 10.38 9.80 9.30 9.38 357.60 358.30 356.60 358.70 3.59 358.30 3.58 357.60 358.30 356.20 354.40 355.10 355.90 355.50 355.20 11585.83 11677.18 11771.85 11890.50 11984.95 12081.40 12203.37 12301.68 12388.17 12484.47 12570.93 12664.31 12754.89 12854.49 12906.79 GREAT LAND DIRECTIONAL DRILLING, Client .... : Field ..... : Well ...... : Section at: Mag Dcln..: CONOCO BADAMI PROSPECT BADAMI #1 N,O.00,W 31.37 E INC. (MIKKELSEN BAY) RECORD OF SURVEY o5/ol/9O Computation...: RADIUS OF CURVATURE Survey Date...: 04/11/90 RKB Elevation.: 30.00 ft Case ID ....... : BAD1D S MEAS INCLN C DEPTH ANGLE 3 166 0.10 3 257 0.20 3 '348 0.20 3 438 0.20 3 530 0.20 VERTICAL-DEPTHS BKB SUB-SEA 166.0 136.0 257.0 227.0 348.0 318.0 438.0 408.0 530'0 500.0 3 620 0.90 620.0 590.0 3 711 1.00 711.0 681.0 3 802 0.90 802.0 772.0 3 892 0.60 892.0 862.0 3 982 0.40 982.0 952.0 3 1073 0.50 3 1163 0.40 3 1253 0.30 3 1343 0.30 3 1439 0.20 3 1532 0.20 3 1623 0.10 3 1736 1.40 3 1829 2.90 3 1923 5.30 3 2014 7.60 3 2108 9.90 3 2199 10.80 1073.0 1043.0 1163.0 1133.0 1252.9 1222.9 1342.9 1312.9 1438.9 1408.9 1531.9 1501.9 1622..9 1592.9 1735.9 1705.9 1828.9 1798.9 1922.6 1892.6 2013.0 1983.0 2105.9 2075.9 2195.5 2165.5 SECTION DIRECTION DISTNCE BEARING 0.1 N 3.80 W 0.4 N 31.60 W 0.5 S 87.60 W 0.7 N 71.80 E 0.9 . N 35.90 E: 0.8 S 24.90 E -0.3 S 49.50 E -0.9 S 83.70 E -1.0 S 89.30 E -0.9 N 77.00 E -0.7 N 66.80 E -0.7 S 64.00 E -0.8 N 82.30 E -0.8 N 84.00 E -0.7 N 87.20 E -0.6 N 45.00 E -0.4 N 36.90 E 0.7 N 44.00 E 3.4 N 36.20 E 8.8 N 34.80 E 17.4 N 32.40 E 30.2 N 20.10 E 46.0 N 7.10 E RELATIVE-COORDINATES FROM-WELL-HEAD O.1N 0.OW 0.4N 0.1W 0'.5N 0.3W 10'.7N 0.4W 0.9N 0.1W 0.8 N 0.3 S 0.9 S 1.0 S 0.9 S 0.6 E 1.5 E 2.8 E 4.0 E 4.8 E 5.5 E 6.2 E 6.7 E 7.2 E 7.6 E 0.7 S 0.7 S 0.8 S 0.8 S 0.7 S 0.6 S 0.4 S 0.7N 3.4N 8.8 N 7.9 E 8.0 E 9.0 E 11.2 E 15.1 E 17.4 N 30.2 N 46.0 N 20.8 27.1 30.9 CLOSURE DL DISTNCE BEARING /100 0.1 N 3.80 W 0.4 N 12.42 W 0.6 N 34.29 W 0.8 N 28.13 W 0.9 N 8.27 W 0.06 0.11 0.00 0.00 0.00 1.0 N 34.55 E 0.78 1.5 S 76.76 E 0.11 3.0 S 71.74 E 0.11 4.2 S 75.89 E 0.33 4.9 S 79.07 E 0.22 5.5 S 82.66 E 0.11 6.2 S 83.31 E 0.11 6.8 S 83.12 E 0.11 7.2 S 84.01 E 0.00 7.6 S 84.57 E 0.10 7.9 S 85.70 E 0.00 8.0 S 87.06 E 0.11 9.0 N 85.47 E 1.15 1.7 N 73.27 E 1.61 7.5 N 59.69 E 2.55 7.1 N 50.14 E 0.6 N 41.95 E 5.5 N 33.92 E 2.53 2.48 1.11 'Survey Codes: 3/MWD BADAMI #1 RECORD OF SURVEY Page 2 05/01/90 S MEAS INCLN C DEPTH ANGLE 3 2289 11.30 3 2380 11.80 3 2477 13.40 3 2566 13.40 3 2673 15.10 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 2283.8 2253.8 63.2 2372.9 2342.9 81.4 2467.6 2437.6 102.6 2554,2 2524.2 123.2 2657.9 2627.9 149.4 DIRECTION BEARING N 1.70 W N 2.70 W N 3.40 W N 3.10 W N 4.50 W RELATIVE-COORDINATES FROM-WELL-HEAD 63.2 N 31.8 E 81.4 N 31.1 E 102.6 N 29.9 E 123.2 N 28.8 E 149.4 N 27.0 E CLOSURE DL DISTNCE BEARING /100 70.8 N 26,67 E 0.67 87.2 N 20.88 E 0.55 106.8 N 16.27 E 1.65 126.5 N 13.15 E 0.02 151.9 N 10.25 E 1.59 3 2766 15.30 3 2'859 15.60 3 2953 15.90 3 3046 16.20 3 3140 16.10 2747.6 2717.6 173.7 2837.3 2807.3 198.5 2927.7 2897.7 224.0 3017.1 2987.1 249.7 3107.4 3077.4 275.8 N 4.90 W N 2.40 W N 1.00 W N 0.80 E: N 3.90 E 173.7 N 25.0 E N 2 .4 22:4:0 N 22.7 ~.. 249.7 N 22.6 E 275.8 N 23.7 E 175.5 N 8.19 E 0.22 199.8 N 6.74 E 0.38 225.1 N 5.78 E 0.34 250.7 N 5.18 E 0.36 276.8 N 4.91 E 0.28 3 3231 17.10 3 3324 17.70 3 3413 18.70 3 3572 20.10 3 3683 20.60 3194.6 3164.6 301.6 3283.4 3253.4 328.7 3367.9 3337.9 355.0 3517.9 3487.9 403.7 3621.9 3591.9 439.0 N 10.60 E 301.6 N 27.0 E N 15.50 E 328 . 7 N 33.3 E N 21.20 E 355.0 N 42.0 E N 24.30 E 403.7 N 62.4 E N 23.60 E 439.0 N 78.1 E 302.8 N 5.11 E 1.27 330.3 N 5.78' E 0.81 357.5 N 6.75 E 1.30 408.5 N 8.79 E 0.91 445.9 N 10.09 E 0.46 3 3776 20.90 3 3868 21.40 3 3961 21.60 3 4055 21.70 3 4148 21.40 3708.9 3678.9 470.0 3794.7 3764.7 502.2 3881.2 3851.2 535.8 3968.6 3938.6 570.4 4055.1 4025.1 604.6 N 16.20 E N 11.30 E N 7.10 E N 0.10 E N 4.50 W 470.0 N 89.3 E 502.2 N 97.2 E 535.8 N 102.7 E 570.4 N 104.8 E 604.6 N 103.5 E 478.4 N 10.76 E 1.06 511.5 N 10.95 E 0.89 545.6 N 10.84 E 0.65 580.0 N 10.41 E 1.02 613.4 N 9.72 E 0.73 3 4245 21.80 3 4339 22.40 3 4432 22.90 3 4525 23.00 3 4622 22.90 4145.3 4115.3 640.1 4232.4 4202.4 675.2 4318.2 4288.2 710.8 4403.9 4373.9 746.9 4493.2 4463.2 784.5 N 7.70 W N 5.60 W N 6.60 W N 5.5O W N 5.50 W 640.1 N 99.7 E 675.2 N 95.6 E 710.8 N 91.8 E 746.9 N 88.0 E 784.5 N 84.4 E 647.8 N 8.86 E 0.61 681.9 N 8.06 E 0.72 716.7 N 7.36 E 0.56 752.0 N 6.72 E 0.21 789.0 N 6.14 E 0.10 3 4716 23.20 3 4811 22.90 3 4904 23.20 4579.7 4549.7 821.1 4667.1 4637.1 858.1 4752.7 4722.7 894.3 N 5.90 W N 7.30 W N 4.10 W 821.1 N 80.7 E 858.1 N 76.4 E 894.3 N 72.8 E 825.1 N 5.61 E 0.33 861.5 N 5.09 E 0.39 897.3 N 4.66 E 0.62 'Survey Codes: 3/MWD BADAMI #1 RECORD OF SURVEY 05/01/90 S MEAS INCLN C DEPTH ANGLE 3 4996 23.20 3 5090 23.30 3 5184 23.60 3 5276 23.90 3 5398 24.10 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 4837.2 4807.2 930.4 4923.6 4893.6 967.4 5009.8 4979.8 1004.8 5094.0 5064.0 1041.8 5205.5 5175.5 1091.4 DIRECTION BEARING N 4.80 W N 3.40 W N 2.30 W N 1.70 W N 2.40 W RELATIVE-COORDINATES FROM-WELL-HEAD 930.4 N 70.0 E 967.4 N 67.4 E 1004.8 N 65.5 E 1041.8 N 64.2 E 1091.4 N 62.4 E CLOSURE DISTNCE BEARING 933.1 N 4.30 E 969.8 N 3.98 E 1006.9 N 3.73 E 1043.8 N 3.53 E 1093.2 N 3.27 E DL /lOO 0.12 0.26 0.37 0.34 0.19 3 5492 23.20 3 5625 22.40 3 5718 22.10 3 5813 21.90 3 5907 21.70 5291.6 5261.6 1129.0 5414.2 5384.2 1179.7 5500.3 5470.3 1214.1 5588.4 5558.4 1248.8 5675.6 5645.6 1282.9 N 8.OO W N 11.80 W N 13.60 W N 11.80 W N 12.60 W 1129.0 N 59.0 E 1179'.7 N 50.2 E 12!41.1 N 42.4 E 1248.8 N 34.6 E 1282.9 N 27.2 E 1130.5 N 2.99 E 1180.8 N 2.43 E 1214.8 N 2.00 E 1249.3 N 1.59 E 1283.2 N 1.22 E 1.33 0.73 0.42 0.34 0.24 3 6002 21.40 3 6093 21.20 3 6183 21.10 3 6275 21.00 3 6367 20.90 5764.0 5734.0 1317.0 5848.8 5818.8 1349.2 5932.7 5902.7 1380.7 6018.6 5988.6 1412.9 6104.5 6074.5 1444.9 N 12.20 W N 14.30 W N 12.90 W N 13.00 W N 14.30 W 1317.0 N 19.7 E 1349.2 N 12.1 E 1380.7 N 4.5 E 1412.9 N 2.9 W 1444.9 N 10.7 W 1317.1 N 0.86 E 1349.2 N 0.52 E 1380.7 N 0.19 E 1412.9 N 0.12 W 1444.9 N 0.42 W 0.32 0.37 0.23 0.11 0.21 3 6461 20.50 3 6576 20.40 3 6661 20.50 3 6755 21.00 3 6845 21.10 6192.4 6162.4 1477.1 6300.2 6270.2 1516.1 6379.8 6349.8 1544.9 6467.7 6437.7 1577.2 6551.7 6521.7 1608.5 N 14.30 W N 13.60 W N 14.00 W N 14.00 W N 15.00 W 1477.1 N 18.9 W 1516.1 N 28.5 W 1544.9 N 35.6 W 1577.2 N 43.7 W 1608.5 N 51,8 W 1477.2 N 0.73 W 1516.4 N 1.08 W 1545.3 N 1.32 W 1577.8 N 1.59 W 1609.4 N 1.84 W 0.43 0.11 0.13 0.53 0.18 3 6941 21.50 3 7037 21.70 3 7133 22.10 3 7228 22.50 3 7323 22.80 6641.2 6611.2 1642.4 6730.4 6700.4 1676.8 6819.5 6789.5 1711.8 6907.4 6877.4 1747.2 6995.1 6965.1 1783.1 N 13.00 W N 12.90 W N 11.90 W N 10.10 W N 10.80 W 1642.4 N 60.2 W 1676.8 N 68.1 W 1711.8 N 75.8 W 1747.2 N 82.7 W 1783.1 N 89.3 W 1643.5 N 2.10 W 1678.2 N 2.33 W 1713.5 N 2.54 W 1749.1 N 2.71 W 1785.4 N 2.87 W 0.50 0.21 0.44 0.50 0.33 3 7416 23.20 3 7505 23.60 3 7595 23.50 7080.7 7050.7 1818.9 N 9.40 W 7162.3 7132.3 1853.7 N 10.80 W 7244.8 7214.8 1889.0 N 11.50 W 1818.9 N 95.7 W 1853.7 N 101.9 W 1889.0 N 108.9 W 1821.4 N 3.01 W 1856.5 N 3.15 W 1892.1 N 3.30 W 0.49 0.52 0.17 'Survey Codes: 3/MWD BADAMI #1 RECORD OF SURVEY Page 4 o5/ol/9O S MEAS C DEPTH 3 7690 3 7785 3 7880 3 7973 3 8066 INCLN ANGLE 23.10 22.80 22.70 22.40 22.30 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 7332.1 7302.1 1925.9 7419.6 7389.6 1962.4 7507.2 7477.2 1998.6 7593.1 7563.1 2033.7 7679.1 7649,1 2068.5 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD N 9.80 W 1925.9 N 115.8 W N 9,80 W 1962,4 N 122,1 W N 10.50 W 1998.6 N 128.6 W N 9.80 W 2033.7 N 134.9 W N 9.80 W 2068.5 N 140.9 W CLOSURE DISTNCE BEARING 1929.4 N 3.44 W 1966.2 N 3.56 W 2002.7 N 3.68 W 2038.2 N 3.79 W 2073.3 N 3.90 W DL /lOO 0.50 0.32 0.15 0.34 0.11 3 8159 22.10 3 8256 21.90 3 8350 21.80 3 8443 21.80 3 8537 21.60 3 8628 21.40 3 8724 21.10 3 8819 21.70 3 8911 22.00 3 9004 22.60 7765.2 7735.2 2103.2 7855.1 7825.1 2139.1 7942.4 7912.4 2173.8 8028.7 7998.7 2208.1 8116.1 8086.1 2242.6 8200.7 8170.7 2275.7 8290.2 8260.2 2310.3 8378.7 8348.7 2344.8 8464.1 8434.1 2378.8 8550.1 8520.1 2413.8 N 9.40 W 2103.2 N 146.8 W N 7.30 W 21391.1 N 152.0 W N 7.70 W 2173.8 N 156.6 W N 7.30 Wi 2208.1 N 161.1 W N 6.60 W 2242.6 N 165.3 W N 6.60 W 2275.7 N 169.1 W N 5.90 W 2310.3 N 172.9 W N 6.30 W 2344.8 N 176.6 W N 6,30 W 2378.8 N 180,4 W N 7.30 W 2413.8 N 184.6 W 2108.3 N 3.99 W 2144.5 N 4.07 W 2179.5 N 4.12 W 2213.9 N 4.17 W 2248.7 N 4.22 W 2282.0 N 4.25 W 2316.8 N 4.28 W 2351.4 N 4.31 W 2385.6 N 4.34 W 2420.9 N 4.3Y W 0.22 0.37 0.12 0.06 0.24 0.22 0.33 0.63 0.33 0.66 3 9097 22.90 3 9194 23,10 3 9290 23.50 3 9380 24,00 3 9476 24.50 8635.9 8605.9 2449.6 8725.2 8695.2 2487.2 8813.3 8783.3 2525.0 8895.7 8865.7 2561.1 8983.2 8953.2 2600.3 N 5.60 W N 6.90 W N 4.50 W N 6.30 W N 7.00 W 2449.6 N 188.6 W 2487.2 N 192.7 W 2525.0 N 196.5 W 2561.1 N 199.9 W 2600.3 N 204.5 W 2456.8 N 4.40 W 2494,7 N 4.43 W 2532.7 N 4.45 W 2568.9 N 4.46 W 2608.3 N 4.50 W 0.43 0.29 0.58 0.65 0.54 3 9569 25.00 3 9662 22.30 3 9755 22.10 3 9846 22.10 3 9943 22.30 9067.7 9037.7 2638.9 9152.9 9122.9 2676.0 9239.0 9209.0 2711.0 9323.3 9293.3 2745.1 9413.1 9383.1 2781.5 N 7.00 W 2638.9 N 209.2 W N 5.60 W 2676.0 N 213.3 W N 4.50 W 2711.0 N 216.4 W N 6.30 W 2745.1 N 219,6 W N 6.30 W 2781.5 N 223.6 W 2647.2 N 4.53 W 2684.5 N 4.56 W 2719.6 N 4.56 W 2753.8 N 4.57 W 2790.5 N 4.60 W 0.54 2.91 0.27 0.28 0.21 3 10033 22.40 3 10129 22.60 3 10223 22.80 9496.3 9466.3 2815.5 9585.0 9555.0 2852.1 9671.7 9641.7 2888,1 N 5.90 W 2815.5 N 227.3 W N 6.60 W 2852.1 N 231.3 W N 5.60 W 2888.1 N 235.1 W 2824.7 N 4.62 W 2861.4 N 4.64 W 2897.7 N 4.65 W 0.13 0.23 0.27 ~Survey Codes: 3/MWD BADAMI #1 S MEAS INCLN C DEPTH ANGLE 3 10320 22.90 3 10410 22.90 3 10505 23.00 3 10595 23.10 3 10816 22.40 3 10909 21 3 10994 20 3 11097 19 3 11192 18 3 11285 16 VERTICAL-DEPTHS BKB SUB-SEA 3 11378 16 3 11471 15 3 11563 14 3 11659 13 3 11780 13 SECTION DISTNCE 3 11876 13 3 11969 13 3 12063 13 2 12131 14 2 12222 15 9761.1 9731.1 2925.6 9844.0 9814.0 2960.5 9931.5 9901.5 2997.3 10014.3 9984.3 3032.4 10218.1 10188.1 3117.3 2 12313 14 2 12406 13 2 12499 12 2 12592 11 2 12685 10 .50 10304.4 10274.4 3151.8 .80 10383.7 10353.7 3182.2 .50 10480.4 10450.4 3217.5 .10 10570.3 10540.3 3247.9 .70 10659.0 10629.0 3275.6 2 12778 11 2 12871 11 2 12964 11 .00 10748.3 10718.3 3301.7 .20 10837.8 10807.8 3326.6 .30 10926.8 10896.8 3349.9 .90 11019.9 10989.9 3373.2 .30 11137.5 11107.5 3401.6 .40 11230.9 11200.9 .60 11321.4 11291.4 .80 11412.7 11382.7 .50 11478.6 11448.6 .00 11566.6 11536.6 .25 11654.7 11624.7 .25 11745.0 11715.0 .00 11835.8 11805.8 .25 11926.9 11896.9 .67 12018.2 11988.2 .25 12109.5 12079.5 .50 12200.6 12170.6 .75 12291.7 12261.7 3423.7 3445.4 3467.6 3484.2 3507.4 3530.3 3552.4 3572.8 3591.5 3609.2 3626.9 3645.2 3663.9 RECORD OF SURVEY DIRECTION BEARING N 5.60 W N 5.60 W N 6.30 W N 5.20 W N 7.30 W N 7.00 W N 7.30 W N 5.90 W N 5.90 W N 4.90 W RELATIVE-COORDINATES FROM-WELL-HEAD 2925.6 N 238.8 W 2960.5 N 242.2 W 2997.3 N 246.1 W 3032.4 N 249.6 W 3117.3 N 258.9 W 3151.8 N 263.2 W 31'82'.2 N 267.0 W 321Y.5 N 271.1 W 3247.9 N 274.3 W 3275.6 N 276.9 W N 5.90 W 3301.7 N 279.3 W N 6.30 W 3326.6 N 282.0 W N 4.50 W 3349.9 N 284.2 W N 4.10 W 3373.2 N 286.0 W N 2.70 W 3401.6 N 287.7 W N 3.40 W 3423.7 N 288.8 W N 3.10 W 3445.4 N 290.1 W N 4.50 W 3467.6 N 291.5 W N 2.40 W 3484.2 N 292.5 W N 1.40 W 3507.4 N 293.3 W N 1.40 W 3530.3 N 293.9 W N 1.40'W 3552.4 N 294.4 W N 0.40 W 3572.8 N 294.7 W N 0.40 E 3591.5 N 294.7 W N 1.20 E 3609.2 N 294.5 W N 0.20 E 3626.9 N 294.3 W N 0.20 E 3645.2 N 294.2 W N 0.40 W 3663.9 N 294.2 W Page 5 05/01/90 CLOSURE DISTNCE BEARING 2935.3 N 4.67 W 2970.4 N 4.68 W 3007.4 N 4.69 W 3042.6 N 4.71 W 3128.1 N 4.75 W 3162.8 N 4.77 W 3193.4 N 4.80 W 3228.9 N 4.82 W 3259.5 N 4.83 W 3287.3 N 4.83 W 3313.5 N 4.84 W 3338.5 N 4.85 W 3361.9 N 4.85 W 3385.3 N 4.85 W 3413.7 N 4.8~3 W 3435.9 N 4.82 W 3457.6 N 4.81 W 3479.9 N 4.81 W 3496.5 N 4.80 W 3519.6 N 4.78 W 3542.5 N 4.76 W 3564.6 N 4.74 W 3584.9 N 4.72 W 3603.6 N 4.69 W 3621.2 N 4.66 W 3638.8 N 4.64 W 3657.0 N 4.61 W 3675.7 N 4.59 W DL 11oo 0.10 0.00 0.15 0.22 0.35 0.97 0.82 1.27 1.47 1.51 0.76 0.86 0.99 0.42 0.50 0.11 0.22 0.23 1.05 0.55 0.82 1.08 1.34 0.81 0.63 0.63 0.27 0.27 'Survey Codes: 2/MULTI SHOT 3/MWD BADAMI ! #1 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 2 13057 11.75 2 13150 11.50 2 13243 11.25 2 13336 11.50 2 13429 10.50 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 12382.8 12352.8 3682.9 12473.9 12443.9 3701.6 12565.0 12535.0 3719.9 12656.2 12626.2 3738.3 12747.5 12717.5 3756.0 DIRECTION BEARING N 0.20 E N 0.20 E N 3.40 W N 2.40 W N 3.40 W RELATIVE-COORDINATES FROM-WELL-HEAD 3682.9 N 294.3 W 3701.6 N 294.2 W 3719.9 N 294.7 W 3738.3 N 295.6 W 3756.0 N 296.5 W 2 13522 10.25 12839.0 12809.0 X 13'595 J 10.25 12910.8 ~12880.8 3772.7 3785.7 'Survey Codes: 2/MULTI SHOT X/EXTRAPOLATED N 2.40 W N 2.40 W 3772.7 N 297.4 W 37'85;7 N 297.9 W Page 6 o5/ol/9O CLOSURE DISTNCE BEARING 3694.6 N 4.57 W 3713.3 N 4.54 W 3731.6 N 4.53 W 3749.9 N 4.52 W 3767.7 N 4.51 W 3784.4 N 4.51 W 3797.4 N 4.50 W DL /lOO 0.03 0.27 0.31 0.27 1.08 0.27 0.00 PERMIT ~ pO~ _ / / ? WELL NAME ..- GUaFLE I IUli DATE ~ t. ~u,~ I .... ^o~cc GEOLOGICAL MATERIALS INVENTORY LIST ' , ( check off orlis½~data as it is ~ceived ] aa7 ! ¢/~,'?~¢ drillin9 h,.t../ ... ;.~.y '1~1 Welltests I core desriptionl~ cored i.{e~s core a,a,lysis' ~ d~ ditch inte~als , digital data /~~-,/~85~' , //,~-/~ ' , / ~,,' ~ ......... ~~- ~ I I I I LOG TYPE RuN INTERVALS SCAI_E NO. 1:i ' , , ,, , , ,,, io] , 11] 13] ,, 15] ,,, .~1 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, A1 aska 99501 June 11, 1990 Dear Mr. Grant- Enclosed are the following data from the Badami #1 well, which is located in Section 9, T 9N , R 20E on the North Slope of Alaska. The API number for this wel 1 i s 50-029--2001~7 ........ _. Well Log Data LIS tape' DIFL, CN-ZDL, LSAL, DEL2 Depth' 0 - 13,350' Again, my apologies for the first copies of these tapes which were in an unreadable backup format. These and all other data from the Badami #1 well are CONFIDENTIAL and should be handled accordingly. To confirm arrival of these data and samples, please sign the attached copy of this letter and return it to me. Should you have any questions or any further problems, please telephone me at (907) 564- 7640. Sincerely, Steve Davies Staff Geologist (lrl) RECEIVED cc' R.F. Wheeler 390.08.07 A]as[(a .OiJ & Gas GoDs, Anchora¢~ TO: ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 ~E: ,~ ~ Receipt of the following material which was transmitted via is hereby acknowledged: QUANT I TY DESCRIPTION RECEIVED: / Copy sent to sender YES ~, NO ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Receipt of the following material which was transmitted via ~2~/~~ . ~-~~ ,~ is hereby acknowl edged :/ QUANT I TY DESCRI PT I ON RECEIVED: DATED: Copy sent to sender YES NO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Receipt of the following material which was transmitted via is hereby acknowledged: QUANT I TY DESCR I PT I ON '~'>~ ~ ~/~ . ~'i'7 '~'/" ~//'~ / 7o z~ 1o / Copy YES sent to sender NO Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 Mr. Larry Grant State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE£E ED I 1_990 June 11, ]990 Dear Mr. Grant: i~[a~ .0il & Gas Cons. Commission '.~,.,; ,5 ' Enclosed are the following data from the Badami #1 well, which is located in Section 9, T 9N , R 20E on the North Slope of Alaska. The API number for this well is 50-029-20017. 1) 2) 3) 4) 5) Well Loq Data Dual Induction 1" MD Dual Induction 1" TVD Dual Induction 2" MD Dual Induction 2" TVD Dual Induction 5" MD Dual Induction 5" TVD Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia LS Acoust i 1 og 1" MD LS Acoust i 1 og 1" TVD LS Acoust i 1 og 2" MD LS Acousti 1 og 2" TVD LS Acoustilog 5" MD LS Acoustilog 5" TVD Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Z-Densilog (Por) 1" MD Z-Densilog (Por) 1" TVD Z-Densilog (Por) 2" MD Z-Densilog (Por) 2" TVD Z-Densilog (Por) 5" MD Z-Densilog (Por) 5" TVD Z-Densilog (Raw) 1" MD Z-Densilog (Raw) 1" ffVD Z-Densilog (Raw) 2" MD Z-Densilog (Raw) 2" TVD Z-Densilog (Raw) 5" MD Z-Densilog (Raw) 5" TVD Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Dielectric Log 2" MD Dielectric Log 2" TVD Dielectric Log 5" MD Blackline & Sepia Blackline & Sepia Blackline & Sepia 111' - 13,510' 111' - 13,510' 111' - 13,510' 111' - 13,510' 111' - 13,510' 111' - 13,510' 3,515' - 10,721' 3,5]5' - ]0,721' 3,515' - 10,721' 3,515' - 10,721' 3,515' - 10,721' 3,515' - 10,721' 10,759' - 13,478' 10,759' - 13,478' 10,759' - ]3,478' 10,759' - 13,478' 10,759' - 13,478' 10,759' - 13,478' 10,759' - ]3,478' 10,759' - 13,478' 10,759' - ]3,478' 10,759' - 13,478' 10,759' - 13,478' 10,759' - 13,478' 3,515' - 10,570' 3,515' - 10,570' 3,515' - 10,570' Dielectric Log 6) Diplog (Raw) ~jo~Di pl og (Raw) 7) Computed Diplog ~,~r~omputed Diplog 5" TVD 5" MD 5" TVD 5" MD 5" TVD Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia Blackline & Sepia 3,515' - 10,570' 10,759' - 13,534' 10,759' - 13,534' 10,760' - 13,548' 10,760' - 13,548' 8) Corgun 5" MD Corgun-/W~/z:~ 5" TVD 1) 2) 3) 4) 5) Blackline & Sepia Blackline & Sepia 8,026' - 10,570' 8,026' - 10,570' loq Data Mud 1 og Mudl og Measured Depth 2" MD True Vertical Depth 2" MD Blackline & Sepia Blackline & Sepia Drilling Data Measured Depth 2" MD Blackline & Sepia Pressure Data Pressure Data Measured Depth .4" MD True Vert i cal Depth .4" MD Blackline & Sepia Blackline & Sepia 1) 2) 3) 4) 5) 6) 7) Core Data Lithologic descriptions of cores I through 5. Final report for routine analysis of conventional and sidewall cores by Petroleum Testing Service, Inc. Core gamma ray log: 12,550' - 12,800' MD; blackline and sepia. Core gamma ray log: 12,800' - 13,050' MD; blackline and sepia. Core graph of grain density, porosity, permeability, and fluid saturation: 12,550' - 12,800' MD; blackline and sepia. Core graph of grain density, porosity, permeability, and fluid saturation: 12,800' - 13,050' MD; blackline and sepia. Customer data diskette (5 1/4" floppy diskette). Cuttings 1) Dry well cuttings' 13 boxes R E jUN ~ 19q0 Gas Cons~ commission Anchora~ - 13,595' MD. Ceh~Ps f'rom COnvention ~ troleum Testfn~ ~ a7 COres 1 through ~ oervice, Inc. 5 w~77 be de7iVered by ~r. Don Graika ~.n L~S tape o¢ the we77 data wi77 ~o~ 7ow Under separate COver These and a77 o handTed ther dar · aCCordin a f~o~ t the attached ~._gTy: To co . he_Saqam~ ~ ~PY or thf, ~]r~ arr~va7 ] we77 are CONFID "'~cer an~.. of these dar- - - NTXAL and shouTd be "return ft to me." anu SampTes, p7ease sfgn Shou7d ~ou have an~ questfons, teTephone me at (907) 564 _ 7640. SfncereT~, SFO(Tr7) CC- R. F. ~/hee7 390.08.07 davies 1 ~aog¢c RX CEIVED Anchorage o -'1,-~8~'1. o " ~hO(/O ,'. 7990 '.. : Cons. Comml~l~ STATE OF ALASKA ~!: ~ ~,._,,SKA OIL AND GAS CONSERVATION COM M~,.,oiON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request; Abando Suspend __ Operation shutdown __ Re-enter suspended well __ Alter camrltj ~ Repair well Change approved program 2. Name of Operator 6Onoco Inc. 3. Address 3201 C Street, Suite 200 Anchoraqe~ Alaska 99503 FEL, Sec. 4. Location of well at suflace 1800' FNL, 4280' At top of productive interval N/A At effective depth N/A At total depth 3296' FNL, 4555' FEL, 12. Present well condition summary Total depth: measured 13,595 true vertical 12,922 Effective depth: measured N/A true vertical Sec. Plugging Pull tubing __ feet feet Size 20" 13-3/8" 9r5/8" Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 110' 3412' 10763' N/A N/A N/A measured N/A true vertical 5. Type of Well: Development ExDIoratory Stratigraphic Service Time extens,on ~ Stimulate __ Variance __ Perforate __ Other ~ 6. Datum elevation (DF or KB) KB 30 Z Unit or Property name Badami 8. Well number No. 1 9. Permit number 89-117 10. APl num_l;)..QL~ ,,q.. ~ -- ,~ i,'~ ! 9, T9N, R2OE, UM 11. Field/Pool 4, T.9N, R2OE. UM N/A As o1" z/23/90' feet Plugs(measured)#1 13, t96'-13,002' (39 bbls.) feet #2 13,000'-12,500' (47 bbls.) Junk(measured) #3 11 316'-11,910' (30 bbls.);te ' N/A #4 11,190'-10,883' (~ {~1' ;re * to 20,000 lb Cemented Measured depth True vedical depth 716 bbls. 3512' 3462' 147 bbls. 10763' 10168' *Retainer set 10,713'; 22 bbls. cement below, 6 bbls. above. ,R'ECEj'¥' -: ED Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A APR 2 7 ]gpn 13. Attachments Description summary of proposal __ Detailed operations program X...~.X 14. Estimated date for commencing operation 4/22/90 16. If proposal was verbally approved Name of approver L o nn i e Sm i th 4/20/90 Date approved 15. Status of well classification as: Oil ~ Gas ~ SuspendedX_.~X Service 17. I hereby certify that the foregoing is true aqC~orrect FOR COMMISSION USE OM'LY -ConditiOn's of approval: N~oti,~,y Corem,ss,on so 'representative may witness Plug integrity ~ BOP Test __ Location clearance ~ Me~nan~cai I/tG~rity Test ~ Subsequent form required/lO~ ~ 0 ;,2 Approved by order of the Commission Form 10-403 Rev 06/15188 to [ne laes[ pt my knowledge. David L. Bowl er Title Division Manager Of~IGINAL SIGNED BY ...... ,r_ r SMITH Date 4/23/90 feet ,,, ted t SUBMIT IN TRIPLICATE PLUGGING AND ABANDONMENT PROCEDURE FOR BADAMI #1 1. Set an EZ drill retainer 50~ above the 9-5/8 shoe . e . . . 7. Squeeze enough cement below the EZ drill to fill the area from 10883 to the bottom of the retainer and lay 50~ of cement on top of the retainer. RIH to 350~ and displace the fluids in the casing with water. Downsqueeze 100 sks of type C permafrost into the annulus. Displace with water. Clean the pits and the test tanks. Pump all remaining liquids into the 9- 5/8" x 13-3/8 annulus. Cut the 9-5/8" casing at 185~, RKB (in order to accommodate a 150~ surface plug with its top at 35~ RKB). Nipple down the stack and pull the casing packoff and slips and recover the 9-5/8". Place the BOP stack back on the 13-3/8" casing head in order to take returns to the pits. Set an EZ drill bridge plug in the 13-3/8" on top of the 9-5/8" stub. Place 150~ of cement on top of the bridge plug to bring the TOC to within 5~ of ground level. Cut the 13-3/8" casing at the height of the 20" flange. Install the wellhead marker. M EMORAND)'M State 9f Alaska ALASKA OIL A~ND GAS CONSERVATION COMMISSION TO: LonniecommissionerC. Smit¢~¢$'~'~j DATE: February 20, 1990 mtENO: JT.ADA. 320 TELEPHONE NO: THRU: SUBJECT.' FROM: Petroleum Inspector BOP Test Conoco Badami No. 1 Permit No. 89-17 Exploratory Sec. 9,T9N,R20E,L~. Thursday~ Feb._ 15, 1990: I traveled this date from AAI KRU CPF No. ~1 t--6---~-~~i~ I well to stand by for the BOP test, however; the testing had been delayed due to stack nipple up problems. Friday Feb. 16, 1990: The testing commenced at 2:30 a.m. amd was ~~ at---~--%-]~3~ ~[m. There were six failures during this test 'including the middle Gray Lock clamp on the stack, four choke manifold valves and one gas detector. Please refer to the attached AOGCC BOP inspection report for more specific information about these failures. I was contacted by Conoco representative Don Girlder on 2/18/90 and informed that all failures had been repaired and retested. I~q~iie witnessing the BOP test, I also conducted an inspection manifold. All lines inspected contained threaded and hammer union type connections, i informed Conoco representative Don Girlder of this non-compliance and was assured that these problems would be addressed immediately. The parts needed to repair these lines were ordered this date by Pool No. 6 representative L. Gentry. March 6, 1990: I traveled this date to Conoco's Badami No. 1 well to inspect ~ progress of work on the downstream choke manifold lines on Pool Rig No. 6. Some welding had been preformed on the lines but the clamps and eli's needed to replace the threaded and hammer union connections had not yet arrived. I spoke with Conoco representative Steve Brady and was assured that these parts would arrive and be installed within the next three weeks. In summary, I witnessed the BOP Test and inspected the lines do~stream of the choke nmnifoid for threaded connections on Pool Rig No. 6 at Conoco's Badami No. 1 exploratory well. Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report ns_ectorD ~.~ .... Operator ,'i2D ~/'~ -'.'~'.n t~ Location: Sec :~ '~ ~3, S R ¢0 ~ Loc~ti0n (general) ,~' Well sign General housekeeping ~ Rig DATE Representative Permit # M ,(~, ,,'~ ~ Rig lt. , ~d9 Rep Reserve pit MUD SYSTEMS: Trip tank Pit,gauge F.]O~ monitor Cas detectors Visual Audio BOPE STACK: Annular preventer Pipe rams L4~~ Blind rams .~ Choke line valves HCR valve ~)F~Y' Kill line valves Check valve TEST RESULTS: Test Pressure Casing set ~ ~1 ~- ACCUMULATOR SYSTEM: Full charge pressure Press after closure Pump incr clos press 200 psig Full charge press attained Controls: Master j Remote ft psig psig min ?_~' sec mln ~7 sec ps~g ~ Blind switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly l ~f/ Test pressure Lower Kelly ~ v¥ Test pressure Ball type ! t)( Test pressure ..... Inside BOP } vl~ Test pressure o /. ;~'~:--:-~"~-~hoke manifold__ I ~V' Test pressure ~ ~ ..... Number valves ,~' Number flanges Adjustable chokes Hydraulically operated choke , Failures ~, Test time I) ,~) hrs Repair or replacement of failed equipment to be made within and Inspector/Commission office notified. I da / '"~ Di stri buti on: · ! orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/17/89 December 27, 1989 Telecopy No. (907) 276-7542 David L Bowler Divis ion Manager Conoco Inc 3201 C St Ste 200 Anchorage ~ 99503-2689 Badami No. 1 Conoco Inc Permit # 89-117 Surf Loc 1800'SNL, 4280'WEL, Sec 9, T9N, R20E, UM Btmhole Loc 2780'SNL, 4280'WEL, Sec 4, TgN, R20E, UM Dear Mr Bowler: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pe~itting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~y~ truly %ours, ~ V ~hairman Alaska Oil and Gas Conservation Co~ission BY O~ER OF THE CO~XISSION jo Enclosure C! Department of Fish & Game, Habitat Section - w/o encl Department of EnvirOnmental Conservation - w/o encl STATE OF ALASKA ALASKA ,,.,.,L AND GAS CONSERVATION C,, .iMISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of work Drill ~P{ Redrill EliI lb. Type of well. Exploratory [] Stratigraphic Test [_% Development Oil .- Re-Entry ~ Deepen~1 Service ~ Developement Gas ~ Single Zone il~ Multiple Zone i- 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO INC. ~B ,,'. = 30 feet 3. Address 6. Property Designation 3201 C Street, Suite 200 ADL 365533 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1800 SNL 4280 WEL BADAMI BLANKET S~ 9 T9N R20E top. of pro. du_ctive interval 8. Well number Number 3461 SNL, 42~0 WEL No. I ' 8086-15-54 SEC 4, T9N R20E 2¢~(~°tba~eP4t2h80 WEL 9. Approximate spud date Amount SEC 4, T9N, R20E February, 1990 $200000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth~MOanOTVD) property line 1000 feet 16440 feet 39547 14831 (14000) feet ,, 16. To be completed for deviated wells 17. Anticipated pressure ~see 20 ~,Ac 25035 ie)i2ii_~ Kickoff depth 1767 feet Maximum hole angle .2Ck. ~ Maximum surface 4971 psig Al ,oral depth fTVD) 4918 psig I 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement .... Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 36 20 94 Weld 80 30 30 110 110 376 ft3 17-½ 13-3/8 72 N80 BUT 34~7 30 30 3527 3500. 2392 ft3 12-¼ 9-5/8 40 S95 BUT 12009 30 30 120~ 11450 1730 ft5 8-½ 7" 29 S95 BUT 14'730 30 30 14760 14000 470 ft3 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ' ~'i ' Conductor :[CEIVED Surface IntermediateDEc` 19 t989 Production Ala,~Oi~,& Gas Cons. Liner ;" Anch0raae Perforation depth: measured true vertical 20. Attachments Filing fee ,iX Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~~, ~ Title ~I~~ ; "'-- Commission Use Only Permit Number AP'i number I A p p rove. 12d/a:~¢7/8 9 [ See cover letter ~:~-I17 50-- ¢2..2.~,-.,Z..~..,¢,L9_--o¢ for other requirements Condit'ion's' ~f approval Samples require--d'7-7,~ Yes = No Mud Icg required ;~ Yes No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ,~ Yes '" No Other: by order of Approved by k,,~ , / , Commissioner the commission Date Form 10-401 Rev. 12-1-85 ¢ S "iplicate Mr. Bob Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 Dear Bob' This letter is a follow-up to Steve Brady's letter of December 6, 1989, which addresses your concern about potential shallow gas at the Badami #1 drilling location. In light of your questions, Conoco has further examined both well and seismic information, and has concluded that shallow gas should not be a problem at the proposed drilling location. Our studies encompassed three main areas: velocity data, well data, and seismic data. Velocity Data Attached please find a copy of a revised velocity plot for the Badami #1 area on seismic line UCD-82-05. The dotted line on this plot is the velocity profile for shotpoint 370 that was submitted with Conoco's initial application for the Badami #1 drilling permit. This profile was generated from stacking velocities used during Arco's original processing of line UCD-82-05. The close correspondence between this profile and the sonic log from the Mobil Mikkelsen Bay #1 well (1970 vintage, also attached), strongly suggests that Arco's processor used this sonic log to guide his/her choice of stacking velocities. Conoco does not consider the use of sonic-derived stacking velocities to be a valid processing technique. Line UCD-82-05 was reprocessed by Conoco in 1989. The revised velocities from shotpoint 350 used to re-stack the data are shown by the solid line on the velocity plot. These values were picked directly from a velocity analysis display. They show some hint of a of a lower velocity zone beneath the permafrost, but nothing as marked as the decrease shown on Arco's original velocity profile. Conoco's revised profile is quite similar to the stacking velocity plot for line DZ-5, which was also submitted with Conoco's Badami #1 permit application. Wel 1 Data The low velocity zone present beneath the permafrost layer on the travel time curves from the Mobil Mikkelsen Bay #1 and Humble E. Mikkelsen #1 wells (attached) is most likely due to hole-washout. The transit time across this zone averages 190 microseconds per foot, which is equivalent to the velocity of sound through water. Across this interval, the sonic log was detecting only drilling RECEIVED DEC2119B9 Alaska Oil & Gas Cons. Anchorage Bob Crandall December 21, 1989 Page 2 The gas curves for these two wells show no appreciable increase in mud gas across this zone. The associated mud weight plots also show no increase in mud density across this zone. Seismic Data At the depths in question, overburden pressures are too low to drive gas into solution with interstitial water. If gas were present, it would be free. If gas were free, it would have a sharp contact with underlying water and an abrupt change in velocity would occur. We do not see any "bright-spots" associated with this horizon on any seismic data in the vicinity of the proposed well. In summary, many wells have been drilled in the Mikkelsen Bay area. None of these wells have encountered significant amounts of gas at the base of the permafrost. Conoco believes the casing and well control program planned for the Badami #1 well is safe and adequate. Please call me at 564-7640 if you have any further questions or comments. Steve Davies Staff Geologist cc: R. F. Wheeler S. J. Brady RE£EIVED ~nchorage 't UCD-82-05 ,, BADAMI #1 lb ~-'- -~' ~--- B.H.L. PTD 14,830' 1(-14,000') DZ-5 ',(SP-150) ./ ,l + q. RECEIVED DEC 211989 Alaska Oil & Gas Cons. commissia~ Anchorage · MOBIL MIKKELSEN BAY #1 MMB1 . MD TRAVEL TIME MUD GAS MUD WEIGHT MD DT. Z. 1 GAS. Z. 1 MUD. Z. 1 FT US/FT UNITS t~/GAL FT ~o. oo ~ ~oo. oo o. oo ~.o. oo ..oo 1~.oo ~) .-1 I~ m ZONE i 0. OOF 16600.00F 30" 33 0 ~00 100o NOTE& 1. ,STATE PLANE COORDINATES ARE ZONE 3 ALL GEODETIC POSITIONS ARE BASED ON N,A.D. 1927 OR=SETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POST1ONS ENE 4. PAD ORIENTED TO PREVAILING WIND DIRECTION ~TI~VA~IMU[ MIKKELSEN PT. VICINITY MAP .,~ 208' BADAMI NO. 1 140' 300' ICE PAD LOCATION IN SEC. 9, TgN, R2OE, UMIAT MERIDIAN WELL I FROM NORTH LINE j FROM EAST LINE ' i BADAMI-lJ 1790.97 4279.,58 STATE PLANE COORDINATES-ZONE 3 WELL NORTH (Y) EAST (X) BADAMi-1 5,906,O29.80 365,OO6.21 GEODETIC POSITIONS NAD 1927 WELL NORTH LATITUDE WEST LONGITUDE BADAMI-1 70' 09' O4.327' 147' 05' o7,739' F. Robert CERTIFICATE OF SURVEYOR: i HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND ,SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTH~ DETAILS ARE CORRECT. ,SURVEYED FOR: DATE OCTOBER 24, 1089 DRAWN J3P CHECKED DLR FIELD BOOK SCALE 1':2OO' JOB NO. 80048 "~ ~. ......Cb~.~ Anchoi-aCe The Badami #1 well is to be drilled as a deviated hole on the North Slope of Alaska. The main objective of this well is the Mississippian aged Upper Kekiktuk sandstones, with a secondary objective in the thin-bedded turbidite sandstones and siltstones found in the Seabee Formation. There are seven offset wells near the proposed location. The Shell West Mikkelsen #4 well will be the control well. The surface location will be onshore at: 1800' SNL, 4280' WEL Section 9, Township 9N, Range 20E UM The well will be directionally drilled 4300' North of the surface location to a bottom hole location at: 2780' SNL, 4280' WEL Section 4, Township 9N, Range 20E UM The predicted True Vertical Depth is 14000' or Pre-Mississippian Agrillite, whichever is shallowest. This well will be drilled using the Pool Arctic Alaska Rig No. 6. The casing program is: Hole Casing Weight Grade Connection Depth Size lb/ft MD 26" 20" 94 K55 Welded 110' 17-1/2" 13-3/8" 72 N80 Buttress 3527' 12-1/4 9-5/8" 40 S95 Buttress 12039' 8-1/2" 7" 28 S95 Buttress 14760' The 20" conductor will be set before moving in and rigging up Rig No. 6. A 21-1/4" MSP, 2000 psi diverter will be nippled up prior to drilling the 17-1/2" hole. A WKM, 5000 psi wellhead will be used in conjunction with the 13-5/8" 10,000 psi BOP while drilling the 12-1/4" and 8-1/2" hole sections. The amount of permafrost found along the North Slope varies with the proximity to shore. Wells drilled in the shallow offshore regions have encountered little to no permafrost. Wells drilled on shore have encountered permafrost as deep as 2500'. The Badami well, due to its proximity to the shoreline, is expected to encounter permafrost to a depth of 1900'. in some areas at the base of the permafrost. Veloci~0~veys in this area do not indicate the presence of shallow gas; however the interval from the base of the permafrost to the 13 3/8" csg. point should be control drilled in case unexpected gas is encountered. Throughout the surface gravel zones the initial mud funnel viscosity requirements will be in the 250-300 sec/qt range. Below the initial gravel zone, maintain the viscosity to the actual hole cleaning requirements, in the 50 to 70 range. The mud temperature should be kept as cold as possible through this interval to avoid thawing of the permafrost. The 13-3/8" casing will be set in the undifferentiated zones of the Sagavanirktok formation. After setting the 13-3/8" casing, the spud mud will be dewatered and the solids disposed of in the reserve pit. The water will be used as make up water for the next hole section. After drilling out with a 9.0 ppg mud, a leak-off test will be performed. A minimum leak off of 12.4 ppg EMW should be reached. If this is not attained the shoe should be squeeze cemented through an E-Z drill packer. However the squeeze pressure should not be allowed to exceed the collapse pressure rating of the 13 3/8" csg. (2670 psi) Solids control must be maintained throughout this interval. The pore pressures are expected to be .465 psi/ft throughout this interval. A secondary objective lies below 8130' TVD. It is not anticipated that these sands will be cored. The 9-5/8" casing will be set 100' into the Hue Shale which is expected at 11350' TVD. The Hue Shale is marked by an increase in gamma ray activity and an abrupt decrease in resistivity. Also the shales are dark brown to black in color and are commonly bentonitic. Mud weights at the bottom of this hole interval should range between 10.0 ppg and 10.5 ppg. After setting the 9-5/8" casing, a leak off test will be conducted. The mud weight will range between 9.8 ppg and 10.5 ppg. Continue to control the solids as much as possible. The Upper Kekiktuk Formation is the primary target and lies at approximately 11890 ft TVD. A core will be cut through this interval starting 50 ft above the LCU. The HRZ (Highly Radioactive Zone) will be used as a marker to identify the interval to core. The HRZ lies approximately 230 ft above the LCU and is very similar to the Hue Shale in lithology and depositional setting but is distinguished by a further increase in radioactivity. The Lower Kekiktuk Formation underlies the Upper Kekiktuk and is considered as a secondary objective. It is not planned to core this interval. The Pre-Mississippian Agrillite at 13500 ft TVD is considered economic and geologic basement, although one well at Pt. Thompson produced gas from a carbonate at the top of the agrillite sequence. The wireline logs will be run in the 17-1/2", 12-1/4" and the 8- 1/2" hole sections as listed in the logging program. Cores will be taken in the 8-1/2" section starting at 50 ft above the LCU and continue through the base of the Upper Kekiktuk. The total length of the core should not exceed 400 ft TVD unless the base of the core is still within an oil or gas zone. The core will be processed as outlined in the Geological Well Plan. The anticipated core interval may be shortened if the oil water contact is encountered sooner. The well will be directionally drilled as a slant to total depth. The kick off point will be at 1767' TVD, building angle at a rate of 1.5 deg/100' using a bent sub and a mud motor. MWD Surveys will be taken at the 20" shoe and at 100' intervals to the kick off point. During the build section MWD surveys will taken on 30' intervals and at 100' intervals during the hold section. A gyro survey will be run in the 9-5/8" casing. At TD, a magnetic multishot will be run. All surveys shall be referenced to Section Grid System. The Magnetic Correction for this is 31.36 degrees. A decision will be made at TD whether to run the 7" casing string. BADAMI # 1 PROPOSED WELL PLAN OUTLINE [WELL] # 1 [SURF]lBO0' SNL, 4280' k/EL, SEC 9 T9N-R-20E UM [TARGET]UP. KEK. [TARGET]2780' SNL, 4280' k/EL, SEC 4 T9N-R20E UM [DEPTH]) [FORMATION] I [DRILLING] I [FORMATION] ) [HOLE] I [CASING] ) [MUD] [MD] I [TOPS] ) [PROBLEMS] I [EVALUATION] I [SIZE] I [PROGRAM] [TYPE & k/EIGHT] 500 1000 1500 2000 25OO 3000 . 3500 4000 . 5000 6000 7000 8000 9000 10000 11000 12000 13000 . 14000 . 15000 BASE OF PERMAFROST @ 1900 ' EOCENE @ 4600'TVD SCHRADER BLUFF @ 6750' TVD SEABEE @ 8130' TVD HRZ @ 11670' PT. THOMPSON 11850' TVD UPR. KEK. @ 11900' TVD Lk/R KEK. @ 12300' TVD TD @ 14000' ARGILLITE GRAVEL COAL BEDS KOP @ 1767 SHALLOk/ GASi BUILD RATE 1.5 DEG/IO0 MAX. ANGLE 20.43 DEG COAL BEDS TO 4300~ AVG. ANGLE 20.43 DEG Core COAL BEDS GR/DIL/BHC 36" 17.5" 20" 13 3~8" 72 LB/FT N-80 3500'TVD 3527'MD AIR 9.0 - 9.5 PPG SPUD MUD 200-300 VIS Mk/D: GR/RES. FDC/CNL/BHC/ISF Sk/C FDC/CNL/BHC/ISF SWC/HDT/VSP 12 1/4" 9 5/8" 40 PPF S-95 !11450' TVD 711 29 LB/FT S-95 14000' TVD 10.0 - 10.5 PPG NON DSPRSD POLYMER 9.8 - 10.0 PPG NON DSPRSD POLYMER Directional Program The Badami #1 well is to be drilled as a deviated hole from an onshore surface location of: 1800' SNL, 4280' WEL Section 9. Township 9N. Range 20E UM The well will be deviated 4300' North of the surface location to an offshore bottom hole location of: 2780' SNL, 4280' WEL Section 4, Township 9N, Range 20E UM The predicted True Vertical Depth is 14000' or Pre Mississippian Argillite, whichever is shallowest. The target objective is the Upper Kekiktuk Formation at a depth of 11890' TVD. The target shall be penetrated no further than 500' North, 2000' South, 1500' East, of 1500' West of the bottom hole location as described above. The well will be kicked off at 1767' TVD with a bent sub and a mud motor. The rate of build will be 1.5 deg./100'. The angle will be built until a maximum of 20.43 degrees is attainted. Once maximum angle is reached it will be maintained until reaching TD and penetrating the target objective as described above. The bottom hole assemblies described in the Bottom Hole Assembly Section shall be used. All surveys shall be referenced to Section Grid System. The magnetic correction for this is 31.36 degrees. GREAT LAND DIRECTIONAL DRILLING, INC. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for CONOCO Well ......... : BADAMI NO. 1 Field ........ : BADAMI PROSPECT MIKKELSEN BAY Section at...: N,0.00,E KB elevation.: 0.00 Computation..: RADIUS OF CURVATURE Case ID ...... : BPMBPA WELL PROFILE Prepared.: 12/18/89 STATION IDENTIFICATION KB KOP BUILD 1.50/100 END OF 1.50 BUILD SEABEE HRZ PT. THOMPSON TARGET OBJECTIVE UPPER KEKIKTUK LOWER KEKIKTUK MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 0.00 0 0 0 N 0.00 E 0 N 0 E 1767 0.00 1767 1767 0 N 0.00 E 0 N 0 E 3129 20.43 3100 3100 240 N 0.00 E 240 N 0 E 8496 20.43 8130 8130 2114 N 0.00 E 2114 N 0 E 12274 20.43 11670 11670 3432 N 0.00 E 3432 N 0 E 12466 20.43 11850 11850 3499 N 0.00 E 3499 N 0 E 12509 20.43 11890 11890 3514 N 0.00 E 3514 N 0 E 12519 20.43 11900 11900 _ 3518 N 0.00 E 3518 N 0 E 12946 20.43 12300 12300 3667 N 0.00 E DL/ 100 0.0 0.0 1.5 0.0 0.0 0.0 0.0 0.0 3667 N 0 E 0.0 ARGILLITE/B.H.L. 14760 20.43 14000 14000 4300 N 0.00 E 4300 N 0 E 0.0 oI A ! BOO ) .... 2400 3200 4000 4BO0 5600 T 6400 7200 BO00 BBO0 9600 10400 11200 , , 8 -'BUILD i I I .50 dog/ilO0 ft 12000 14400 BOO 0 800 AVERAGEJ ANGLE 2~.43 deg i , J, Marker Identification AIKB B) KOP BUILD 1.50/100 C) END OF t.50 BUILD IDI SEABEE ., Fi PT. THOMPSON GI TARGET OBJECTIVE H~ UPPER KEKIKTUK II LO~ER KEKIKTUK I J) ARGILLITE/B.H.L. '! VERTICAL SECTION CONOCO 8ADAMI NO. I Section at: N 0.00 E TVD Scale.: 1 inch = 1600 feet Den Scale.: 1 inch = 1600 feet Drawn .....: 12/18/B9 MD TVD DEPRT INCLN O 0 0 0 O0 1787 1787 0 0 O0 3t29 3t00 240 20 43 8496 8t30 2tt4 20 43 12274 11870 3432 20 43 12466 11850 3499 20 43 12509 1t890 3514 20 43 12519 11900 3518 20.43 12946 12300 3667 20.43 i4760 14000 4300 20.43 1600 2400 ~00 4000 4,~00 5Eoo ~;400 7200 ~000 Departure Marker Identification MD N/S E/W A) KB 0 0 N 0 E B) KOP BUILD t.50/t00 1787 0 N 0 E C) END OF 1.50 BUILD 3t29 240 N 0 E D) SEABEE 8498 2114 N 0 E E) HRZ 12274 3432 N 0 E F) PT. THOMPSON 12466 3499 N 0 E G) TARGET OBJECTIVE 12509 35t4 N 0 E HI UPPER KEKIKTUK 12519 3518 N 0 E I) LOWER KEKIKTUK 12946 3667 N 0 E J] ARGILLITE/B.H.L. 14760 4300 N 0 E FLAN VIEW CONOCO BADANI NO. 1 CLOSURE ..... : 4~00 ft N 0.00 E DECLINATION.' 21.27 E SCALE ....... : 1 inch = 700 f~et DRAWN · 12/1B.!~9 4550 4200 2B50 3500 2i50 2BO0 2450 2i00 i750 1400 7O0 25O 2t00 , -- t N O.OO E i750 i400 t050 7~,0 350 O ,~50 700 l;JSO i400 i/FO MUD PROGRAM Hole Size: 17-1/2" Interval: 80'-3500' TVD Mud Type: Spud Program: Drill this interval with a high viscosity fresh water spud mud. The initial viscosity requirements will be in the 250- 300 sec/qt range throughout the surface gravel zones. Below the initial gravel interval, maintain the viscosity relative to the actual hole cleaning requirements. All make-up water should be from the water source lake in order to keep hole erosion, due to melting of the permafrost, to a minimum. Maintain high annular velocities through this interval. Past experience has shown this to be more effective for hole cleaning than manipulating mud rheology. Run all solids control equipment to maintain abrasive solids content below 1%. Properties: Density: 8.8-9.6 Vis: 250-300 seq/qt, initial 50-70 sec/qt, final PV: 15-30 cps YP: 15-70 lb/100 sqft pH: 8.5-9.0 Solids: <10% Filtrate: 12-25 cc's, initial 8-12 cc's, final Hole Size: 12-1/4" Interval: 3500'-11450" TVD Mud Type: .. pHpa Program: Drill this interval with a fresh water, pHpa polymer system. Initial polymer make-up should be .75 ppb. Do not add bentonite to the mud during initial make-up. Bentonite should only be used to improve wall cake. All solids control equipment should be run 100% of the time. Excessive amounts of fines are counterproductive to a polymer mud system. Increased concentrations of pHpa may be added if cuttings and wellbore conditions indicate a lack of polymer. Weight up the mud as hole conditions dictate. Use barite to weight up, do not let the mud weight creep up using drill solids. Additions of anionic polymer may be used to maintain the desired yield point. A polymer deflocculant can be used on an as-needed basis to control excessive rheology, which may develop. Avoid the use of lignites and lignosulfonates until other techniques have proven unsuccessful. To successfully drill the shales in this interval the following guidelines should be followed: a. Avoid mechanically disturbing the shale, minimize reaming and excessive surge and swab pressures. b. Avoid turbulent flow in the annulus. c. Maintain adequate rheological properties for proper hole cleaning and suspension. d. Keep API filtrate low. e. Circulate bottoms up prior to tripping. f. Minimize exposure time. g. Maximize solids control efforts to insure effective and performance. Properties: 3500'-9500' Density: 9.0-9.5 ppg Vis: 35-40 sec PV: 10-15 cps YP: 8-12 sec/100 sqft Gels: 4/8 pH: 8.5-9.0 Solids: <8% Filtrates: 8-10 cc's 9500'-11900' 9.5-10.5 ppg 40-50 sec 15-20 cps 10-15 sec/100 sqft 6/10 8.5-9.0 <13% 5-6 cc's Hole Size: 8-1/2" Interval: 11450'-14000' TVD Mud Type: pHpa Program: Drill out of the 9-5/8" casing and dump the severely contaminated mud. Reduce the mud weight to 9.8 ppg or as allowed by hole conditions. Reduce the mud weight by mechanical separation and dilution. Continue to treat the mud as in the last interval. Maintain the pH at 9.0-9.5. Properties: Density: 9.8-10.5 ppg Vis: 40-50 sec PV: 10-20 cps YP: 8-20 sec/100 sqft Gels: 8/12 pH: 9.0-9.5 Solids: <12% Filtrate: 5-6 cc's Oi Drilling Ti xe Curxze i i i i i i e i -1 -2 -3 -4 -5 -15 -7 -8 -9 -1i3, -11 -12 -13 -14 -15 -1t5 ,i I ................. .............m .......................................................... ....... o .... 4. ..... . .... . .......... i i i , i i i i i 11. 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 II itl Ii I II] i I !1111 I i !III! I !! !!1 iI i~! I I I I i Ii Iil iil i iIIt Ii I ~1 I IIIii!!! .... I ..... I I i J i i I i t i I I i I i i I i t I I I i t I i X i i i m ! t m m , · I · ' ............ . ......... .~ ............. at. ....... S ...... ~. _ ,., ....... ~ ................... .~ ....................... · ................... .." ~,_ - Log set 9 5/8 "- ,". . ." ...................... 4 ................. ~ ' ,---------------,---- .............. ~- ...................... 4 ....................... { ....................... m i ....~'' , m m i , i m m i i i m I i Ill lllll II!11111 ii~1111 iliitlllllllllliltillllllillllll I ! I ! !i Iil !1 ---------------.-- ..-o,.,..o.- .... -.-------- ....~---o--------------- ....i---------o ---------,,~* -- .~---..--...... ! i i ! i i Ii I I I ......... ~... o.........~.......................a.......................~...~............, o.......m...........o........... · ~;; ,.. :.; ;.............. e i i e e I i i I m i m m I I , I · O 10 20 ~ 40 ,50 60 Days Maximum Anticipated Surface Pressure Maximum anticipated surface pressures were calculated assuming a full column of dry gas at reservoir pressure less the hydrostatic pressure exerted by the gas. The maximum pressure will be encountered at 11450' TVD and is 4971 psi. The maximum surface pressure which could be encountered at TD is 4918 psi at 14000' TVD. i U~U-UZ-UO - SP 370 ¢o/uoco .... , ..... , . MD TRAVEL TIME a~ DTUCD. Z.2 FI US~FI ~0.00 200.00 , . _ , .... ~00 1000 ,,oo ' ~ , ' 2800 4~00 , sooo I I oooo , I ~ 13 3f8"' ~ ,' ,' eaoo ~ 7000 ~800 ~ ~ t ~ooo , e.oo l ~oo0 t ~ i 7000I , 7,a00 ~r 8000 ,i{:,, . I -.o0~ 10000 , 10500 14000 14~00 ~OOO ,,, PRFISURE 8 CHECK LIST FOR NEW WELL PERMITS ITEM ~ APPROVE DATE (2) Loc ~8 /?? (8) (3) Admin/pc (4) Casg Company Is the permit fee attached .......................................... Lease & Well No. /~/2~ YES NO 2. Is well to be located in a defined pool ............................. 3. Is we:l] located proper distance from property line .................. ~ 4. Is w~,l_located proper distance from other wells .................... 5. Is suz~icient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... ~. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~_ Does the well have a unique name and number ......................... (9 thru 13) 10. (10 and 13) 12. (14 thru 22) 14. 15. (5) BOPE ~%,//~ )z-zz-£~ (23 thru 28) 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER (29 thru 31)~ (6) Add: Geology: Engineering: rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. _~_ Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented A~ Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 0 HO o~ 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. PP PP PP PP PP PP PP PP PP PPPPP PPPPPP PP ~P PP~PPP PPPPP JUL 1 2 1990 ,,Alaska Oil & Gas Cons. uommission Anchorage AAAAAA AAAAAAAA AA AA AA AA AAAAAAAA A~AAAAAA AA AA AA AA AA ~A ~ AA 111 il 11 11 11 11 11 11111111 11111111 O0 000000000 000000000 O0 000 O0 O0 00030 O0000 O0 OOOO O0 000 O0 000000000 000000000 O0 CCCCCC CCCCCCCC CC CC CC CC C,,. CC CC CCrCC'"CC~ ,, CCC,.'- ~ 55555555 555555 77777777 77777777 77 777 777 777 777 777 777 777 777 O0 O0 .'300000000 000000000 OOOO0000O 000000000 00 000 0 e O 0 .-., ,-. ,', ,", n ,-, nO 0000 2'2 03."]'C~'" O0 00000 ¢00.00 O0 0,3000 0n S: O""J 0CS OOOC O0 COS' 03 gOO CO cc; .....: .., '., 0 "' "' '" ,] 03 O00 O00 O""'" r'- 0000 O,.. j ._ , CO0000000 O0000000C 00' 0~'~ O0 0003 O0 00~00'~ 00000 O0 0000 O0 000 O0 000000000 000000000 MICROFILMED !111 999999~9 11 99 99 11 99 99 11 99999999 11 9999999 11 99 11 ~9 11111111 9999~9~ 11111111 9?999 OtlGIIIAL el :'':::,, '::: · // /t/ /// /// 1// /// /// /// /// /// /// // CO0000000 O0 000 O0 0000 O0 00000 00000 O0 0000 O0 000 O0 000000000 000000000 O0 222222 22222222 222 22 222 222 222 222 222 22222222 22222222 il III !11 III Iit II! III III III III I I/ II PROGRAM: LISCAN REVISION: 5,1 ORIGINAL PART NUMBER: W5790-PE32 Start of ex, ecut±on: Mort 2 JLY 90 3:00: **** REEL HEADER ***w LIS 90/04/04 ATLAS 01 ~'LIS CUSTOMER FORMAT T~PE'' **** TA~E HEAOER ~*** LiS 90/04/04 4266 01 'OPEN HnLE-LSAL~ 'ZDL/CN,OI:L,DCL2~ : RANG=~ IS 0-1~5~0~ ~ FT' miLE m 1 MAIN .001 1024 CN : CONOCO INC. WN : 8AD~MI 1 FN : PRUOHOE BAY COUN : NORTH SLOPE STAT : ALASKA COMMENT RECORD * COMPOSITE OI~L - MAIN P~SS. , FORMAT ~ECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 16 CURVES : * D~TA RECORD -999 -999 -999 DEPTH CAL T2q2 CILD 530.000 ,2500 .2500 .2500 13480.000 -999.2500 -999.2500 -999.2500 13430.0C0 -999,2500 -999,2500 -999.25G0 13330,000 -999,2500 -999,2500 -999,2500 13330.000 -999.2500 -9~9,2500 -999,2500 13280,000 -999.2500 -999,2500 -999,2500 13230,000 -999,[~00 -999,2500 -999,2500 13180,000 -999,2500 -ggg_?~NN (TYPE~ GR TEMP TlR2 RiLM -999.2500 -999.25C0 -999.2500 -999.2500 0.0000O00 -999.2500 -999.2500 8.555737 102,2022 -999.2500 -999.2500 20.69205 136,3720 -999,2500 -999,2500 16,44868 65,257:$& -999.2500 -999.2500 31,79115 119,7523 -999.2500 -999,2500 13,10712 59.26790 -999,~5G0 -999.2500 30.80865 102.7666 -999,2500 O) 95.~ BYTES * SPD T T.-=_ N TlR1 -999,2500 -999,2500 -999.2500 27,99721 6275,602 -999,2500 28,23300 6240,316 -9¢9,2500 27,99721 6159,520 -999,2500 27,99721 6123.289 -999.2500 28,55210 6256,832 -999,2500 27,99721 6149,Z30 -999.2500 27,99721 6094,977 -ooo ~ SP RFOC -999.2500 -999,2500 -999,2500 13,09219 -999.2500 9,089048 -4,299891 -999.2500 22.44174 -21,25008 -999,2500 31,44548 -38,86517 -999,2500 65,64975 -36,66333 -999,2500 21,97298 -46,89384 -999,2500 64,45670 -45,15822 -999,2500 CHT T2R2 RILD -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 7,994205 -999,2500 -999,2500 1&.71700 -999,2500 -999,2500 20,68810 -999,2500 -999,2500 47,32159 -999,2500 -999,2500 14,27618 -999,2500 -999,2500 56,30705 -999,2500 -999,2500 40 AA?O~ 131~30,000 -999.2500 -999.2500 -999.2500 13080,000 -9~9.2500 -999.2500 -999.2500 13030.000 -999.2500 -999.25C0 -999.2500 12980.000 -999,2500 -999.2500 -999.2500 12930,000 -999.2500 -999.2500 -999,2500 12880,000 -999.2500 -999,2500 -999.2500 12830,000 -999.2500 -999.2500 -999,2500 12780.000 -999.2500 -999.2500 -999,2500 12730.000 -999,2500 -9~9.2500 -999.2500 126~0,000 -999.2500 -999,2:00~ -999.2500 12630.000 -999.2500 -999,2500 -999.2500 12580.000 -999.2500 -999.2500 -999,25G0 12530.0C0 -999.2500 -999.2500 -999.p~nn 102.9808 -999.2500 -999.2500 37.97232 46.62569 -999.2500 -999.2500 12,46507 63.795'32 -999,2500 -999,2500 27.21883 125.2300 -999,2500 -999.2500 17.42252 38.~7327 -999.2500 -999.2500 10.66796 105.2322 -99~.~500 -999.2500 20.82507 25,07906 -999,2500 -999,~5C. 0 4,209522 86.25561 -~99.2500 -999,2500 22.71181 61.96349 -999.2500 -999,2500 41.10185 122.40~7 -999.2500 -999,2500 15.30769 10~.~749 -999,2500 -999.2500 36.32803 232.353S -999.2500 -999.2500 10.38643 234.7901 -999.2500 -999.2500 ~_~??~1~ 27.997~1 6 ~:70.531 -999.2500 27.99721 5959,570 -999.2500 27.99721 6083,76~ -999.2500 27,99721 6056.824 -999,2500 27.99721 8116.109 -999.2500 27.99721 590S.773 -999.2500 28.99710 5964.109 -999,2500 28.99710 5981.770 -999,2500 28.99710 5943.344 -999.2500 28,99710 58 ~ ~3.137 -99c.2500 25,~9710 593'7.316 -999,2500 28.99710 5829.89~ -999.250g 28.99710 5927.910 -999.2500 -55.63399 -999,2500 71,48222 -65.~7119 -999.2500 21 .09038 -42.19003 -99~.2500 45.95107 -27.267?0 -999.2500 25.08339 -71.72328 -999.2500 17.63232 -31.98111 -999.2500 31.93182 -61,16209 -999.2500 11,85423 -17.53902 -999.2500 35.45587 -40.66112 -999.2500 62.52612 -12.16527 -999.2500 20,36005 -20.03484 -999.2500 45.94240 7.079444 -999.2500 29.64082 12.65606 -999.2500 6.764817 -999.2500 -999.2500 58.88177 -999.2500 -999.2500 11.73653 -999.2500 -999.2500 41.39320 -999.2500 -999.2500 20.85896 -999.2500 -999.2500 9,621717 -999.2500 -99Q.2500 25.22325 -999,2500 -999,2500 2,680060 -999.2500 -999.2500 29.69499 -999.2500 -999.2500 85.01970 -999.2500 -999.2500 16.77037 -999.2500 -999.2500 54.81721 -999.2500 -999.2500 11.58201 -999.2500 -999.2500 4.706237 12430. -999. -999. -999. 12430. -999. -999. -999. 12350. -999. -999. -999. 12330. -999. -999. -999. 122~0. -999. -999. -999. 12230. -999. -999. -999. 1 21 80. -999. -999. -999. 12130. -999. -999. -999. 12030. -999. -999. -999. 12030. -999. -999. -999. 11930. -999. -999. -999. 11930. -999. -999. -999. 11880. -999. -999. -999. 000 2500 2500 2500 000 2500 2500 2500 OCO 2500 2500 2500 000 2500 2500 2500 000 2500 2¢00 2500 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2~00¢ 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2500 203.6697 -999.2500 -999.2500 5.146312 249.8415 -999.2500 -999.2500 2.942827 107.1 384 -999.2500 -999.2500 5.343166 115.2539 -P99.2500 -999.2500 7.096797 121.0351 -999.2500 -999.2500 2.516077 97 61*'~ -999.2500 -999.2500 3.285626 $5.45265 -999.2500 -999.2500 7.733830 88.81766 -999.2500 -999.2500 8.929340 84.7~678 -999.2500 -~99.2500 6.552065 7~.57852 -999.2500 -999.2500 ~.134363 94.07~33 -999.2500 -999.2500 5.985726 85.31377 -999.2500 -999.25'00 7.412457 90.37840 -999.2500 -999.2500 5.276596 2~.99710 5 8o8.8.,,5 5 -999.2500 28.99710 5897.535 -999.2500 28.99710 5847.945 -999.2500 2~.99710 5800.402 28.99710 57-59.766 -999.2500 2~.99710 ¢633.1Ol -999.2500 29.10631 5.500. 523 -999.250C 29.23289 5700.703 -999.2500 25.99710 5649.207 -999.2500 29. 2~289~ 5629.871 -999.2500 28.99710 5592.148 -999.2500 29.3421~ 5630.063 -999.2500 28.99710 5542.652 -999.2500 10.60611 -999.2500 1 2 · 06076 4.486076 -999.2500 5.112757 7.238507 -999.2500 10.16275 14.67992 -999.2500 12.51219 17.13130 -99~.2500 3.637911' 11.49637 -999.2580 7.354175 10.44291 -999.2~00 7.995390 7.720370 -999.2500 9.286070 10.94595 -999.2500 7.293156 9.066360 -999.2500 7.935375 12.04629 -999.2500 5.736335 9.220911 -999.2500 7.162929 15.21143 -999.2500 4.339622 -999.2500 -999.2500 4.307197 -999.2500 -999.2500 3.023795 -999.2500 -999.2500 5.120671 -999.2500 -999.2500 7.271593 -999.2500 -999.2500 2.4910Q7 -999.2500 -999.2500 4.19,$947 -999.2500 -999.2500 7.976995 -999.2500 -999.2500 8.894354 -999.2500 -999.2500 6.6~3908 -999.2500 -999.2500 8.475800 -999.2500 -999.2500 5.980412 -999.2500 -999.2500 7.577661 -999.2500 -999.2500 5.659159 -999. -9'99. -999. 11780, -999, -999, -999. 11730, -999. -999, -999, 11680. -999. -999. -999. 11630. -999, -999, -999, 11580. -999. -999. -999. 11530, -999. -999, -999. 11450, -999. -999, -999, 11430, -999. -999, -999, 11380, -999. -999, -999, 11330, -999, -999, -999, 11280, -999. -999. -999, 11230, -999. -999. -999, 2500 2500 2500 000 2500 2500 2500 000 2~00., 2500 2500 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2500 000 2500 2500 2500 -999,2500 -999,2500 8,134895 94.19548 -999,2500 -999.2500 5,301419 86.94839 -Q99.2500 -999,2500 4.767399 93.52377 -999,2500 -999.2500 4,757395 98,46870 -999,2500 -999,2500 ~,922488 95.00670 -999.2500 -999.2500 5.238157 97.59297 -999.2500 -~99.2500 5.271013 90.92415 -999.2500 -99c~.25C0 5.031887 91,97543 -999.2500 -999.2500 5,857321 88,25253 -999.2500 -999.2500 6.317132 90,39731 -999,2500 -999,2500 6,610250 86.90640 -999,2500 -999.2500 5.151550 93,91835 -999,2500 -999.2500 5,984253 5518.676' -999.2500 29,65201 5471,637 -999,2500 28.99710 5431 .508 -999,2500 28.99710 5485.555 -999,2500 29,34210 5418.902 -999,2500 28,99710 5440.176 -999,2500 28.99710 5470.254 -999,2500 29,99701 5358,836 -Q99,2500 29,99701 5338.105 -999,2500 29,99701 5373.824 -~99,2500 29,99701 5223,316 -999,2500 29,99701 5224,801 -999,2500 29.99701 5081,879 -999,2500 -999.2500 9,012680 14,97059 -999,2500 5,667971 17.07G08 -999,2500 5,217170 20,~3202 -999,2500 5,203836 19,70929 -999.2500 5,231523 18,41756 -999,2500 5,752533 17,00110 -999,2500 5.684915 19,87259 -999,2500 5.578731 16.69734 -999.2500 6,228723 16,03326 -999,2500 0,310962 17,11536 -999,2500 6,358295 18,68623 -999,2500 5,838246 17,618~8 -999,2500 6,629608 -999.2500 9,266277 -999.2500 -999,2500 5,354135 -999,2500 -999,2500 5,012956 -999,2500 -999,2500 4,738553 -999.2500 -999.2500 5.177798 -999,2500 -999,2500 5.309170 -999,2500 -999,2500 5,364353 -999,2500 -999,2500 5.115295 -999.2500 -999,2500 5.947948 -999,2500 -999,2500 6,702744 -999,2500 -999,2500 6,613500 -999,2500 -999.2500 6,413992 -999.2500 -999,2500 5,907027 111 $0 , 000 91 . 01 385 29 . 99701 1 ~ . 17614 -99.0.. 2500 -999.2500 -999.2500 11130.000 -999.2500 -999.2500 -999.2500 11080,000 -999.2500 -999.2500 -999.2500 11030.000 -999.2500 -999.2500 -~99.2500 10980.000 -999.2500 -999.2500 -999.2500 10930.000 -999.2500 -999.2500 -999.2530 10880.000 -999.2500 -999.2500 -999.2500 10830.000 -999.2500 -999.2500 -999 250~ 10750.000 -999.2500 -999.2500 -999.2500 ~'~10730.000 6.000000 868.1250 42.62068 10680,000 2.746001 838,8750 94.01337 10630,000 1.954301 339.5000 110.6297 10530.0'"' 0,..., 3,797.4.00 832.1875 112.7044 10530,000 3.62~402 -999.2500 6.372914 92.30331 -999.2500 -999.2500 6.376651 92.48253 -999.2500 -999.2500 6.125176 80.07489 -999.2500 -999.2500 6.178131 62.6;~ 14"-, -99o. 2':,00 -099.~500 15,17~.79 e8.12776 -999,2500 -99o.2500 14-49777 57.71510 -999.2500 -999.2500 14.00678 38.98795 -999.2500 -999.2500 26.80122 64.91704 -999.2500 -999.2500 7.288156 36.79907 0,0000000 850.6875 10000.00 45.5607'? · 4' 10000.00 50.73502 o44,0000 O,lOOO00O 0.0000000 142,0731 ~1.3750 0.2000000 77,150.36 -999.2500 29,99701 5076.953 -999.2500 29.99701 5188.742 -999.2500 29.9~701 5049.281 -9~9.2500 29.99701 4928.328 -999.1500 43~$.418 -o99.'~5n0 29.99701 4909.61 3 -999. 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OdS !, B9 ~'3 i, dN~'S _~003 --] b~ N : SDA~Jn3 9 I, id : ±iNR H£d2O Bd~l inked ~2d H£dBO ]NO Z 'ON i~3d3~ ~ NN8 'I~IQ ~ 0~032~J INgWW02 ~ 1,070.063 865.1326 3.234401 1144.688 425.32/,2 4950.000 3.540701 1161.813 491.3477 4930.000 3.882201 1206.938 639.3057 4880.000 4.000001 11~0.43~ 441.1543 4S30.000 4.539400 I 24 2.81 S 612. ;~130 4780.000 4.000001 1359.500 110~.094 4730.000 3.848001 1180.813 421.8337 4680.000 3.447900 1183.375 441.5342 4630.000 5.076800 1182.688 482.2517 4580.000 4.264800 1191,000 490.4590 4530.000 5.515201 1290.625 872.2493 4480.000 3.974501 1385,438 1129.115 4430.000 3.94900~ 1250.000 1.669678 62.68729 93,80974 1152.375 2.533213. 52.96924 o~ 651 0c 1176.750 2.146433 58.09285 93. 4020'~ 1218.875 1 .786439 56.61366 93,10516 11~0.563 2,389185 ~9.83160 92.76921 1256.750 1.972589 46.78729 '?- 2. 55600 1358.000 I .091204 69.35924 92.23929 1191.438 2.529048 61.~3031 91.84969 1190.125 2.454377 58.93439 91.46140 1194.250 2.282025 61.46011 90.96123 1202.375 2.184667 36.68816 90,49875 1423.063 1.282271 40.8~087 90.17790 I 524.875 I .009346 50.11998 840.3750 ¢ 18.88890 3139.481 924.8750 9.999001 3071.714 944.6875 10,99890 3041.414 988,8125 17.9~820 3091.796 923.3125 17.99820 3070,389 1010.125 17.99820 3041.128 1123,125 17,99820 3094.470 957,1875 17.99820 -- 3090.398 961.0000 17 .'99820 3053.813 965.3750 17.99820 2962.883 964.3750 17.99820 2969.891 1176.313 12.99870 2953.545 1250.125 12.99870 3.917229 65.24907 112.7796 3.331048 52.94481 113.7494 3.064114 56.66183 121.3053 2.765100 58.38383 112.7225 3.285867 61.61 368 118.1353 2.831074 38.11520 132.7447 2.334979 67.78506 114.2080 3.191277 62.58611 114.3154 3.518441 53.29128 114.1624 3.397129 53.38582 118.7472 3.239815 31.12036 124.3122 2.517403 35.88545 131.1214 2.155248 42.75188 1.503460 834.2954 913.1250 2.351148 813.2769 .~28. 9375 2.035219 821 .5513 976.7500 I .554197 829.9316 910.3125 2.266781 831.2007 995.6250. 1.631819 822.3892 1108.563 0.9073638 857.6201 941,2500 2.370603 869.5649 947.9375 2.264831 862.1946 950.8125 2.073606 840.8967 950.0000 2.038906 849.6091 1038.938 1.146461 833.1292 1106.688 0.8856498 857.7905 /? 0~8"£~0~ 6£~'~8 O~Z£ '956 ~B6~O6'E O0~'~ZO[ ~966'99~ £~B '~901, £96991,"E O~Z£ 'BZ6 O0~Z'Z96 ~£06~T"~ ~E90'096 0£9~'69g O0~Z'BS6 ~9ZO'~Z9 £~£"~E0~ ~[~9E9'[ O~Z"~O~ 909£'E9B 1,06 Z~£O"~9B 91,8+z9Z"£ 6£~TL"LZL I,Z~£Z'££ ZO90g'05 ~6/..90' £ 8909~ "Z9 LO86Z6'~ 9 LZ~/'O£ L £9~£Z'g9 90~'£9'~ £~g~'£ 9gO+z'6L I, £O~0'9LL 9BSOO'Z~ .6c50B9'95 gZ60'6LL ~9B~Z'6~ g6~g"ZLL 6£~£9~ '£ E9~,9Z9'~ 1,9~7L'~£ ~Z9'6ZSE O~B66'~L 99L'9£01, 99g'£09~ 0~g66'~ i, ~ZB9'£96 SZB'9601, .~9~7' tZ9~ 1,6Z66 '0~ O00'LgOL LZB'99Z~ L6Z66'O~ qZg9 '066 06 I. · L£ZZ 090Zg'OL 00766'6L ~L~'L96 ZOZ'06S~ OOg66'6L 00~'066 0~9'L£6~ OOB66'6L B£6'9£OL 96~' i. 6'88 00866'61. 60£'£L6~ O~g66'~L O.cZ' i,,~O I, F.~9'61,6Z 0SB66'~1, £9~'6£1,1, £ZL'996~ 0 ~g66 ~' ~/!, 1'" I t~ I I/"%1 I Z£06£'9~ O~£L£'Z OOg'ZO£L BO~6L '9~ O~ZZ*~' L~ ~Z69SZ'~ £969g'95 ~90£'0Z OZZZB9'~ V£L06'9B 06LZg'LZ 989'B6E~ EgO~6'9g 085~'0Z OS~Z£'Z9 ~Lg6B'£9 6Z9~9"~ 69~g6'~9 9L~Z9"~9 ~£~Z98'L £~L'~6~L £0Z96'8~ 60£60'6~ ~9969L'~ ~0909'58 OB~O2'L9 00S,66£~ 99£g6'6S OZZZg'~ ~Z L~Z~' L 000'09Z£ 96£~ 8£6'60£[ 00Z96~'~ 000 '0£B£ ZBO6'Z6£ LO9~Z6'£ O00'OBS£ tZ&&'~£ OOLgZO'~ 000'0£6£ LSZ~' LOt £ i, 8'68Z L 00~0~"~ 000 '0~6£ O00"OZ~L 000'0£0~ £L£'OL~L 00£9g0'~ O00'OSO~ ~£99'90~ 00££6~'£ 000'0£~ £90 ' g";'~ !, LOZ£O0 '~ 000 ' 0~' I,'~ 96£0'9B~ O00'O£Z~ LOLg'ffL9 O01, S9.c' +~ 000 'O8Z~, 9~L0'9~ 000~B6'£ 000'0££~ O~Z~'ZZ6 000'06£L 000'05£~ 'ON £~d3~ £ N~ ]~Ia Z # 00'0£~£ = H£dBO ~d~l 9NiONf 00'0££~ -- Nld~O ~dV£ 9NI£~1S S0~03~ ~±~0 O0[Z'666- OOgZ'666- 00~Z'666- O00000~'O OOgZ'O~S 0000'00~ Z69699Z"O Lg~z'ZZg £9~'~0L~ £Z£~£'L OOg'~£OL 6Bt£"~L8 9Bg91,9g'O 0SZ'98 I,i, Z669 'gZZ OOff'666- 00f~'666- 00~'066- O00000~'O ~0~60'L6 00000"0~- +~EE800'E .661,9'~1, 9£6~8 '0~ 6EO£OZ'~ 066Z8'9~ ~;£9g'Z2 I, 69Z6g'8£ ~gB6'ZE~ /_B96£' ~Z 00~'666- 00;2'656- 00~'666- ~Z£~'S~ 3000000'0 0~'66'~ ~ £90'6~0L Otg66'gL OF.g' 6Z~;~ 0'/966 -_c~ 991,'Z0~ !, /..£ o · I,.£ s; ~ 0'~66 ".c !, 00~'666- 00~'666- 00~'666- 00~"666- 00g~'666- 00~'666- 80~2'666- 000"0£~£ 000000~ '0 0000000'0 03 C./... 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TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 13 10610.00 ENOING TAPE DEPTH 10460.00 FILE # 9 REPEAT.O09 **** FILE HE4OER **** 1024 * COMMENT RECORO * CN-ZDL-REPEAT- RUN NO I FORMAT RECORD (TYPE# ONE DEPTH PER FRAME TAPE DmPTH UNIT : :T 20 CURVES : NAME COD I GR 68 2 CAL 68 3 SSO 68 4 SHR 68 5 R~ 68 6 DEV 68 7 CHT 68 8 TTEN 68 9 SPD 68 10 SFT2 68 11 HRD1 68 12 HRD2 68 13 LSN 68 14 SSN 68 15 CN 68 16 CNC 68 17 'ZDEN 68 18 :ZCOR 68 19 PE 68 20 PORZ 68 E SaM 64:) PLE# UNIT BYTES I API 4 I iN ~ I CTS 4 I CTS 4 I DEG 4 I DEG 4 I LB 4 I LB 4 I F/FM ~ -- I CTS 4 I CTS ~ I CTS 4 I CTS 4 I CTS 4 1 PCT 4 I PCT 4 I GMCC 4 I GMCC 4 I BARN 4 I PCT 4 D4TA RECORD / DEPTH RB CN PORZ~ 3560.000 -999.2500 -999.2500 (TYPE# O) 1014 BYTES * GR DEV HRD1 CNC -999.2500 -999.2500 CAL CHT HRD2 ZOEN -999.2500 -999.2500 -000 SSD TTEN LSN ZCOR -999.2500 -999.2500 SHR SPD SSN PE -999.2500 -999.2500 --OOQ ~ £=1 ~ .LIN:ti H.Ld::tU ~W~$~_--I ~d H.LcI.~O 2NO (~9 #~d~i) OtlO3~ l~W~O~ 2 ON N~ - ~ ON l~2d2~-~G,Z-N3 00'092£ = Hld~O 9N!ON~ 00'09~£ = Mld~0 ~d~£ 00S~'666- 00~2'666- 00~2'666- 00S2'666- ~£0966'k 9~k9'~ ~92L61,'2 6£~9 ' I,~ ~ ££2066'2 ~Z~'~O~ 0££~9'0 0~09~£ '£ Z~ ~'*~ I, I, I, YZ66'S~ I, Z2£~'0 £2Z6~'~ 69££'~ ~Z66'S2 ~6Z096~'0 00~2'666- 00S2'666- 00S~'666- 00S2'666- ~9~200L'0 06£9~'£~ g~g'OOZ5 6Z~6Z9~'O .b~6~'££ ~66~L'0 OOZZ9'£~ 1,0-B609BZtB'0 0~'6~20~ L0-B£~Z6'0 02~00'Z2 99'Z92~ 00~'666- 00~2'666- 00~2'666- 00~2'666- 66Z'200L 9Z292k'2 £0£~'£66 9~OBL~'2 69LB'9B6 zgok£'O2 ~£9922 '~ 926 '~9~ 296'~kOk £6~6'2k £ Lg£66' L 2L~'Z29~ L-c96 '~£6 , 0052'666- 00~'666- 00~'666- 00~2'666- 6£ZZ~'g2 ££~'~9Z~ Z~££'89£ ££L£~'~£ 66~99'£~ Z6L9g '£g ~06'£9L2 LLkg6'O~ 60~'809£ Z~££'g9£ ~9L0'92 00g~'666- 00~2'666- 00~2'666- 00~2'666- 000'09Z£ 89602'~k 000'0L££ 062£S'2~ 2~9'086~ 000'09££ O06Z I,'9;~ E?. l,,6g' 9~ Z L0'~'LI, 2 2~9'g~ 62~9Z'9~ 996'02B~ 000'09~£ 80ZBZ'6£ 9££'~00£ O00'OL~£ r 00~2'666- CURVES NAME 1 GR 2 CAL 3 SSO 4 SHR 5 6 TTEN 7 SPD 8 SFT2 9 HRD1 10 HRD2 11 CN 12 CNC 13 ZDEN 1 4 'ZCOR 15 16 PORZ COD 68 68 68 68 68 6~ 68 68 68 68 68 68 68 68 E SAMP 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 LE# UNIT BY. TES API ' 4 IN 4 CTS 4 CTS 4 OEG 4 LB 4 F/FM 4 CTS 4 CTS 4 CTS ~ PCT 4 PCT 4 GMCC 4 GMCC ~ BARN 4 PCT 4 , DATA RECORD DEPTH RB HRD2 PE 3400.000' -999.2500 -999.2500 -999.2500 3350,000 238,5223 2037,512 26,51527 3300.000 0.0000000 0.0000000 0.0000000 (TYPE# GR TTmN~ CN PORZ 999.2500 999.2500 999.25C0 999.2500 .go00000 2299.558 99.89145 75,73625 21.71967 2000.000 79.93030 .0000000 O) 958 BYTES * CAL SPD CNC -999.2500 -999.2500 -999.2500 12,34854 25.99741 103,3724 lb. O0000 0.000OO00 0,0000000 SSD SFT2 ZD:N -999,2500 -999,2500 -999,2500 3360,937 550,4656 1,414910 0.0000000 0.0000000 2.000000 SHR HRD1 ZCOR -999,2500 -999,2500 -999,2500 0,1565920 1180,363 -0,9535793 0,0000000 0,0000000 -0,2500000 TOTAL DATA RECORDS STARTING TAPE DEPTH FILE TRAILER **** : 19 = 3400.00 ;NDING TAPE DEPTH = 3270,00 FILE # 11 **** FILE HEADER. **** REPEAT.011 1024 * COMMENT RECORD * CN-Z:DL-REPEAT NO 2 - RUN NO 2 · FORMAT ONE DEP RECORD (TYPE# TH PER FRAME TAPE DEPTH UNIT : FT 16 CURVES : NAME COD 1 GR 58 2 CAL 68 3 SS~ 68 4. 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II III III III Itl III III III III III III II O0 II 000000000 I!1 000000000 III O0 000 !11 O0 0000 III O0 00000 /// 00000 O0 /// 0000 O0 /// 000 O0 /// 000000000 /// 000000000 /// O0 // ZLL LLL LLZ LLL LZZZZZZL O0 000000000 000000000 O0 000 O0 0000 O0 00000 00000 O0 0000 O0 000 O0 000000000 000000000 O0 LLLLLLLL LLLLLLLL LL LL O0 000000000 000000000 O0 000 O0 0000 O0 00000 00000 O0 0000 O0 000 O0 000000000 000000000 O0 O0 000000000 000000000 O0 000 O0 0000 O0 00000 00000 O0 0000 O0 000 O0 000000000 000000000 O0 O0 000000000 000000000 O0 000 O0 0000 O0 00000 00000 O0 0000 O0 000 O0 000000000 000000000 O0 dd dd dd dd ~d~d'ddd d~dddddd dd dd dd dd d~dddddd ddddddd PROGRAM: LISCAN REVISION: 5.1 PART NUMBER: W5790-PE32 Start of execution: Mon 2 .JLY 90 3:25~ **** REEL HEADER **** LIS 90/04/24 ATLAS 01 ** LIS CUSTOMER LIBRARY TAPE ATLAS WIRELZNE SERVICES WELL DATA SYSTEM **** TAPE HEADER **** LIS 90/04/24 00014282 01 DIGITAL ARRAY ACOUSTIC FILE # 1 MAIN .001 **** FILE HEADER ~*** 1024 CN WN FN COUN STAT CONOCO iNCORPORATED BADAMI NO. 1 BADAMI NO. 1 NORTH SLOPE ALASKA * COMMENT RECORD * OTC, DTS, DTST AND SCRA COMPUTED FROM DIGITAL ARRAY .ACOUSTILOG This 'is ~he last 'comment line. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 8~06" I,~ 860Z"90~ 0/.~9" ~1,~ ~S 1,6"01,~ /.. ~ £0 ' 90;~ £~0~"60~ 1,69S "60~ 0~1,6"~£~ 00S~'666- oo,¢z'666- 8 ~£~' 6.1, i, 9999'7_01, OSSO'6~L S9/_9" ~ +/I, OOS~ '666- 6££Z"ff~7 i, 91,68"Z~ i. 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